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HomeMy WebLinkAbout1.0 ApplicationWilliams WILLIAMS PRODUCTION RMT CO. Parachute Creek Gas Plant Expansion Phase III Garfield County Special Use Permit Application November 2005 • • • GARFIELD COUNTY Building & Planning Department 108 8th Street, Suite 201 Glenwood Springs, Colorado 81601 Telephone: 970.945.8212 Facsimile: 970.384.3470 www, garfie ld-cou nty. com Special Use Permit GENERAL INFORMATION (To be completed by the applicant) Street Address 1 General Location of Property: 4289 County Road 215 Parachute, CO 81635 A Legal Description: Please see attachment 4 "Site Plan" for legal description ➢ Existing Use & Size of Property in acres: Use : Gas Plant/drilling. Acres: • Description of Special Use Requested: Request for an addition to the Williams Production RMT Co. Parachute Creek L'as Plant. Zone District:Resource Lands- Lower Valley Floor 1 ➢ Name of Property Owner cApplicant# illiams Production RMT Co. • Address: 1058 County Road #215 Telephone: 970-285-9377 • City: Parachute State: CO Zip Code:81635 FAX970-285-93''7 > Name of Owner's Representative, if any (Attorney, Planner`etc): Philip Vaughan-PVCMI- Land Planning Division • Address:1038 County Road 323 Telephone: 970-625-5350 y City:Rifie State: C0 ,333+/ - Zip Code: 81650 FAX: 970-625-4522 STAFF USE ONLY > Doc. No.: Date Submitted: TC Date: Y Planner Hearing Date: • • • 1. APPLICATION SUBMITTAL REQUIREMENTS As a mnimum, specifically respond to ail the following items below and attach any additional information to be submitted with this application: Please submit, in narrative form, the nature and character of the Special Use requested. Submit plans and supporting information (i.e. letters from responsible agencies). Include specifications for the proposed use including, but not limited to, the hours of operation, the number and type of vehicles accessing the site on a daily, weekly and/or monthly basis, and the size and location of any existing and/or proposed structures that will be used in conjunction with the proposed use, and provisions for electric power service and any other proposed utility improvements. Be specific. .,i If you will be using water or will be treating wastewater in conjunction with the proposed use, please detail the amount of water that would be used and the type of wastewater treatment. If you will be utilizing well water, please attach a copy of the appropriate well permit and any other legal water supply information, including a water allotment contract or an approved water augmentation plan to demonstrate that you have legal and adequate water for the proposed use. 13. Submit a site plan /map drawn to scale that portrays the boundaries of the subject property, all existing and proposed structures on the property, and the County or State roadways within one (1) mile of your property. If you are proposing a new or expanded access onto a County or State roadway, submit a driveway or highway access permit. f4. Submit a vicinity map showing slope / topography of your property, for which a U.S.G.S. 1:24,000 scale quadrangle map will suffice. J5. Submit a copy of the appropriate portion of a Garfield County Assessor's Map showing all the subject property and public and private landowners adjacent to your property (which should be delineated). In addition, submit a list of all property owners, public and private landowners and their addresses adjacent to or within 200 ft. of the site. This information can be obtained from the Assessor's Office. We will also need the names (if applicable) of all mineral right owners of the subject property. (That information can be found in your title policy under Exceptions to Title). J6. Submit a copy of the deed and a legal description of the subject property. J8. If you are acting as an agent for the property owner, you must attach an acknowledgement from the property owner that you may act in his/her behalf. Submit an statement that specifically responds to each of the following criteria from Section 5.03 of the Zoning Regulations: J(1) Utilities adequate to provide water and sanitation service based on accepted engineering standards and approved by the Board of County Commissioners shall either be in place or shall be constructed in conjunction with the proposed use. J(2) Street improvements adequate to accommodate traffic volume generated by the proposed use and to provide safe, convenient access to the use shall either be in place or shall be constructed in conjunction with the proposed use: J(3) Design of the proposed use is organized to minimize impact on and from adjacent uses of and through installation of screen fences or landscape materials on the periphery • c. The site shall be posted such that the notice is clearly and conspicuously visible from a public right-of-way, with notice signs provided by the Planning Department. The posting must take place at least thirty (30) but not more than sixty (60) days prior to the hearing date and is the sole responsibility of the applicant to post the notice, and ensure that it remains posted until and during the date of the hearing. 4. The Applicant is required to appear before the Board of County Commissioners at the time and date of the public hearing at which time the Board will consider the request. In addition, the Applicant shall provide proof, at the hearing, that proper notice was provided. 5. Once the Board makes a decision regarding the Special Use request, Staff will provide the Applicant with a signed resolution memorializing the action taken by the Board. Following the Board's approval, this office will issue the Special Use Permit to the applicant. If the Board's approval includes specific conditions of approval to be met, this office will not issue the Official Special Use Permit certificate until the applicant has satisfied ail conditions of approval. The Special Use Permit approval is not finalized until this office has issued the Official Special Use Permit certificate signed by the Chairman of the Board of County Commissioners. I have read the statements above and have provided the required attached information ich is correct and accurate to the best of my knowledge. \T\\ (Signature of applicant/owner) Last Revised: 07/25/2005 GARFIELD COUNTY BUILDING AND PLANNING DEPARTMENT FEE SCHEDULE Garfield County, pursuant to Board of County Commissioners ("Board") Resolution No. 98-09, has established a fee structure ("Base Fee") for the processing of each type of subdivision and land use applications. The Base Fee is an estimate of the average number of hours of staff time devoted to an application, multiplied by an hourly rate for the personnel involved The Board recognized that the subdivision and land use application processing time will vary and that an applicant should pay for the total cost of the review which may require additional billing. Hourly rates based on the hourly salary, and fringe benefits costs of the respective positions combined with an hourly overhead cost for the office will be used to establish the actual cost of County staff time devoted to the review of a particular project. Actual staff time spent will be charged against the Base Fee. After the Base Fee has been expended, the applicant will be billed based on actual staff' hours accrued. Any billing shall be paid in full prior to final consideration of any land use permit, zoning amendment or subdivision plan. If an applicant has previously failed to pay application fees as required, no new or additional applications will be accepted for processing until the outstanding fees are paid. Checks, including the appropriate Base Fee set forth below, must be submitted with each land use application, and made payable to the Garfield County Treasurer. Applications will not be accepted without the required application fee. Base Fees are non-refundable in full, unless a written request for withdraw from the applicant is submitted prior the initial review of the application materials. Applications must include an Agreement for Payment Form ("Agreement") set forth below. The Agreement establishes the applicant as being responsible for payment of all costs associated with processing the application. The Agreement must be signed by the party responsible for payment and submitted with the application in order for it to be accepted. The complete fee schedule for subdivision and Iand use applications is attached. GARFIED COUNTY BUILDING AND PLANNING DEPARTMENT BASE FEES The following Base Fees shall be received by the County at the time of submittal of any procedural application to which such fees relate. Such Base Fees shall be in addition to and exclusive of any cost for publication or cost of consulting service determined necessary by the Board for the consideration of any application or additional County staff time or expense not covered by the Base Fee, which have not otherwise been paid by the applicant to the County prior to final action upon the application tendered to the County. TYPE OF PROCEDURE BASE FEE Vacating Public Roads & Rights -of -Way $400 Sketch Plan $325 Preliminary Plan $675 + application agency review fees and outside consultant review fees, as authorized pursuant to the Regulations, such as the Colorado Geologic Survey Final Plat $200 Amended Plat $100 Exemption from the Definition of Subdivision (SB -35) $300 Land Use Permits (Special Use/Conditional Use Permits) • Administrativelno public hearing $250 • Board Public Hearing only $400 • Planning Commission and Board review & hearing $525 Zoning Amendments • Zone District map amendment $450 • Zone District text amendment $300 • Zone District map & text amendment $500 • PUD Zone District & Text Amendment $500 • PUD Zone District Text Amendment $500 Board of Adjustment • Variance $250 • Interpretation $250 Planning Staff Hourly Rate • Planning Director $50.50 • Senior Planner $40.50 • Planning Technician $33.75 • Secretary $30 County Surveyor Review Fee (includes review ofAmended Determined by Surveyor$ Plats, Final Pints, Exemption Plats) Mylar Recording Fee $11 - 1" page $10 each additional page Page 2 • The following guidelines shall be used for the administration of the fee structure set forth above: 1. All applications shall be submitted with a signed Agreement for Payment form set forth below. 2. County staff shall keep accurate record of actual time required for the processing of each land use application, zoning amendment, or subdivision application. Any additional billing will occur commensurate with the additional costs incurred by the County as a result of having to take more time that that covered by the base fee. Any billings shall be paid prior to final consideration of any land use permit, zoning amendment, or subdivision plan. All additional costs shall be paid to the execution of the written resolution confirming action on the application. 4. Final Plats, Amended or Corrected Plats, Exemption Plats or Permits will not be recorded or issued until all fees have been paid. 5. In the event that the Board determines that special expertise is needed to assist them in the review of a land use permit, zoning amendment, or subdivision application, such costs will be borne by the applicant and paid prior to the final consideration of the application. All additional costs shall be paid prior to the execution of the written resolution confirming action on the application. 1110 6. If an application involves multiple reviews, the Applicant shall be charged the highest Base Fee listed above. • 7. Types of "Procedures" not listed in the above chart will be charged at an hourly rate based on the pertinent planning staff rate listed above. 8. The Planning Director shall establish appropriate guidelines for the collection of Additional Billings as required. 9. This fee structure shall be revised annually as part of the County budget hearing process. Page 3 • • • GARFIELD COUNTY BUILDING AND PLANNING DEPARTMENT AGREEMENT FOR PAYMENT FORM (Shall be submitted with application) GARFIELD COUNTY (hereinafter COUNTY) and Williams Production RMT C o . (hereinafter APPLICANT) agree as follows: 1. APPLICANT has submitted to COUNTY an application for Parachute Creek Gas Plant Expansion— Phase 3 (hereinafter, THE PROJECT). 2. APPLICANT understands and agrees that Garfield County Resolution No. 98-09, as amended, establishes a fee schedule for each type of subdivision or land use review applications, and the guidelines for the administration of the fee structure. 3. APPLICANT and COUNTY agree that because of the size, nature or scope of the proposed project, it is not possible at this time to ascertain the full extent of the costs involved in processing the application. APPLICANT agrees to make payment of the Base Fee, established for the PROJECT, and to thereafter permit additional costs to be billed to APPLICANT. APPLICANT agrees to make additional payments upon notification by the COUNTY when they are necessary as costs are incurred. 4. The Base Fee shall be in addition to and exclusive of any cost for publication or cost of consulting service determined necessary by the Board of County Commissioners for the consideration of an application or additional COUNTY staff time or expense not covered by the Base Fee. If actual recorded costs exceed the initial. Base Fee, APPLICANT shall pay additional billings to COUNTY to reimburse the COUNTY for the processing of the PROJECT mentioned above. APPLICANT acknowledges that all billing shall be paid prior to the final consideration by the COUNTY of any land use permit, zoning amendment, or subdivision plan. APPLICANT KNAli --- PY "a'N,SN. V Signature Date: 1\1-I'AbC Wc.• Print Name Mailing Address: 1012004 Page 4 • TABLE OF CONTENTS WILLIAMS PRODUCTION RMT CO. PARACHUTE CREEK GAS PLANT PHASE 3 EXPANSION GARFIELD COUNTY, COLORADO SPECIAL USE PERMIT 2005 1. Special Use Permit Application (Items 1 through 11 are arranged as called for in the Garfield County Special Use Permit "Application Submittal Requirements") 2. Introduction including overview of project, Garfield County Comprehensive Plan of 2000 and Garfield County Zoning Resolution compliance. 2a. Site pictures 3a. Water System 3b. Wastewater System 4. Site Plan 5. Garfield County Road & Bridge Department- Access Issues 6. Vicinity Map 7. Garfield County Assessor's Maps 8. Listing of Adjacent Property Owners adjacent to or within 200' of the subject property Page 1 of 3 40 9_ Deed & Legal Description of Property • • 10. Authority of Authorized Representative 11. Impact Statement- Cover Letter (The items prepared within section 11 are arranged as called for in the Garfield County Supplemental Regulations Section 5.03.07 and are additionally compliant with Garfield County Supplemental Regulations Section 5.03.08 items #1-#4 Industrial Performance Standards) 1.A. Existing lawful use of water. 1. Construction Stormwater Management Plan prepared by Cordilleran Compliance Services, Inc. 2. Spill Prevention Control and Countermeasure Plan prepared by Cordilleran Compliance Services, Inc. 3. Domestic Water System- Please see attachment "3a Water System". 1.B. Impacts on adjacent land 1. Vapor- Please see copy of Air Pollution Control Division Construction Permit attached in 12.1.8.1. 2. Dust- Statement on Dust Control. 3. Smoke- Please see copy of Air Pollution Control Division Construction Permit attached in 12.1.B.1. 4. Noise- Statement on Noise Abatement. 5. Glare- Statement on Glare Abatement. 6. Vibration- Statement on Vibration Abatement. Page 2 of 3 1.C. Impacts on Wildlife See attached letter. 1_D. Impacts of Truck and Automobile Traffic. 1. Traffic Analysis Prepared by Felsburg, Holt and Ullevig. 1.E. Distances from Abutting Property. Letter attached regarding abutting property. 1.F. Mitigation Measures Proposed. Please see mitigation measures noted in each of the submittal items. 2.A. Site Rehabilitation Plan 12. Performance Standards as detailed in Garfield County Supplementary Regulations 5.03.08 (5) 5A. Storage of flammable or explosive solids or gases. 5B. Enclosures. Fencing of site. 5C. Materials or wastes transferred off property. 5D. Storage of heavy equipment. 5E. Storage area sizing. 5F. Lighting to be pointed downward and inward. 6. Water Pollution. Please see submittals in 12.1.A SWIVEL') and SPCC and 12.1.B Air Pollution Control Division Construction Permit. Page 3 of 3 PVCMI Land Planning Division 1038 County Road 323 Rifle, CO 81650 Ph. 970-625-5350 Fax 970-625-4522 Email: pvcm@direcway.com direcway.com November 30, 2005 Mr. Mark Bean Director Garfield County Building and. Planning Department 108 8th Street, Suite 201 Glenwood Springs, CO 81601 Dear Mr. Bean, Please consider this packet our application for a Special Use Permit for the Williams Production RMT Co. Parachute Creek Gas Plant Expansion Phase 3 located at 4289 County Road #215 Parachute, Colorado 81635. 1. Project Description: The proposed plant expansion is an 11.18 acre expansion to the existing plant phases 1 and 2. Phase 1 was permitted in 2002 via Garfield County Resolution 2002-67 dated June 17, 2002. Phase 2 was permitted in 2004 via Garfield County Resolution 2005-09 dated January 3, 2005. This resolution included phase I and phase 2 under the same special use permit. A copy of resolution 2005-09 is attached_ The property encompassing the Parachute Creek Gas Plant will be leased by Bargath, Inc., a wholly owned subsidiary of Williams Energy. This executed lease document is attached. The Parachute Creek Gas Plant is located within a 1,333 -acre parcel owned by Williams Production RMT Co. The existing plant and the proposed expansion are well-placed within this property to reduce impacts on adjacent properties. Please see exhibit 6 - Vicinity Map. Page 1 of 6 The Parachute Creek Gas Plant is utilized to collect natural gas from area gathering systems and process the natural gas by removing water, natural gas liquids and carbon dioxide (CO2) to provide the quality necessary for introduction to interstate natural gas pipelines. The existing plant design capacity is 300,000,000 standard cubic feet of natural gas per day (MMSCFD). The proposed plant expansion will expand capacity to 800 MIvMSCFD which is inclusive of phases 1, 2 and 3 of the plant. As noted in the attached plot plans, a portion of Phase 3 is planned to be completed in 2006 and the equipment noted "Future" will be installed at a later date. The goal of this Special Use Permit application is to allow for the phase 3 expansion in its entirety to be considered within this application. This additional plant capacity is needed by Williams Production RMT Co. to keep pace with the projected production curve. The removal of the carbon dioxide from the process will continue to benefit the Solvay Chemicals CO2 facility that will allow a portion of the CO2 removed from the natural gas to be put to beneficial use in the soda ash operation at Solvay Chemicals. There are 4 new buildings proposed for the plant expansion. A. Compressor Building- 75' wide x 450' long x 35' eave height. B. Amine Regen Building- 70' wide x 100' long x 40' eave height. C. MCC/Control Building- 50' wide x 75' long x 40' eave height. D. Warehouse/Office Building- 75' wide x 200' long x 40' eave height. These buildings are sized for maximum sizing and may be constructed in smaller dimensions. The plant operates 24 hours a day, 7 days a week and 365 days per year. The current plant employs 20 full time employees and 18 tanker trucks serve the plant every 24 hours. The plant expansion is expected to add 17 full-time employees to the plant and will add 13 tanker trucks loading at the plant each day. These items are detailed in the traffic analysis in 11.1.D.1. A number of skid -mounted pieces of process equipment are being installed at the site. These are noted on the attached plot plan prepared by The Hanover Company dated 8/9/05 and includes the equipment with legend and a designation as to whether the equipment will be installed during the Phase 3 expansion or in the future. Seven new Caterpillar 3612 residue gas compressors will be installed at the site. The air permit issued by the Air Pollution Control Division includes the calculation for 4 of these 7 compressors. Air permits will need to be applied for and received from the State of Colorado for the additional 3 compressors as they are built. Residential Grade exhaust silencers will be installed on the compressors and the compressors will be enclosed by a pre-engineered steel building. Page 2 of 6 • Electrical power was upgraded to the existing Parachute Creek Gas Plant and was completed in September 2004. This electrical upgrade has been sized to serve the Phase 3 plant expansion as well. Construction Schedule: A. Overlot grading of the site- December 2005/January 2006. B. Steel piling installation- January -July 2006. C. Equipment foundations are anticipated to be poured in January -September 2006. D. Piping, equipment installation and other associated work will occur from February -September 2006. E. Building foundations and building erection will occur after approval of the special use permit. F. Plant startup is scheduled for October 2006. A grading permit will be applied for and received from Garfield County prior to the overlot grading of the proposed site of the Phase 3 expansion. Williams Production RMT Co. has agreed to move forward with piping and equipment installation "at their own risk" as the Garfield County Special Use Permit for the proposed plant has not been granted. • Please find attached pictures of the existing Parachute Creek Gas Plant and the surrounding area. 2. Existing zoning: The proposed plant expansion area is Resource Lands- Lower Valley Floor. The Garfield County Zoning Resolution Section 3.10.04 notes "Resource Lands- Gentle Slopes and Lower Valley Floor. Uses, special: allowed by permit only: Industrial support facilities which would include: material handling, pumping facilities,. electric distribution, warehouse facilities/staging areas, water impoundments, access routes, utility lines, utility substations, pipelines; extraction, processing, accessory uses to the above..." We see that the proposed Parachute Creek Gas Plant expansion meets the Garfield County Resource Lands- Gentle Slopes and Lower Valley Floor special use permit designations. 3. Surrounding zoning: Resource Lands and the existing uses are Industrial and Agricultural. Page 3 of • • • 4. Garfield County Comprehensive Plan of 2000: The Garfield County Comprehensive Plan of 2000 notes this project in Study Area 3. Natural Resource extraction is detailed in Section 9 of the "Goals, Objectives, Policies and Programs" located on page 17. "Garfield County recognizes that under Colorado Law, the surface and mineral right interests have certain legal rights and privileges, including the right to extract and develop these interests. Furthermore, private property owners also have certain legal rights and privileges, including the right to have the mineral estate developed in a reasonable manner and to have adverse land use impacts mitigated." Policies Section 9.1 notes: "Garfield County, to the extent legally possible, will require adequate mitigation to address the impacts of mineral extraction on adjacent landowners. These measures may include the following: A. Landscaping and screening; B. Modification of phasing or area to be mined; C. Roadway improvements and signage; D. Safe and efficient access routes; E. Drainage improvements to protect surface and groundwater" We see that the proposed Parachute Creek Gas Plant expansion meets the Garfield County comprehensive plan goals, objectives, policies and programs. We have addressed each of the policies stated in 9.1. Additionally, the Parachute Creek Gas Plant permitting in June 2002 and January 2005 and the functioning of the plant over the last 3 years has demonstrated compliance with the Garfield County Comprehensive Plan. 5. Referral Agencies: We have had two pre -application meetings with Mr. Fred Jarman of the Garfield County Building and Planning Department. The first at Mr. Jarman's office on September 22, 2005 and a second meeting at the Parachute Creek Gas Plant on September 27, 2005. We have met with many of the referral agencies to review the proposed plant expansion and to review agency concerns and issues. Please find below status of meetings with referral agencies to date. A. Garfield County Road & Bridge Department- September 13, 2005 Jake Mall meeting at Parachute Creek Gas Plant Site. Jake and 1 reviewed the signage and striping improvements made in June 2005. We agreed that a new traffic Page 4 of 6 • • • analysis would be prepared for the Phase 3 plant expansion. We have addressed these items in submittals in sections 5 "Access Issues" and 11.1.D. "Traffic". B. Grand Valley Fire Protection District- September 20, 2005 meeting with David Blair at Parachute Creek Gas Plant Site. There was a conversation regarding fire protection on-site. We have addressed these items in a submittal in Performance Standards section 12.5.A. C. Town of Parachute- September 20, 2005 meeting with Town of Parachute Planner Aaron Kunz and Town of Parachute Engineer Mark Austin. We have addressed the items noted by the Town of Parachute throughout our application packet. We are preparing an application to the Town of Parachute to respond to the Town of Parachute Ordinance 11,492 regarding the Watershed Protection District. D. Colorado Division of Wildlife- We met with the Parachute District CDOW officer J.T. Romatske at the Parachute Creek Gas Plant site on August 30, 2004 regarding Phase 2 of the plant. Our response regarding Phase 3 is in submittal 11.1.0. E. Jesse Smith- Assistant County Manager/Acting Garfield County Oil and Gas Auditor- A meeting was held on November 22, 2005 with Mr. Jesse Smith at his office. The draft application and draft site plan were reviewed with Mr. S mith. F. Steve Anthony- Garfield County Vegetative Management- A meeting was held on September 30, 2005 at the Parachute Creek Gas Plant site.. The items discussed are addressed in 11.2.A Site Rehabilitation Plan. 6. Impact Statement - Please find this information in submittal number 11 in the application. Page 5of6 7. Performance Standards as detailed in the Garfield County Supplementary • Regulations 5.03.08 (5) Please find this information in submittal number 12 "Performance Standards" in the application. Please contact me with any questions. Sincerely, Philip B. Vaughan President PVCMI • • Page 6 of 6 L•..LA I1 kY jLLjr9 IJ r"rwi) RI�11 PARACHUTE III SURFACE LEASE AND AGREEMENT State: Colorado County: Garfield Lessor: Williams Production RhiT Company Lessor's Address: I5!$ Arapahoe Street, Tower 3, Suite 10DD Denver, CO 80202 Lessee: 9argath Inc. Lessee's Address: ala Williams Production IQ 11 Company 1515 Arapahoe Street, Tower 3, Suite 1000 Denver, CO 80202 Date Emmert November 30, 2005 Effective Date: November 30, 2005 IYU. dI 1 t"./4 In consideration of the rental provided below, to be paid ley Lessee to Lessor, each named above, Lessor grants, 'ewes and lets to Lessee the tract of land (the "bands") for the Parachute iII Compressor Facility Site located in the routs*, and at named above, and described as follows: (Sec Exhibit "A" attached hereto and made a part hereof.) This Compressor 5tatimPlant lease and Agreement (the "Lease") shell be fora primary term of twenty (20) years (the "Primary Term') from the Effective Date stated above, with options of renewal for each subsequent twenty (20) year period. The option to renew the term of this tease for each subsequent twenty (20) year period shall be exercisable by Lessee by delivering, notice (the "Notice") in writing to Lessor at the address set out above (or to the address Furnished later to Lessee by Lessor) before the enci of nail twenty (20) year period. With that execution of this Lease, Ixssen has paid to Lessor the sum of 52,000,00 as rental compensation for the Tull Primary Term of this Lease. At any time prior to the end of the Primary Term or prior to the end of each snbseeprent twenty (20) year rem, et the option of Lessee, Leasee may extend this lease for an additional term of twenty (20) years by paying tenial amount of SI,500.00 to Lessor. Payment for each successive twenty (20) year period shall bo duo on or before the end of the preceding twenty (2Q) yeas period, Lessee agrees to fllmislt Lessor a recordable Release of the rights granted under the terms of this I.triwe at the termination of this Lease. As part of the consideration far this Lease, Lessee agrees to hold Lessor harmless from Otey and olI claims. damages, suits or obligations, ctximed or asserted against Lessor by reason of Lessee's operation or business on the Lands and against any and all parries asserting such claims, and to defend Lesser in any and all shits brought against Lessor by reason of Lessee`, operations on the Ltnds, all tit Lessee's expense, Lessee covenants and ttgrccs to pay any taxes which may be levied upon or assessed against struetures, fixtures or other equipment which may be built or Installed on the Todds by Lessee. This is n surfircti: ILasc only and shall not be construed to limit Lessor's right as the owner of minerals in and under she Lands_ Without restricting or limiting the general and exclusive rights, privileges, powers, purposes and uses panted to Lessee, by the enumeration of the metiers set aut below, it specifically agreed drat the Lands leased pursuant to this Lease may be used, occupied and enjoyed by Lessee for the following purposes: Constructing, acting, ere: ting. Installing, operating, mrsinmiuing. Inspecting. using. replacing. repairing, moving on and removing from the lends a compressor station and/or gasoline plant end_'or gas purit'ing, dehydrating. treating and cleaning plant and all buildings, watehoumcs, Page 1 of 3 .i"-11'11 ,v 1 1 1 11 L).O Ji r..1OL4 garages, storage facilities and structures of whatever kind, together with oar machinery, engines, pumps, equipment, appliances. facilities, meters. pipes, regulators, fittings, gate *elves, blow off valves, gate boxes, boilers, stills, heaters, drips, cooling towers, Opal Inca, telephone lines, electric transmission lints, and any other strutter (collectively the "Facilities") es may be necessary, convenient, or desirable to Lessee in Its operations in oarrying on its business in which Itis now engaged or may herenfcr be engaged. Lessor agrees that Lee may use the existing roads on Lessor's lands show on the utiechcki Exhibit "A" for the purpose of oecessing The facilities, with the right of ingress and egress for such use and purposes at al! times. Lessor's grant to Ltt&Ge includes tan right to dig andior drill n Water well CT' welts on the Lands and use water produced from such wells in Lessee's operations. In tht event it becomes necossory to drilla .eater weld or wells on the Lands, Lessee ogreea to leave casing in such well tar wells for use by Lessor when this Lease terminates and the Lands arc vacated by Lessee, 1.e95ee is granted the right to ley, repair and remove lines of pipo for water, gas, or oil over adjacent lands of Lessor, and erect and maintain telephone Tines and electric transmission linea, at a reasonable consideration or compensation to be paid to Lessor, with the right of ingress and egress for such use and purposes ai all times. Lessee shall have the right to du and perfoml any act on Lessor's adjacent lands its may become necessary ro protect Lesseo"a property in ease of fiood or fire, and to prevent the &paid and loss of oil and other liquid3. Lassce warrants end agrees that it will comply with any and ail laws, ordinances, orders, rules, regulations, standaidtt and licensing requirements of any stets, federal, municipal or local authority ar agency, now in force and effect or which may be passed, enacted, issued, revised, requited or later promulguted. incident to or nrlsing our ofor in any way connected with Lessee's utilisation of the Lands or any activity conducted tmder, pursuant to or by virtue of this [.ease. Lessee agrees that it will nor discharge, dump, bury or store for purposes of disposal, pollutants of any kind on he Lands or into or on any water on, adjacent to or in the area of the Lands, including, but not limited to, pollutants such as oil, chemicals, toxic substances or materials, hazardous wustcs or hazardous st[b5tances, including pollutants as the sante may be dermad In any Federal, state or municipal laws, rules, regulations or ordinances, Lessee specifically agrees to fully indemnify and hold Lessor harmless from and against all claims, demands. Loses, costs for removal and(or cleanup of pollutants, judgments, causes of actions, finev, penalties, costs, including, but not limited to, attorneys' fees and costs of court, arising nut of or connected with Lessee's noncompliance with the terms of this Lease. Lessen has the right, upon the expiration oldie Primary Tesco of this Lease, or any extension thereof,as the; ono may be, within six (6) months after that dale to remove any and all buildings, amuses, structures and equipment which it muy have placed on the Lands, provided all rentals have been pairs. Les9ea agrees that upon the termination of this Lease for any reason, it will, if requested by Lessor, remove any or all structures acrd level then surface of the Lands nt L.esact's 501e coat wad expense. Notwithstanding anything herein contained to the contrary, the righty granted to Lesser herein shall ba nonexclusive; Lessor shall have the continuing tight ro rreeosr, the Lands and to use the property for any means which do not interfere with Lessees operations on the Lands. The terms, covenants arld previsions of this Lease shall extend ro and be binding upon Lessor and Lessee and their respective assigns and successors in interest, LESSOR Williams Production. Company By a rtt SU( ides ._At t rrie�t i' r r_ Page 2 of 3 LE5SJ E Hargeth hit• By: Nar _lice' ct34t__Sar_r- I ry k'Y LLL.F1JIJ Frruu MAI IYV.deli STATE OF COLORADO COUNTY OF DENVER Before ate. :t Notary Public, in and for said County And State aforesaid, do hereby conlfy that Joseph P. Barrett , whose mune is subscribed to the foregoing instrument us A t^CnE -in-Fa4t of Y' Prndue iu Cn a corporation, appeared before nye this day in perm' :end nciuyowtedged than a executed said instrument as b freo and voluntary act and deed as the tree and voluntary act and deed of said corporation {'Irr the uses and purposes therein ser forth. Given under my hand and Notarial Seal this 30th dav of Nov em.er, 2405.-) / My Commission Expires: 5/21/90n 7 (SEAL) Notary Public Patti E. Rives 1-.4/4 S TATE OF COLORADO ) COUNTY OF DENVER Before nt a .turyPublic, in and for Raid County and Stens aforesaid, do hereby certify lira[ J o s e p �3 r rett , whose name is subscribed to the foregoing instrument as Assistant Secretary ofBnrrath inc., a corporation, appeared before me osis day in person and acknowledged that i1C. executed said insrrurncnt as FtiS fits and voluntary act and deed es the free and voluntary net and deed of .mid corporation fur the uses and purposes therein set forth. Given under my hand and Notarial Seal this 30tda day of Novemlxr, 2005 My Commission Expires: 5/21/2007 (SEAL) Notary Public Patti E. Rives Page 3 of 3 Exhibit A -Surface Lease G4r1#206-26 NA N 26'20'42"W 252.95' GMg207-28 L. `?8 S28, T6S, \ S33. T6S, R96W ciP \\ 11 _ �GM#208-28 GM#44-28( I G‘126-28` PARACHUTE CREEK GAS PLANT PHASE NO.3 ±11.18 ACRES 33 1/4 CORNER 1912 GLO BRASS CAP PARACHUTE GM #215-33 WILLIAM'S OFFICE PARACHUTE REEK GAS PLANT PRISE NO.2-_-_-_- z - #31-33 GM #216-33( a GM /431--33 -� GM f531- 33 1 ARACHUTE CREEK G PLANT PHASE NO 1 \ // 7/ // // // // 1/ CONSTRUCTION SUI vs*T S, NC. 0012 SUNRISE 3L1/D. SILT, CO S1+'o52 (S10)E316-573 PROPOSED PARACHUTE CREE< GAS PLANT PHASE NO.3 GENERAL LEGAL DESCRIPTION: An easement for the purpose of constructing and maintaining a Gai Plant facility with all pertinent accessories situate in the SE1/4 SW1 /4 8c! SW1 /4 SE1/4 of Section 28 and in the NW1/4 NE1/4 of Section 33, Township 6 South, Range 96 West of the 6th Principal Meridian, Garfield County, Colorado, being more particularly described as follows: Commencing at a found 1912 GLO Brass Cap in place for the S1/4 corner of said Section 28; thence N26'20'42"W a distance of 252.95 feet to the True Point of Beginning of the easement described herein; thence N58'58'22"E a distance of 643.67 feet; S28'36'46"E a distance of 628.64 feet; thence S35'39'45"W a distance of 693.43 feet; thence N29'46'48"W a distance of 902.69 feet to the point of beginning, containing 11.18 acres more or less. V 'i11ia m, PRODurnOH 1058 COUNTY ROAD 215 PARACHUTE, COLORADO, 81635 SCALE: 1"=300' DATE: 11/09/05 DWG: PHARRETT1 PC0P3_LEGAL NOV. 33-2005 : 49 1 WILLIAMS PROD RMT Corporate Data Sheet Report I'!U'. 7i r.�.. As of 21612003 • Williams Production RMT Company -_,-- Joseph P. Barrett Assistant Secretary SIF-- 8/2/2001 8/2/2001 8/1/2002 Tom E. Blaclr. Assistant Secretary 8/2/2001 8/2/2001 8/1/2002 Suzanne H. Costiu Assistant Secretary 11/21/2002 11/21/2002 11/21/2002 Craig L. Rainey Assistant Secretary 8/2/2001 8/2/2001 8/1/2002 Patti E. Rives Assistant Secretary 8/2/2001 8/2/2001 8/1/2002 Deborah. Viehdorfer Assistant Secretary 8/2/2001 8/2/2001 8/1/2002 Securities Equity Common Stock Date First Authorized: 5/4/2001 Date Cancelled: Data First Issued; 5/4/2001 Par Value: Authorized Capital; # Authorized: 1,000 Exchange Listing: fe Outstanding: 1,000 Transfer Agent: # Issued: 1,000 CUSIP: # in Treasury: Syrnbol: # Cancelled: Comment: current Owner(s) Williams Production Holdings LLC Beneficial Ownership; Value of Consideration: Consideration; Comments: Certificate No. •1. Ownership # Units 3 cjr i ransrrdred 100% 1,000.00 7/30/2002 Former Owners) Certificate No. % Ownership # Units ThWiiiaras Companies, Inc. Beneticlat Ownership: Value of Consideration: Consideration: Comments: Direct subsidiaries S1,000_00 i ?PIRNag or L,$teeender 100% 1,000.00 8/2/2001 7/30/2002 Registered in %Ownership Units Held Bargatb. Inc. Colorado 100.000 % 1.000.J Barrett 1997 Trust Delaware 1.000 °/o Barrett Fuels Corporation Delaware 100.000 % 100 _ BarrettRahources Inte'n Corporation DelawareAO&% 1.000 NOV.30.2005 a:49AM WILLIAMS PROD RMT Corporate Data Sheet Report e Williams Production RMT Company Nn. 7Si P.3/5 As of 216/2003 Incorporation: Delaware (5/4/2001) Status: Current Phone #: Entity Type: Corporation Fax #: Federal ID #: 73-1613076 Internal#: Corporate Comment: Name changed from Resources Acquisition to Williams Production RMT Company on 8/212001 in the purchase of Barren Resources Tax Year End: Employees: No Fiscal Year End: Annual Mooting Date: 8/7/2003 Domestic True International False Canadian Entity Federal False Canadian Entity- Provincial False primary Address 1515 Arapahoe Street Tower 3 Suite 1000 Denver, CO 80202 Former tamo(s) Start Date End Dato Resources Acquisition Corp. S/4/2001 &; 2.2001 Directors Currently Authorized: Minimum: Maximum: Quorum: Classes: Title Effective First Elected Last Elected Ralph A. Hill Director 5/4/2001 5/4/2001 8/1/2002 Steven J. Malcolm Director 5/4/2001 5/4/2001 8/1/2002 Phillip D, Wright Director 12/1(2001 12/1/2001 8/1/2002 Officers Title Effective First Elected Last Elected Phillip D. Wright President 12/1/2001 12/1/2001 8/1/2002 Ralph A. Hill Senior Vice President 5/42001 5/4/2001 8/1/2002 Neal A. Buck Vice President 8/2/2001 8/2/2001 8/1/2002 Bryan K Guderian Vice President 5/4/2001 5/412001 8/1/2002 Mark W, Husband Vice President 8/1/2001 8/1/2001 8/1/2002 Joseph N. Jaggers III Vice President 8/2/2001 8/2/2001 8/1/2002 James G. Ivey Treasurer 5/4/2001 5/4/2001 8/1/2042 Landy L. Fullmer Controller & Assistant Treasurer 8/212001 8/2/2001 8/1/2002 n rr ne ., e+,.....r,..., 11 r1I17nn/ 1 1 /710061 7 101 /2002 NOV .30.2005 8:50AM WILL IAMS PROD RMT NO. 791 P.4/5 Corporate Data Sheet Report As of 2/6/2003 11, Williams Production RMT Company Bison Royalty LLC Delawarc 100.000 Piceance Production Holdings LLC Delaware 50.000 % Plains Petroleum Gathering Company Delaware 100.000 % 10,000 Ruligon Gas Company, LLC Colorado 100.000 % Rulison Production Company LLC Delaware 100.000 % Direct Owners Williams Production Holdings LLC Registrations Colorado Registered In %Ownership Units Held Dclawar 100.000 °- Charter No. Tax ID No. Date End Date Duration Qualification 7/16'2001 Perpetual Agent: The Corporation Company Comments: Resources Acquisition Corp. qualified 7/16/2001. Quelifcatiorx was amended in the name of Williams Production RMT Company on 8/14/2001. Delaware incorporation Agent: The Corporation Trust Company comments: IIIKansas Qualification Agent: The Corporation Company, Inc. Comments: Louisiana Qualification Agent: C T Corporation System Comments: Montana Qualification Agent: C T Corporation System Comments: New Mexico Qualification Agent: C T Corporation System Comments: North Dakota Qualification Agent; C T Corporation System Comments: Oklahoma Qualification Agent: Tho Corporation Company Comments: Texas Qualification Agent: C T Corporation System Comments: Utah Qualification 5/4/2001 7/18/2001 8/13/2001 8/29/2001 12/11/2001 8/1/2002 8/17/2001 8/13/2001 8/15/2001 NOV. 30.2005 8:50AM WILLIAMS PROD RMT NO.791 Corporate Data Sheet Report P.5/5 As of 2/512003 II Williams Production RMT Company Agent: C T Corporation System. Comments: Wyoming Qualification Agent: C T Corporation System • History 7123/2001 Perpetual Comments: Resources Acquisition Corp. was qualified an 7/23/2001. Qualification was amended in the name of Williams Production IMT Company on 8(14/2001. 2/2872001 Meir ed Mer•er On February 28, 2001 Plains Petroleum Company, a Delaware corporation, Plains Petroleum Operating Company, a Delaware corporation. merged with and into Barrett Resources Corporation. 8/212001Other Name Change Name changed from rtisources Acquisition Corp, to Williams Production RMT Company 81212001 Merged Merger Barrett Resources Corporation merged with and into Resources Acquistion Corp. under the name of Williams Production RMT Company. Generated: 2/6/2003 240.19 PM Page 4 of NOU.30.2035 9:47AM WILLIAMS PROD RMT ' N0.790 P.2/3 Corporate Data Sheet Report Bargath Inc. Incorporation: Status: Entity Type: Federal ID #: Corporate Comment: Tax Year End: Fiscal Year End: Annual Meeting Date: Canadian Entity Federal Canadian Entity Provincial Prlmary Address As of 1/17/2005 Colorado (6130/1.986) Current Corporation 84-1032091 Phone #:. Fax #:. Internal #: This entity cannot be dissolved due to a restriction in the Williams Production ltlriT Company Credit Agreement with Lehman. Employees: No False False One Williams Center Tulsa, Oklahoma 74172 (United States) Bylaws Information Purpose of Business! Location of Minute Books: Location of Seal: directors Currently Authorized; Ralph A.. Hill Steven J. Malcolm Officers Ralph A. Hill Neal A, J3uck Bryan K Guderian Mark W. Husband Joseph N. Daggers 111 Travis N, Campbell Brian 1C. Shore —Ow Joseph P. Barrett Tom E. Black Landy L. Fullmer Craig L. Rainey Minimum: Title Director Director Title Maximum: Senior Vice President Vice President Vice President Vice President Vice President Treasurer Secretary Assistant Secretary 4— ASsistant Secretary Controller & Assistant Treasurer Assistant Secretary r Quorum: Effective First Elected 8/2/2001 8/212001 8/2/2001 8/2/2001 Classes; Last Elected 8/2/2001 8/2/2001 Effective First Elected Last Elected 8/2/2001 8/2/2001 8/2/200I 8/2/2001 8/2/2001 8/2/2001 8/2/2001 8/2/2001 8/2/2001 8/2/2001 11/2012003 11/20/2003 11/2112002 11/21/2002 8/2/2001 8/2/2001 8/2/2001 8/2/2001 8/2/2001 8/2/2001 8/2/2001 8/2/2001 8/2/2001 8/2)2001 8/2/2001 8/2/2001 8/2/2001 8/2/2001 8/2/2001 11/20/2003 11/21/2002 8/2/2001 8/2/2001 8/2/2001 8/2/2001 €i00-1 r • • NOV .38.20©5 8:47AM WILLIAMS PROD RMT NO.798 R.-3/1 Corporate Data Sheet Report As of 1117/2005 Bargath Inc. Deborah Viehdorfer Direct Subsidiaries Fort Union Gas Gathering, L.L.C. Direct Owners Assistant Secretary Williams Production RMT Company Registered in Delaware Registered In 8/2/2001 8/2/2001 51212001 %Ownership Units Meld 10 000 % Ownership Units Held 100.000 °A 1,000 Registrations Charter No. Tax ID No. Date End Date Duration Colorado Incorporation 613011986 Agent: The Corporation Company Oklahoma Qualification FB00567130 5/6/1996 Agent: The Corporation Company Utah Qualification 5/6/1996 Agent: C T Corporation System Wyoming Qualification #553893 12/12/2000 Agent: C T Corporation System History 4/12/1996 Merged Merger Grand Valley Corporation, a Kansas corporations merged with and into Bargath, Inc. 619/1999 Merged Merger Consent of Sole Shareholder, Bargath Inc,, approved the Agreement and Plan of Merger with Bargath Inc. and Alarado (Denver) Company, a Delaware Corporation, wholly owned subsidiaries of Alarado Corporation, a Delaware corporation, a wholly owned subsidiary of Barrett. 5/19/2000 Merged Merger Parachute Mountain, Inc., a New Mexico corporation, a wholly owned subsidiary of Barrett merged with and into Bargath Inc. 11/5/2004 Merged Merger Rulison Gas Company, LLC, a Colorado limited liability company, a holding company wholly owned by Williams Production RMT Company. was merged into Bargath, Inc. • • STATE OF COLORADO County of Garfield 1111111111111111111111111111111111111111111111111 666856 01/11/2005 02:22P B1655 P230 M ALSDORF 1 of 5 R 0.00 D 0.00 GARFIELD COUNTY CO ) )ss At a regular meeting of the Board of County Commissioners for Garfield County, Colorado, held in the Commissioners' Meeting Room, Garfield County Courthouse, in Glenwood Springs on, Monday, the 3"i day ofJannary A.D. 2005, there were present: John Martin Larry McCown TresiHaupt Don DeFord Mildred Alsdorf Ed Green _ • Commissioner Chairman , Commissioner , Commissioner , County Attorney , Clerk of the Board , County Manager when the following proceedings, among others were had and done, to -wit: RESOLUTION NO. 2005-09 A RESOLUTION CONCERNED WITH THE APPROVAL OF A SPECIAL USE PERMIT APPLICATION FOR AN INDUSTRIAL SUPPORT FACILITY TO INCLUDE PROCESSING AND A PIPELINE WHEREAS, the Board of County Commissioners of Garfield County, Colorado ("Board"), has received an application from Williams Production Co. RMT, for a special use permit ("SUP") to allow for a Industrial Support. Facility to Include Processing and a Pipeline within the RiL (Resource Lands); and WHEREAS, the special use is located at 4289 County Road 215, 4 miles north ofParachute, also in Section 4, Township 7 South and in Sections 27, 28, 29, 32, 33 and 34 Township 6 South all in Range 96 west of the 6th Principle Meridian, Garfield County, Colorado; and WHEREAS, the Planning Commission held a public hearing on the 8th day of December, 2004, at the request of the Board upon the question of recommendation with conditions of approval for the above described SUP to then be directed to the Board, and at that hearing the public and interested persons were given the opportunity to express their opinions concerning the approval of said SUP; and WHEREAS, REAS, the Board held an initial public hearing on the 20th day ofDecember, 2004, upon the question of whether the above described SUP should be granted or denied, at which hearing the public and interested persons were given the opportunity to express their opinions concerning the approval of said SUP, and where the public hearing was continued by the request of the Applicant; • 11111111111111111111111111111111111111111 uiu 1111 iui 566856 01/11/2005 02:22P 61655 P231 M ALSDORF 2 of 5 R 0.00 D 0.00 GARFIELD COUNTY CO and WHEREAS, the Board opened and continued the public hearing on the 3`d day of January, 2005, upon the question of whether the above described SUP should be granted or denied, at which hearing the public and interested persons were given the opportunity to express their opinions concerning the approval of said special use permit; and WHEREAS, the Board on the basis of substantial competent evidence produced at the aforementioned hearing, has made the following determination of fact as listed below: 1. Proper posting and public notice was provided as required for the meeting before the Board of County Commissioners. 2. The meeting before the Board of County Commissioners was extensive and complete, that all pertinent facts, matters and issues were submitted and that all interested parties were heard at that meeting. 3. The above stated and other reasons, the proposed special use permit has been determined to be in the best interest of the health, safety, morals, convenience, order, prosperity and welfare ofthe citizens of Garfield County. 4. The application has met the requirements of Special Use (Sections 5:03, 5:03:07, 5:03.08 411 and 9:03) the Garfield County Zoning Resolution of 1978. NOW THEREFORE, BE IT RESOLVED by the Board of County Commissioners of Garfield County, Colorado, that Special Use Permit is hereby approved subject to compliance with all ofthe following specific conditions: 1. All representations of the Applicant, either within the application or stated at the meeting before the Board of County Commissioners, shall be considered conditions of approval, unless specifically altered by the Board. 2. The Applicant shall comply with all applicable requirements of the Garfield County Zoning Resolution of 1978, as amended. 3. The Applicant shall comply with all State and Federal regulations and standards, concerning Noise Abatement, Water and Air Quality. 4. Vibration, emission of smoke and particulate matter, and the emission of heat or radiation shall comply with applicable Federal, State, and County laws, regulations and standards. 5. Any signage installed on-site shall comply with the County's sign regulations. 6. Any changes to the Special Use Permit for all uses as listed in the application as amended 2 Williams Production RMT Parachute Creek Gas Plant Expansion BOCC 113/05 • 1111111 11111 1111111 ilii 11111111111111111111111111111111 666856 01/11/2005 02:22P B1655 P232 M PLSDORF 3 of 5 R 0.00 D 0.00 GARF IELD COUNTY CO from previous approvals and the exhibits as attached shall require a new Special Use Permit. 7. The Applicant shall respond to any alleged complaint regarding debris, trash or other materials deposited by and associated with the proposed use outside ofthe fenced area and on private or public land within 24 -hours of the initial complaint. 8. The Applicant shall make all improvements which address the concerns of the Garfield County Road and Bridge Department regarding the application of paint striping to CR 215 and the installation of appropriate directional and safety signage. Said department shall respond to the County Building and Planning Department in writing when their concerns have been satisfied. These improvements shall be done prior to the 6 month SUP review as noted in condition 18 noted later in these conditions. 9. The Applicant shall paint the proposed use structures with non -reflective Desert Brown paint as proposed in the application prior to the 6 month SUP review as noted in condition 18 noted later in these conditions. 10. The proposed use shall be fully enclosed by an 8' tall chain link fence at the perimeter ofthe plant and it shall connect directly into the existing chain link fence that surrounds the existing plant. A Building Permit will be required for the exterior 8' fence which shall be erected prior to the 6 month SUP review as noted in condition 18 noted later in these conditions. S 11. As per Garfield County Regulations and COGCC rule 803, the Applicant shall maintain that all site lighting shall be pointed downward and inward to the property center and shaded to prevent direct reflection on adjacent property. • 12. A Revegetation bond is be required by Garfield County for the new and existing plant site totaling approximately 20 acres of surface disturbance and a security in the amount of $20,000 ($1,000/acre) shall be secured by Garfield County prior to issuance ofthe SUP. The security shall be held by the County until vegetation has been successfully reestablished. according to the Reclamation Standards in the Garfield County Weed Management Plan. 13. The Grand Valley Fire Protection District (GVFPD) shall review the proposed use and respond in writing to the Garfield County Building and Planning Department noting that all concerns of the District have been met. This shall be done prior to the 6 month SUP review as noted in condition 18 noted later in these conditions. 14. When the current special use is abandoned, the Site Rehabilitation Plan which is highlighted in this report and found in the application shall be followed and shall be applied to the reclamationofall previous uses permitted as SUP's #1981-14, #1981-100, #1980-11, #1992- 101 and #2002-67; including but not limited to removal and reclamation of water tanks, internal roads, pipelines, concrete pads and foundations, utility drops, RV hook-ups and other facilities. The Applicant affirms that these requirements rest with the land and that the applicant shall make these requirements known to any heirs, assigns or purchasers of property 3 Williams Production R? Parachute Creek Gas Plant Expansion BOCC 113/05 111E1 111111 1111111IIII 111 VIII II II III VIII IIII IIII 666856 01/11/2005 02:22P B1655 P233 M ALSDORF 4 of 5 R 0.00 D 0.00 GARFIELD COUNTY CO subject to this Special Use Permit. 15. The Applicant has proposed five (5) new buildings for the plant expansion. These buildings are proposed for maximum sizing and may be constructed in smaller dimensions. The Applicant has provided the Building and Planning Department with an updated final "site plan" which indicates the locations of the aforementioned 5 buildings. 16. The Applicant shall implement and properly manage (1) the "Stormwater Management Plan" and (2) the "Spill Prevention Control and Countermeasures Plan" as prepared by Cordillerian Compliance Services Inc. as submitted in the application throughout the life ofthe proposed use. tiftk Ulv (41LL 17. If the proposed use allegedly produces a v lume of sound which violates noise standards as set forth in the Colorado Revised Statute the Applicant shall hire an acoustical engineer, measure the amount of noise, and if in violation implement proposed mitigation measures of the nuisance noise within 60 days 18. Additionally, as per section 9.03.05 which allows Periodic Review, the Special Use Permits shall be made subject to a review at six (6) months from the date of Issuance of the Special Use Permit. The purpose of such review shall be to determine compliance or noncompliance with any performance requirements associated with the granting of the Special Use Permit. Such review shall be conducted in such manner and by such persons as the County Commissioners deem appropriate to make the review effective and meaningful. Upon the completion of the review, the Commissioners may determine that the permit operations are in compliance and continue the permit, or determine the operations are not in compliance and either suspend the permit or require the permittee to bring the operation into compliance by a certain specified date. If a determination is made that the Permit shall be modified or revoked, a Public Hearing shall be scheduled as per the County regulations at such time to proceed with said action. Such periodic review shall be limited to those performance requirements and conditions imposed at the time ofthe original issuance ofthe Special Use Permit. 4 Williams Production R IT Parachute Creek Gas Plant Expansion l3OCC 1!3/05 • 1111111111 iIlIll lll 1111 111111111111 Ill 111111111 lilt 666856 01/1112005 02:22P B1655 P234 M ALSDORF 5 of 5 R 0.00 D 0.00 GARFIELD COUNTY CO Dated this 1 Oth ATTEST: day of January vote: , A.D. 2005 . GARFIELD COUNTY BOARD OF COMMISSIONERS, GARFIELD COUNTY, COLORADO Upon motion duly made and seconded the foregoing • esolu '. n as adopted • a+e following COMMISSIONER CHAIR JOHN F. MARTIN , Aye COMMISSIONER LARRY L. MCCOWN , Aye COMMISSIONER TRESI HOUPT , Aye • STATE OF COLORADO ) )ss County of Garfield ) I, , County Clerk and ex -officio Clerk of the Board of County Commissioners, in and for the County and State aforesaid, do hereby certify that the annexed and foregoing Resolution is truly copied from the Records of the Proceeding of the Board of County Commissioners for said Garfield County, now in my office. IN WITNESS WHEREOF, I have hereunto set my hand and affixed the seal of said County, at Glenwood Springs, this day of , A.D. 20 County Clerk and ex -officio Clerk of the Board of County Commissioners MINIMS Pnxtuction RMT Parachute Creek Gas Plant Expulsion [OCC 1/3/05 PVCMI Land Planning Division 1038 County Road 323 Rifle, CO 81650 Ph. 970-625-5350 Fax 970-625-4522 Email: pvcm@direcway.com Project: Williams Production RMT Co.- Parachute Creek Gas Plant Expansion. Phase 3 Submittal Item Number: 3a. Water System A. Domestic- Non -Potable Water Use: A proposed 5,000 gallon tank will be placed near the new Office/Warehouse building to be constructed in Phase 3. This non -potable water is brought on-site by a water truck. The source of the water is the Town of Parachute. Please find attached an agreement with Toby's Vacuum Truck Service, Inc. for water for domestic use in the plant and for construction use. Non -potable water is used for the 2 toilets, 2 lavatory sinks and the emergency shower. Please find attached a report from John Withers P.E. with Geotechnical Engineering Group, Inc. noting that the 5,000 gallon tank and system is sized for the expansion of the plant and addition of 10 new employees within the Office/Warehouse Building. B. Domestic- Potable Water: Potable water is supplied to the plant via Mountain Clear in 5 gallon bottles. The above information illustrates that the existing water supply via Toby's Vacuum Truck Service, Inc. provides adequate legal and physical water to serve the plant expansion. Please contact me with any questions. Sincerely, Philip B. Vaughan President PVCMI Page 1 of I CONTRACT FOR WATER SUPPLY THIS CONTRACT FOR WATER SUPPLY made this ?. , day of tkce { r 2005. ("Effective ate") by and between Toby's Vacuum Truck Service, Inc. ("TOBY") and Williams Production MT Company ("Williams"), is predicated on the following: WHEREAS, Toby is in the business of providing water to third parties for construction and. domestic purposes; and. WHEREAS, Williams is constructing the Parachute Creek Gas Processing Plant Expansion Phase 3 ("PCGP Plant Expansion Ph. 3") and as a result of such construction, will require water for hydrostatic testing of pipe, dust suppression and soils compaction during the construction and for domestic non -potable purposes for personnel. WHEREAS, Toby has agreed to supply water to Williams for hydrostatic testing and dust suppression during construction of the PCGP Plant Expansion Ph. 3 and for domestic non - potable purposes for personnel during the Term of this Agreement; NOW, THEREFORE, for and in consideration of the promises and agreements herein provided, the parties hereto agree as follows: 1. TOBY will provide to Williams approximately ten (10) acre feet of water for Williams use in hydrostatic testing of pipe, dust suppression and soils compaction during construction of the PCGP Plant Expansion Ph. 3. Additionally, TOBY will provide to Williams approximately 7,500 gallons of water a week for domestic non -potable purposes for personnel for a period of 20 years. TOBY shall 40upply all water required and requested by Williams. 2. TORY agrees to provide a copy of this Agreement to the Garfield County Planning Department as evidence of a project water supply in an entitlement proceeding in which Williams is currently engaged. 3, TOBY will transport and deliver the water to the PCGP Plant Expansion Ph. 3 pursuant to Williams instructions. 4. As consideration for the foregoing Agreement Williams agrees to pay to TOBY $200 per acre foot of water actually used on a monthly basis within thirty (30) days receipt of an invoice showing the amount of water supplied in the previous month. Furthermore, Williams agrees to pay TOBY delivery and gallonage fees as per the most current TOBY rate schedule during the period of this contract for domestic non -potable purposes for personnel. 5. This Agreement shall have a term of twenty (20) years („Term") unless extended by mutual agreement of the parties. 6. TOBY represents and warrants that the water supplied shall be of the quality required by Williams' for Williams' needs. 7. This Agreement shall be governed by the laws of the state of Colorado, without regard to the conflict of laws provisions. Page 1 of 2 The within Agreement shall be binding upon the parties hereto, their successors and assigns. ikoby's Vacuum Truck Service, Inc, By '-1 ty-).4 f 0764(.4._, Robert B. LeBorgne, Owner Williams Production RMT Company By SfTi.).)4, Steve Soychak, Distr. Manager Page 2 of 2 • • • Geotechnical lk,Engineering Group, Inc, NON POTABLE WATER SYSTEM DESIGN Office ! Warehouse Building Williams Gas Facility No. 3 County Road 215, South of Starkey Gulch Garfield County, Colorado Prepared For: Williams Production RMT Company Mr. Eric Miller P.O. Box 370 Parachute, CO 81635 Job No. 2,164 November 8, 2005 Geotechnical, Environmental and Materials Testing Consultants Grand Junction - Montrose - Moab - Crested Butte (970) 245-4078 • fax (970) 245-7115 • geotechnicalgroup.corn 2308 Interstate Avenue, Grand Junction, Colorado 81505 • • • TABLE OF CONTENTS SCOPE 1 SUMMARY OF CONCLUSIONS 1 SITE CONDITIONS 1 PROPOSED CONSTRUCTION 2 NON POTABLE WATER SUPPLY SYSTEM DESIGN CALCULATIONS... 3 OPERATION AND MAINTENANCE 4 LIMITATIONS 4 FIG. 1 - VICINITY MAP FIG. 2 - SITE PLAN / LOCATION OF NON POTABLE WATER SUPPLY FIG. 3 -CROSS SECTION OF NON POTABLE WATER SUPPLY SYSTEM • • • SCOPE This report presents the results of a Non Potable Water System Design for the proposed Office / Warehouse Building of the Williams Gas Facility No. 3 at County Road 215, south of Starkey Gulch (Parachute Creek) in Garfield County, Colorado. The report includes design and construction criteria for the proposed non potable water supply system. This report was prepared as continuing services, in general conformance with our Proposal No. 04-101, dated June 4, 2004. SUMMARY OF CONCLUSIONS The anticipated non potable water supply will require a holding tank volume of at least 5,000 gallons based on average design flow or 7.500 gallons based on peak design flow for a 7 day supply. Detailed design, and installation recommendations are included in the text of this report. 2. Geotechnical Engineering Group, Inc. should be called to observe and document system installation, prior to backfill. SITE CONDITIONS The subject site was located approximately 4 miles northwest of Parachute, Colorado, south of Starkey Gulch (Parachute Creek) and west of County Road 215. Fig. 1. The subject site was located north and west of an existing gas production facility on Non Potable Water Supply Office !Warehouse Building Williams Parachute Creek Plant 3 1 • • • vacant, undeveloped land. Low indigenous and non -indigenous vegetation was noted across the site. The facility No. 3 site was gently undulating and generally sloped down toward the southwest at 3 to 6 percent (measured with handheld rangefinder and hand level). Man Camp Road was southeast of the site; the previously mentioned gas production facility was beyond. Parachute Creek, undeveloped land and steeper upslopes of the valley sidewalis were southwest. Undeveloped land was northwest. County Road 215 was north and east of the site with steeper valley sidewalls beyond. The vicinity sloped down toward the valley bottom; the valley bottom sloped down toward the southeast at less than 1 percent (USGS Parachute, Colorado Quadrangle, 1962). PROPOSED CONSTRUCTION We understand the proposed non potable water supply system will serve, 2 toilets and 2 lavatories. There will be no showers. We understand there will be a maximum of 12 full time employees that will use the building. Potable water will be supplied by an outside vender and not included by this design. The proposed non potable water supply system location is shown on Fig. 2. Site grading plans indicate a fill bench located (plant) north of the proposed building, approximately 8 feet above the ground level. It is desired to place the holding tank on the upper bench in order to help assist gravity flow. A pressure assist pump may be required if gravity flow is not adequate. If proposed Non Potable Water Supply Office! Warehouse Building Williams Parachute Creek Plant 3 2 • • • construction is different from what is stated, we should be contacted to review actual construction and our recommendations. NON POTABLE WATER SUPPLY SYSTEM DESIGN CALCULATIONS Calculations and design parameters used to size the holding tank follow: Average flow Calculation 2 toilets 24.8 g/p/d x 2 = 49.6 g/p/d 2 Lavatories 4.4 glp/d x 2 = 8.8 g/p/d total = 58.4 g/p/d x 12 employees = 700.8 gallons/day Peak flow = 150% of average = 1,051.2 gallons/day ‘,/ Design Volume based on average flow and 7 days =7 X 700.8 = 4,905.6 gallons = 5,000 gallons Design Volume based on peak flow and 7 days = 7 X 1,051.2 = 7,358.4 gallons = 7,500 gallons A cross section showing system layout is included as Fig. 3. Non Potable Water Supply Office 1 Warehouse Building Williams Parachute Creek Plant 3 7 • • • OPERATION AND MAINTENANCE Performance of the subject non potable water supply system will be dependent on suitable operations and maintenance practices. The owner must understand and accept responsibility for operations and maintenance of the system. Important factors include: 1. The owner should install a structural barrier if necessary and take precautions to prevent vehicular traffic or other activities in the vicinity of the holding tank which may lead to damages. 2. The owner should plant and maintain grass or other shallow rooted cover crop to prevent erosion. 3. The owner should inspect and prevent intrusion of burrowing animals and deep rooted plants the holding tank area. LIMITATIONS Design notes contained in this report are based in part on assumptions regarding water usage and assumptions provided by client. Actual usage may be more or less. Geotechnical Engineering Group does not accept responsibility for variation in the assumed design parameters. The scope of work performed is specific to the proposed construction and the client identified by this report. Any other use of the data, recommendations and design parameters (as applicable) provided within this report are not appropriate applications. Non Potable Water Supply Office / Warehouse Building Williams Parachute Creek Plant 3 4 • • Other proposed construction and/or reliance by other clients will require project specific review by this firm. Changes in site conditions can occur with time. Changes in standard of practice also occur with time. This report should not be relied upon after a period of three years from the date of this report and is subject to review by this firm in light of new information which may periodically become known. We believe this design was conducted in a manner consistent with that level of care and skill ordinarily used by geotechnical engineers practicing in this area at this time. No other warranty, express or implied, is made. If we can be of further service in discussing the contents of this report or the analysis of the influence of the subsurface conditions on the design of the proposed construction, please call. REGIS,-. Sincerely, ®•°°� aa,�;'' GEOTECHNICAL EI eEIRi 4 }41P, INC. �34 • 30324 • (v n P. Withers, P.>.".. ase•a•'� Principal Engineer S. ' JPW:cb (3 copies sent) Non Potable Water Supply Office 1 Warehouse Building Williams Parachute Creek Plant 3 • • • Non Potable Water System Design Williams Gas Plant No. 3 County Road 215 and Mancamp Road Garfield County, Colorado f_. f`. Job No. 2,164 ow Mari, Camp p Road Location A �. � pp�o�i�ate - ;15519 rz, , r' ' Vicinity Map Fig. 1 • Proposed Building Septic Tank Relocate Dirt Road / 50' South f Absorbtion -Field 1 , •""- ,o " Future Repair Area 1 jII c- ai Co 0 co Job No. 2,164 Location of Sewage Disposal System Fig. 2 Assist Pump and Shut Of Valve Proposed Building Pad Elevation (5432') r_r Ground Surface Thrust Block • Job No. 2,164 Shut Off Valve/ Fill Port Soil Cap 2H:IV to 3H:IV Soil Mound. Minimum 18-24 Inches Cover. Pad Elevation f 4 (5440') Holding Tank 1 314'° Copper Water Line (Minimum 48 inch Burial) Scale 1"=10' Cross Section of Non Potable Water Supply • Fig. 3 • • Notes 1. Trench and backfill around structures shall be placed in 8" Lifts and compacted to at least 90% AASHTO T-180. 2. All Portland cement concrete shall be Colorado Department of Transportation Class "B". (Section 601.02). 3. Pipe shall be bedded in material with 100% passing 314" sieve and 20% maximum passing, No. 200 sieve. Native material may be used in lieu of granular bedding material if the native material is in compliance with size requiements noted. 4. All work shall be in accordance with approved plans and the standard specifications of Garfield County. • • Job No. 2,164 General Notes Fig. 4 • • PVCMI Land Planning Division 1038 County Road 323 Rifle, CO 81650 Ph. 970-625-5350 Fax 970-625-4522 Email: pvcm@direcway.com Project: Williams Production RMT Co.- Parachute Creek Gas Plant Expansion Phase 3 Submittal Item Number: 3b. Wastewater System The new office/warehouse building to be constructed during Phase 3 will have 2 toilets, 2 lavatory sinks and the emergency shower. Please find attached the following: A. Copy of the Sewage Disposal System Design produced by John Withers P.E. of Geotechnical Engineering Group, Inc. dated 11/7/05. Please contact me with any questions. Sincerely, Philip B. Vaughan President PVCMI Page 1 of 1 • Geotechnical ngineering E Group, Inc. SEWAGE DISPOSAL SYSTEM DESIGN Office I Warehouse Building Williams Gas Facility No. 3 County Road 215, South of Starkey Gulch Garfield County, Colorado Prepared For: Williams Production RMT Company Mr. Eric Miller P.O. Box 370 Parachute, CO 81635 Job No. 2,164 November 7, 2005 Geotechnical, Environmental and Materials Testing Consultants Grand Junction - Montrose - Moab - Crested Butte (970) 245-4078 • fax (970) 245-7115 * geotechnicalgroup.corn 2308 Interstate Avenue, Grand Junction, Colorado 81505 TABLE OF CONTENTS SCOPE 1 SUMMARY OF CONCLUSIONS 1 SITE CONDITIONS 2 PROPOSED CONSTRUCTION 3 SEWAGE DISPOSAL SYSTEM DESIGN 4 SUBSURFACE CONDITIONS ....4 DESIGN CONSIDERATIONS 5 DESIGN CALCULATIONS 6 PROPOSED DESIGN CONSTRAINTS 6 SYSTEM DESIGN 7 SYSTEM INSTALLATION'.......,..., 9 OPERATION AND MAINTENANCE 12 LIMITATIONS 13 FIG. 1 - VICINITY MAP FIG. 2 - SITE PLAN 1 LOCATION OF PROPOSED ABSORPTION SYSTEM FIG. 3 - ABSORPTION FIELD PLAN VIEW FIG. 4 - ABSORPTION FIELD CROSS SECTION APPENDIX A - LOGS AND LEGEND OF PROFILE TEST HOLE AND RESULTS OF PERCOLATION TESTING SCOPE This report presents the results of a Sewage Disposal System Design for the proposed septic system to be located at the Office / Warehouse Building of the Williams Gas Facility No. 3 at County Road 215, south of Starkey Gulch (Parachute Creek) in Garfield County, Colorado. Our services were conducted to provide design criteria for the proposed sewage disposal system. The report includes descriptions of subsoil and groundwater conditions found in one profile test pit, percolation testing results and design and construction criteria for the proposed sewage disposal system. The report was prepared from data collected from percolation testing and developed during engineering analysis and experience with similar conditions. This report was prepared as continuing services, in general conformance with our Proposal No. 04-101, dated June 4, 2004. SUMMARY OF CONCLUSIONS Subsurface conditions encountered in the proposed percolation field area consisted of sandy clay and clayey sand with variable gravelly and silty lenses noted. Groundwater was found in the area of the absorption field at depths of 10 to 20 feet. We used a design soils percolation rate of 60 minutes per inch for the proposed system area calculation. The proposed sewage disposal system for this site is an absorption field. We recommend a field of 24 feet by 103 feet dimension encompassing an area of 2.448 square feet. Detailed design, installation, and operations and Sewage Disposal System Design Williams Gas Facility No.3 Parachute Creek, Garfield County. Colorado GEG Job No. 2,164 • • maintenance recommendations are included in the text of this report. Geotechnical Engineering Group, Inc. and Garfield County Health Department should be called to observe and document system installation, prior to backfill. 4. An area located south- southeast of the proposed system is designated the "future repair area". This area should be set aside for potential septic system remediation. In no case should the proposed system area or future repair area be constructed with a structure or pavement. SITE CONDITIONS The subject site was located approximately 4 miles northwest of Parachute, Colorado, south of Starkey Gulch (Parachute Creek) and west of County Road 215, Fig. 1. The subject site was Located in a northwest and southeast oriented valley bottom. Steeper slopes were noted along the sides of the valley. The subject site was located north and west of an existing gas production facility on vacant, undeveloped land. Low indigenous and non -indigenous vegetation was noted across the site. The facility No. 3 site was gently undulating and generally sloped down toward the southwest at 3 to 6 percent (measured with handheld rangefinder and hand level). Northwest -southeast trending irrigation type risers (dry at the time of our visit) were noted crossing the central portion of the facility No. 3 site. Smaller gas production structures were noted near the north, east and west portions of the site. An earth bermed ditch was noted near the north and east portion of the site. The ditch was approximately 15 to 20 feet wide and 5 to 7 Sewage Disposal System Design Williams Gas Facility No.3 Parachute Creek, Garfield County, Colorado GEG Job No, 2,164 2 • feet deep. Water in the ditch was flowing toward the south. An open excavation near the west portion of the site was 4 to 10 feet wide, more than 180 feet long and approximately 8 to 12 feet deep. The excavation sidewalls indicated clay type soils. Man Camp Road was southeast of the site; the previously mentioned gas production facility was beyond. Parachute Creek, undeveloped land and steeper upslopes of the valley sidewalls were southwest. Undeveloped land was northwest. County Road 215 was north and east of the site with steeper valley sidewalls beyond. The vicinity sloped down toward the valley bottom; the valley bottom sloped down toward the southeast at less than 1 percent (USGS Parachute, Colorado Quadrangle, 1962). PROPOSED CONSTRUCTION We understand the proposed construction will contain 2 showers, 2 toilets and 2 lavatories. We understand there will be a maximum of 12 full time employees that will use the building. The proposed sewage disposal system (SDS) location is shown on Fig. 2. A log of the profile test hole and percolation testing are included in Appendix A. If proposed construction changes or is different from what is stated, we should be contacted to review actual construction and our recommendations. Sewage Disposal System Design Williams Gas Facility No.3 Parachute Creek, Garfield County, Colorado GEG Job No. 2,164 • s • SEWAGE DISPOSAL SYSTEM DESIGN Subsurface Conditions Subsurface conditions at the site were investigated by drilling and sampling nineteen exploratory borings. Borings TH-18 and TH-19 were in the area of the proposed absorption field. Locations of the exploratory borings are shown in Appendix A on Fig. 2. Graphic logs of the soils found in the borings and field penetration resistance tests are presented in Appendix A on Figs. 7 and 8. Subsurface conditions encountered included up to 67 of sandy clay underlain by clayey gravel to the maximum depth explored of 78 feet. The sandy clay had clayey gravelly sand and sandy, silty clay lenses, was medium stiff to very stiff, dry to wet and brown. This soil had an appearance of ancient landslide / sheet flow type deposition and sulfates noted. Groundwater was encountered at 15.5, 26 and 32 feet below the ground surface on the day of drilling in exploratory borings TH-1. TH-2 and TH-16 (respectively). Percolation Testing Percolation testing was performed on August 24 and 25, 2005 in percolation holes P-1 through P-3. A profile boring was observed at TH-19. Locations of profile boring TH- 19 and P-1 through P-3 are shown in Appendix A on Fig, 2. Three percolation holes were augered to depths of 4 feet below existing grade and prewetted on August 24. 2005. Sewage Disposal System Design Williams Gas Facility No.2 Parachute Creek, Garfield County, Colorado GEG Job No. 2,164 • • • A small drainage (dry at the time of our visit) was noted more than 100 feet southwest of the proposed septic area. No other water sources were identified within 300 feet of the area of the proposed septic system. Results of the percolation testing are included in Appendix A on Figs. 16 through 18. Subsurface conditions encountered in the profile hole (TH-19) consisted of 8 feet of sandy clay to the maximum depth explored of 8 feet below the ground surface. Groundwater was not identified in the profile to the maximum depth observed. We estimate a high seasonal groundwater level of 7 feet below the ground surface. Percolation test results ranged between 20 minutes per inch to time intervals which did not measurably percolate. Groundwater was not identified in the boring to the maximum depths observed. Many of the percolation readings were 40 minutes per inch. We used a design percolation rate of 60 minutes per inch in calculations. Design Considerations Based on our site observations and percolation testing, we believe an absorption bed system can perform satisfactorily for the proposed system. Consideration should be given to the lowest floor level in order to help insure flow without the need for a lift station. Sewage Disposal System Design Williams Gas Facility No.3 Parachute Creek, Garfield County, Colorado GEG Job No, 2,164 • • • DESIGN CALCULATIONS Calculations and design parameters used to size the absorption field follow: Proposed Design Constraints Average flow Calculation 2 showers 14.7 g/p/d x 2 = 29.4 g/p/d 2 toilets 24.8 g/p/d x 2 = 49.6 g/p/d 2 Lavatories 4.4 g/p/d x 2= 8.8 g/p/d total = 87.8 g/p/d x 12 employees = 1,053.6 gallons/day Peak flow = 150% of average = 1,580.4 gallons/day Design percolation rate = 60 minutes/inch A = t; where, t = Percolation rate (minutes/inch) Q = Peak flow A = Absorption field area 1580.4 A = 5 60 = 2,448 square feet (Design dimension = 24 x 102 feet = 2,448 square feet) Sewage Disposal System Design Williams Gas Facility No.3 Parachute Creek, Garfield County, Colorado GEG Job No. 2,184 • SYSTEM DESIGN For purposes of design, we estimate a high seasonal groundwater 7 feet below the ground surface. The gravel absorption bed system should be placed 2 foot below the existing ground surface. A minimum tank size of 1,976 gallon septic tank is required to accept septic effluent from the proposed system (based on a minimum detention time of 30 hours). A larger, readily available, tank size may also be used (such as 2,000 gallon). A removable, cleanable septic tank filter should be installed at the outlet. As discussed above, a gravel absorption bed system is proposed to discharge septic effluent to the underlying subsoils. The design absorption field will be 24 feet by 102 feet in lateral dimension and encompass an equivalent area of 2,448 square feet.. IP2, A 12" grave) seepage bed will be placed over the absorption area, The grave) seepage bed shall consist of 1.0" — 2.5" screened rock with individual aggregate components of uniform size. Four inch perforated effluent discharge lines will be embedded in the gravel seepage bed with a minimum of 6" of gravel under, and 2" of gravel over each line. The bottom of the gravel bed shall be at least 1 foot below the existing ground surface. Deeper depths may be required. • 3. The piping system should consist of two laterals of four inch perforated effluent discharge fines, 96 feet in length. Details of the system are included on Figs. 2 through 4, attached. After the gravel seepage bed is installed, synthetic filter fabric (140-200 mesh), hay, or untreated building paper should be placed over the gravel and the system covered with a soil cap. The soil cap should consist of 18 - inches to 24 -inches of native soil mounded 5% to promote surface run off away from the absorption area. Consideration must be given to provide positive drainage away from the completed absorption field in each direction. Sewage Disposal System Design Williams Gas Facility No.3 Parachute Creek, Garfield County, Colorado GEG Job No. 2,164 Sidewall construction of the soil cap from the perimeter of the absorption field to the existing ground surface shall consist of: • removing surface vegetation and scarifying or disking the existing ground surface under the basal extent of the soil cap sidewall to enhance subsurface absorption, followed by; • maintaining a maximum backslope of 3 horizontal to 1 vertical (33%) from the resulting perimeter elevation to the existing ground surface to reduce erosion. All relevant setbacks with respect to the absorption field shall be taken from the toe of the surface cap rather than the gravel seepage bed. The area located south-southeast of the proposed absorption system is designated the future repair area, see Fig. 2. The future repair area should be set aside for potential septic system remediation. In no case should this area be constructed with a structure. The same set back and grade requirements apply to the future repair area as the absorption system area. Eighteen inches to 24 inches of soil cover is recommended for all SOS elements (excepting maximum 8 inches soil cover over septic access ports) to mitigate frost concerns. The installer should confirm the feasibility of gravity discharge of sewage effluent from the residence to the absorption field. If field measurements do not confirm the design assumptions, gravity discharge of sewage effluent from the existing residence to the absorption field can not be assured and a lift pump may be required. Please contact the design engineer and Garfield County Health Department to address any design modifications necessary for effective operation of the SDS if the above design assumptions are not upheld. Sewage Disposal System Design Williams Gas Fatuity No.3 Parachute Greek, Garfield County, Colorado GEG Job No. 2,154 The installer must also confirm the setbacks from property Cines, building envelopes, and existing easements shown in the attached graphics are maintained. Additionally, any unknown utility lines, easementsor other adverse conditions disclosed during construction must maintain the required setbacks. The proposed residence must be located to maintain required SDS setbacks as well as provide compliance with Garfield County Planning Department zoning setbacks. Finally, implementation of a repair absorption field south of the proposed system may require future installation of a lift station to provide discharge of septic effluent from the tank to the repair absorption field. SYSTEM INSTALLATION The owner and system contractor should be aware of and comply with the following installation and system operation requirements. All installation activities shall be conducted in accordance with Garfield County Health Department Sewage Disposal System (SOS) regulations. If at any time during construction, subsurface site conditions are encountered which differ from the design parameters stated above. construction activities should stop and the design engineer and Garfield County Health Department be contacted to address any necessary design modifications. The system contractor must be approved and licensed by the Garfield County Health Department for installation of sewage disposal systems. Installation procedures including grade, location. setbacks. septic tank size, and absorption field size should conform with the attached figures. Sewage Disposal System Design Williams Gas Facility No.3 Parachute Creek, Garfield County. Colorado GEG Job No. 2,164 • • Construction activities and system components should not encroach upon existing easements or utility corridors. A minimum of 6 feet of undisturbed soil should be maintained between individual absorption elements and the septic tank and for adjacent absorption elements. Minimum setbacks for system components are. SOURCE SEPTIC TANK ABSORPTION FIELD BUILDING SEWER water line 10 feet 25 feet 10 feet dwelling 10 feet 20 feet ---- unoccupied bldg. or structure 5 feet 5 feet _ - Property lines 10 feet 10 feet 10 feet subsoil drains 10 feet 25 feet 10 feet open ditch 50 feet 50 feet 50 feet lined/gated ditch 25 feet 25 feet 25 feet solid pipe ditch 10 feet 10 feet 10 feet dry gulch 10 feet 25 feet _ 10 feet pond 50 feet 50 feet 50 feet To help avoid surface flow infiltration and saturation of the new absorption system, abandonment of flood irrigation within 50 feet of any SDS element is recommended. All sewer lines and effluent distribution piping should be 4 inches in diameter, have glued joints, and should looped at termination of discharge. Septic tank lines should be placed level. All lines discharging sewage from the residence to the septic tank shall maintain fall of between 1/8 inch and 'f4 inch per foot and shall employ sweep 90's or 2-45's at all turns. Sewer lines from the dwelling to the septic tank and at least 6 feet from the septic tank outlet must meet minimum standard ASTM -3034. Sewer lines under driveways shall always meet minimum Schedule 40 PVC standards and should be encased with corrugated metal pipe when covered with less than Sewage Disposal System Design Williams Gas Facility No.3 Parachute Creek, Garfield County, Colorado GEG Job No, 2,164 10 24 inches of soil. Eighteen inches to 24 inches of soil cover should be maintained over all SDS components to mitigate freezing of septic effluent (excepting maximum 8 inches cover over septic access ports). The installer should not place fill in the open excavation until inspected and approved by the design engineer. Additionally, the final cover should not be placed on sewer lines, septic tank, or the absorption area until the system has been inspected and approved by the design engineer and the Garfield County Health Department. The installer should provide 48 hour notice to the engineer and the Garfield County Health Department for all required inspections. 9. Four inch effluent distribution lines should be embedded in gravel with a minimum of 6 inches of gravel under, and 2 inches of gravel over each line. A layer of 1.0 to 2.5 inches screened rock with individual aggregate components of uniform size should be used. A covering of untreated building paper, hay, straw, or synthetic filter fabric should be placed on top of the gravel before placing the surface cap. 10. The system contractor shall be aware of the potential for construction activities to reduce soil permeability's at the site through compaction, smearing, and shearing. The following precautions and construction procedures should be employed during installation to mitigate disturbance to native soils: a. Excavation should proceed only when the moisture content of the soil is below the plastic limit. Excavation and backfill equipment should work from the surface where at all practical to avoid compaction of the soils at depth. c. The bottom and sidewalls of the excavation should be left with a rough, open surface. The appearance should be that of broken or ripped soil as opposed to a sheared, smeared, or troweled surface. Any smoothed or smeared surfaces should be removed with a toothed rake or shallow ripper taking care to remove loose residues from the bottom of the excavation by hand if necessary. Sewage Disposal System Design Williams Gas Facility No,3 Parachute Creek, Garfield County, Colorado GEG Job No. 2,164 d. Care should be taken in placing fill materials in the excavation to avoid damaging the exposed soil surfaces. OPERATION AND MAINTENANCE Performance of the subject sewage disposal system will be dependent on suitable operations and maintenance practices. The owner must understand and accept responsibility for operations and maintenance of the system. Important factors include: The owner should install a structural barrier if necessary and take precautions to prevent vehicular traffic, excessive surface watering, accidental flooding, or other activities in the vicinity of the absorption field which may compact, saturate, or otherwise alter the subsurface soil parameters used in designing the septic system. The owner should plant and maintain grass or other shallow rooted cover crop to prevent erosion and promote evapotranspiration over the absorption area. 3. The owner should inspect and maintain the required mounding and drainage away from the absorption area to prevent saturation from precipitation and surface flows_ The owner should inspect and prevent intrusion of burrowing animals and deep rooted plants into the absorption area. The owner should conduct periodic maintenance of the septic system by removing accumulated sludge from the septic tank every 3 to 4 years to prevent clogging of the absorption area. The septic tank filter should be inspected on a yearly basis, minimum. Sewage Disposal System Design Williams Gas Facility No.] Parachute Creek, Garfield County, Colorado GEG Job No. 2,164 12 The owner should not allow disposal of harmful substances into the subject sewage disposal system. LIMITATIONS Satisfactory performance of a sewage disposal system is dependent on several factors including subsurface evaluation, design, installation, operation and maintenance procedures. It is important to understand there is an element of risk inherent with the performance of each individual sewage disposal system. The design engineer can provide design measures and recommendations to help mitigate risk. A comprehensive review by the health department is recommended to help mitigate risk. The risks associated with overall system operation/performance must be understood and accepted by the owner. Design notes contained in this report are based on limited subsurface data. Variations in subsurface conditions not indicated by the test pit are possible. Subsurface conditions may also change with time. The installation contractor should observe actual subsurface conditions exposed at the time of excavation. If differing conditions are suspected, installation should cease immediately. If different soil or groundwater conditions are suspected, Garfield County Health Department and our office should be contacted to review conditions and make necessary design changes. The recommendations contained in the report are also based on information supplied to Sewage Disposal System Design Williams Gas Facility No.3 Parachute Creek, Garfield County, Colorado GEG Job No. 2,164 13 • GEG by the client. Geotechnical Engineering Group does not accept responsibility for variation in the assumed design parameters. The scope of work performed is specific to the proposed construction and the client identified by this report. Any other use of the data, recommendations and design parameters (as applicable) provided within this report are not appropriate applications. Other proposed construction and/or reliance by other clients will require project specific review by this firm. Changes in site conditions can occur with time. Changes in standard of practice also occur with time. This report should not be relied upon after a period of three years from the date of this report and is subject to review by this firm in light of new information which may periodically become known. We believe this design was conducted in a manner consistent with that level of care and skill ordinarily used by geotechnical engineers practicing in this area at this time. No other warranty, express or implied, is made. If we can be of further service in discussing the contents of this report or the analysis of the influence of the subsurface conditions on the design of the proposed construction, please call. Sewage disposal System Design Williams Gas Facility No.3 Parachute Greek, Garfield County, Colorado GEG Job No. 2,164 14 • Sincerely, p REQ ,.. GEOTECHNICAL Ef I ERGROUP, INC, ei 303d (1I a John P. Withers, ..... Principal Engineer's, JPW:cb (3 copies sent) Sewage Disposal System Design Williams Gas Facility No.3 Parachute Creek, Garfield County, Colorado GEG Job No. 2,154 15 Sewage Disposal System Design Williams Gas Plant No. 3 County Road 215 and Mancamp Road Garfield County, Colorado 8 ,.._., \, .'' 11): I ., '.. . C , . 1 , k . • 1. .,-- 1 .-. ' '-- P.-1 . .i ,2. . i. . '' • 1 '-- -- ' ' \ by- /'-' ( / e , - , ..., ,, ._.,, — ' • ) i, ) :\---t-/;) • i le/' ,)f , ",, ed./ , i ---7, A -1\ r ,,,, 27 ) /' /-,.1 7 • i ,..1 1, 4 \., -..:, ;•., . ‚ Li k1/4, Subject ) . - L'111. I ‘A,,-- f ">"' taw /0/ CY ' •• ,-)-- .‘ ' / f , s. ' . - '-'1 el \ r„ 1 • . I ' . / '. 1 CV 1 i *._ (.-..., \72'), - . - k (' 55/9/ Man Camp Road f -s‘ (Location Approxirridte) Job No. 2,164 fr. re ( NI Vicinity Map Fig. 1 • Proposed -- Building -- $epflC_Y`' Tank Relocate ~ _ Dirt Road 50' South 14, 1 Absorbtiop 1 Field 1 / Future Repair Area Job No. 2,164 Location of Sewage Disposal System Fig. 2 Clean Out Septic Tank 4" Perforated PVC Pipe Job No. 2,164 Looped at ends Proposed Building / / 11 111 11 102' 96' 3' - 6' 6 -- 3' - — 24' Scale: 1" = 20' Absorption Field Plan View Clean out should be provided every 100 lineal feet. Fig. 3 • 12" Seepage Bed 1.0 - 2.5 inch screened rock 4 -inch Perforated Distribution Lines, typical (6" Gravel under, 2" Gravel over minimum) Synthetic Filter fabric, hay or untreated building paper over gravel Soil Cap (mound 5%) • Job No. 2,164 • 6' 24` • • Scale 1"=5' Absorption Field Cross Section Fig. 4 APPENDIX A LOGS AND LEGEND OF PROFILE TEST HOLE AND RESULTS OF PERCOLATION TESTING TH-1 • Note: This figure was prepared based on GEG field and in house mapping, and is intended to show exploratory boring locations only. gTH-2 TH 3 TH♦ 5 TH-13 TH 4 TH- TH-16 TH-16 ■■ ■ H -15j • TH-9 Anticipated location of proposed structures (typical) TH-17 -1-14- 9 H-18 P-10 d P-3 0 P-2 Legend • Indicates location of exploratory borings. o indicates location of percolation testing. Job No. 2,108 Location of Exploratory Borings Fig. 2 TH-1 elev. 5434' 5450 5440 5430 CO CD 5420 0 TH-2 elev. 5444' TH-3 elev. 5442' 5410 TH-4 elev. 5433° Anticipated Plant Finish Grade elev. 5431' & 5440' Fot 20/12 PE iPis 6/12 9/12 5406 20112. 18/12 7/12 8/12 Elevation -fee 4/12 Job No. 2108 Logs of Exploratory Borings Fig. 3 TH-5 TH-6 TH-7 TH-8 elev. 5441' elev. 5432' elev. 5433' elev. 5430' 5450 5450 Anticipated Plant Job No. 2108 22/12 8/12 7/12 8/12. 4/12 7/12 Finish Grade elev. 5431' & 5440" 19/12 16/12 16/12 5440 5430 fj 21/12 / 8/12 5420 / 6/13 6/12 5410 6/12 5400 5390 5380 50/10 5370 Logs of Exploratory Borings Fig. 4 Elevation -fee Elevation -fee • TH-9 TH-10 TH-11 TH-12 elev. 5434' elev.5439' elev. 5442' elev. 5448' 5450 5450 Anticipated Plant Finish Grade elev. 5431' & 5440' 5440 5430 5420 5410 5400 25/12 21/12 8/12 7/12 19/12 11/12 14/12 5440 16/12 8/12 5430 11/12 5420 5410 5400 Job No. 2108 Logs of Exploratory Borings Fig. 5 Elevation -fee • TH-13 elev. 5444' TH-14 elev. 5443' TH-15 elev. 5339' TH-16 elev. 5442' 5450 5450 Anticipated Plant Finish Grade elev. 5440' 5440 — 5430 5420 5410 5400 5390 5380 19/12 12/12 14/12 23/12 13/12 6/13 15/12 8/12 8/12 24/12 8/12 8/12 11/12 29/12 48/12 50/5 5440 5430 5420 5410 5400 5390 5380 5370 5370 Job No. 2108 Logs of Exploratory Borings Fig. 6 • TH-17 elev. 5436' TH-18 elev. 5431' TH-19 elev. 5429' 5450 5450 Anticipated Plant Finish Grade elev. 5431' 5440 5440 5430 19/12 5420 5410 19/12 8/12 21/12 17/12 7/12 9/12 5430 5420 5410 5400 5400 Job No. 2108 Logs of Exploratory Borings Fig. 7 Elevation -feet Legend Clay, sandy, Sand, clayey, gravelly and Clay, sandy, silty lenses, medium stiff to very stiff, dry to wet, brown, sulfates noted, possible ancient slide deposits. (CL) Gravel, clayey, dense to very dense, wet. (GC) Indicates drive sample. The symbol 5/12 indicates that 5 blows of a 140 pound hammer falling 30 inches were required to drive a 2.5 inch O.D. sample barrel 12 inches. Indicates bag sample taken from auger cuttings. 'g I Indicates free water level. Numeral indicates number of days after drilling that measurement was taken. Indicates depth at which exploratory boring caved. Indicates practical drill rig refusal with augering methods. Boring terminated. Indicates penetration test. The symbol 50/9 indicates that 50 blows of a 140 pound hammer falling 30 inches were required to drive a 2.5 inch O.D. dynamic cone 9 inches. Elev. Indicates elevation of ground surfaces at test boring location as obtained 5,434 from topographic map provided by Williams Production and is approximate. Notes 1. Exploratory borings were drilled and sampled on August 24 and 25, 2005 using a 4 -inch diameter solid stem, continuous flight auger and a track mounted drill rig. 2. These logs are subject to the explanations, limitations and conclusions as contained in this report. Job No. 2,108 Legend of Logs of Exploratory Borings Fig. 8 1111 SATURATION AND PREPARATION DATE: August 24, 2005 TIME AT START OF SATURATION: 11:30 Geoteehmiewi i a reieaI 1 Group, Iae. PERCOLATION TEST DATE: August 25, 2005 WATER IN BORINGS AFTER SATURATION Depth to Water pi YES X NO PERCOLATION TEST RESULTS HOLE NUMBER 8' Diameter DEPTH (INCHES) TIME AT START OF INTERVAL TIME INTERVAL (MINUTES) DEPTH TO WATER CHANGE IN WATER DEPTH (INCHES) PERCOLATION RATE (MIN/INCH) START OF END OF INTERVAL INTERVAL (INCHES) (INCHES) P-1 rY 0' 4" DIA 48" 11:01 10 33.25 33.5 0.25 40 48" 11:11 10 33.5 34.0 0.5 20 48" 11:21 10 34.0 34.25 0.25 40 48" 11:31 10 34,25 34.25 0.0 48" 11:41 10 34.25 34.5 0.25 40 48" 11:51 10 34.5 34.75 0.25 40 * Note * - : indicates did not percolate during this interval. Job No. 2,108 Fig. 16 Geateelwleal IhkEngimeerhig 16. Group, Inc. SATURATION AND PREPARATION DATE: August 24, 2005 TIME AT START OF SATURATION: 11:40 PERCOLATION TEST DATE: August 25, 2005 WATER IN BORINGS AFTER SATURATION YES X NO Depth to Water PERCOLATION TEST RESULTS HOLE NUMBER 8" Diameter DEPTH (INCHES) TIME AT START OF INTERVAL TIME INTERVAL (MINUTES) DEPTH TO WATER CHANGE IN WATER DEPTH (INCHES) PERCOLATION RATE (MIN/INCH) START OF END OF INTERVAL INTERVAL (INCHES) (INCHES) P-2 © 0' 4" DIA 48" 11:02 10 33.25 33.5 0.25 40 48" 11:12 10 - 33.5 33.75 0.25 40 48" 11:22 10 33.75 34.0 0.25 40 48" 11:32 10 34.0 34.25 0.25 40 48" 11:42 10 34.25 34.5 0.25 40 48" 11:52 10 34.5 34.75 0.25 40 Job No. 2,108 Fig. 17 Geotechnical 11Eagiaeeriag Ih Group, Inc. SATURATION AND PREPARATION DATE: August 24, 2005 TIME AT START OF SATURATION: 11:50 PERCOLATION TEST DATE: August 25, 2005 WATER IN BORINGS AFTER SATURATION Depth to Water 1 YES X NO PERCOLATION TEST RESULTS HOLE NUMBER 8" Diameter DEPTH (INCHES) TIME AT START OF INTERVAL TIME INTERVAL (MINUTES) DEPTH TO WATER CHANGE IN WATER DEPTH (INCHES) PERCOLATION RATE (MIN/INCH) START OF END OF INTERVAL INTERVAL (INCHES) (INCHES) P-3 @ 0' 4" DIA 1 48" 11:03 10 30.25 30.75 0.5 20 48" 11:13 10 30.75 31.0 0.25 40 48" 11:23 10 31.0 31.0 0.0 co 48" 11:33 10 31.0 31.25 0.25 40 48" 11:43 10 31.25 31.5 0.25 T 40 48" 11:53 10 31.5 31.5 0.0 co * Note * co : indicates did not percolate during this interval. 0 Job No. 2,108 Fig. 18 • Geotechnical iI Eug u rring, Groupl", Inc`. • TABLE 1 SUMMARY OF LABORATORY TEST RESULTS 410 JOB NO. 2,108 HOLE DEPTH (FEET) NATURAL MOISTURE (%) DRY DENSITY (PCF) Atterberg Limits Swell / Consolidation PASSING NO. 200 SIEVE (%) WATER SOLUBLE SULFATES (PPm.) SOIL TYPE LIQUID LIMIT (%) PLASTICITY INDEX (%) SWELL (%) CONFINING PRESSURE (PSF) TH-1 2 20.8 107 32 16 _ 79 Clay, sandy (CL) 9 17.9 _ 107 CIaY sandy (CL) 14 20.8 105 Clay, sandy (CL) 24 22.6 100 Clay, sandy (CL) _ TH-2 9 Laborato Testing in Progress , TH-3 4 6.8 119 _ Clay, sandy (CL) 9 Laboratory Testing in Progress 14 20.2 106 28 15 83 Clay, sandy, silty (CL) TH-4 4 11.5 102 Clay, sandy (CL) TH-5 9 8.9 112 +1.6 1,000 Clay, sandyjCL) - TH-6 2 13.6 107 _ Clay, sandy (CL) 9 22.4 103 Clay, sandy (CL) TH-7 4 Laboratory Testing in Progress 19 8.2 114 +0.6 1,000 Clay, sandy (CL) TH-8 2 5.3 109 +0.6 250 Clay, sandy (CL) TH-9 2 7.5 Clay, sandy (CL) TH-10 4 8.0 105 +0,2 250 Clay, sandy (CL) 9 8.2 113 Clay, sandy (CL) 19 16.2 111 Clay, sandy (CL) 29 19.8 96 23 8 66 Clay, sandy, silty (CL) Page 1 of 2 • GeoIerhnirai (E ngineering Group, Inc. • TABLE 1 SUMMARY OF LABORATORY TEST RESULTS • JOB NO. 2,108 HOLE DEPTH (FEET) NATURAL MOISTURE (%) DRY DENSITY (PCF) Atterberg Limits Swell / Consolidation PASSING NO. 200 SIEVE (%) WATER SOLUBLE SULFATES (ppm) SOIL TYPE LIQUID LIMIT (%) PLASTICITY INDEX (%) SWELL (%) CONFINING PRESSURE (PSF)- - TH-11 9 7.6 119 +1.2 1,000 Clay, sandy (CL) 19 9.1 103 24 Sand, clayey, gravelly (SC) TH-12 9 12,8 111 - - Clay, sandy (CL) TH-13 9 Laboratory Testing in progress 14 26.0 109 +0.4 1,000 Clay, sandy (CL) I TH-14 9 I 4.5 114 -0.7 1,000 Clay, sandy (CL) TH-15 4 7.3 84 30 Sand, clayey, gravelly (SC) TH-16 19 14.3 _ 114 24 10 _ 46 Sand, clayey (SC) 29 14.7 115 51 Clay, sandy, gravelly (CL) TH-17 2 8.6 108 +5.5 250 Clay, sandy (CL) 9 5.7 114 +0.5 1,000 Clay, sandy (CL) TH-18 4 Laboratory Testing in Progress 9 10.9 107 26 12 59 Clay, sandy, silty (CL) 14 16.4 107 69 Clay, sandy (CL) Page 2 of 2 PVCMI Land Planning Division 1038 County Road 323 Rifle, CO 81650 Ph. 970-+625-5354 Fax 970-625-4522 Email: pvcm@direcway.com Project: Williams Production RMT Co.- Parachute Creek Gas Plant Expansion Phase 3 Submittal Item Number: 4. Site Plan Please find attached the following: A_ Proposed Parachute Creek Gas Plant Phase 3 parcel map noting legal description of phase 3 and relationship to Phase 1 and Phase 2. Prepared by Construction Surveys, Inc. dated 11/9/05. B. "Williams Production Parachute Creek Gas Plant 3- Plot Plan" prepared by The Hanover Co. dated 819/05. This mapping includes the equipment legend and plot plan for Phase 3. C. "Williams Production Parachute Creek Gas Plant 3- Grading Plan Terrace Design" prepared by The Hanover Co. dated 1016/05. This mapping notes the grading design for the project. D. "Addition to Parachute Gas Processing Plant Existing Conditions Map" prepared by Construction Surveys dated 6/4/04. This mapping was included in the Phase 2 SUP application and is being included for your use as this includes the Phase 1 and Phase 2 equipment and layouts. E. "Williams Production RMT Co. Williams Parachute Creek Ii" Plot Plan North, Plot Plan East and Plot Plan South prepared by The Hanover Co. dated 8/25/04. This mapping was included in the Phase 2 SUP application and is being included for your use as this includes the Phase 1 and Phase 2 equipment and layouts.. Please contact me with any questions. Sincerely, Philip B. Vaughan President. PVCMI Page 1 of 1 • GM/2O6-28 0 GM/207--28 k c7 54" F, 0. / c[r a 1 0. P.Q.B. 0- GM#2O8-28 GM#44-28 qb GV/26-28 N 2670422"W 252.95' . 28 33 1/4 CORNER 1912 GLO BRASS CAP PARACHUTE 0 CIA #215-3 WILLIAM'S OFFICE PARACHUTE CREEK GAS PLANT PHASE NO.3 111.18 ACRES 528, T6S, R96W S33, T6S, R96W 0` V GM /31-33 41111) GM /216-33 GM {431-33 GM /531-33 _PARACHUTE +CREEK PLANT PHASE NO.2 PARACHUTE CREEK GAS PLANT PHASE NO -E CONSTRUCTION SURVEYS, INC. 0012 SUNRISE [3LVD. SILT, CO S162 (SIOAre)-5153 PROPOSED PARACHUTE CREE< GAS PLANT 'P .15E NO.3 GENERAL LEGAL DESCRIPTION: An easement for the purpose of constructing and maintaining a Ca$ Plant facility with all pertinent accessories situate in the SE1/4 SW1/4 &` SW1/4 SE1/4 of Section 28 and in the NW1/4 NE1/4 of Section 33, Township 6 South, Range 96 West of the 6th Principal Meridian, Garfield County, Colorado, being more particularly described as follows: Commencing at a found 1912 GLO Brass Cap in place for the S1/4 corner of said Section 28; thence N26'20'42"W a distance of 252.95 feet to the True Point of Beginning of the easement described herein; thence N58`58'22"E a distance of 643.67 feet; S28'36'46"E a distance of 628.64 feet; thence S35'39'45"W a distance of 693.43 feet; thence N29'46'48"W a distance of 902.69 feet to the point of beginning, containing 11.18 acres more or less. PRooucnoN 1058 COUNTY ROAD 215 PARACHUTE, COLORADO, 81635 crAl r. 1"=330' I nArr• t /no inc. I DWG: PBARRETT1 \PCGP3 LEGAL (Doeeoo !31111 I 000C ; 13333 C...)(71)00000000000G0 3 '4UR1;16KOUP1111.1114 14.ili.E14;,!oziu444dOiIN r..341eglg-m010,,n7 i. . :: !r• : :. :1 : ! ? , •I .4 .."' -1 ! . ..7 o r, * * Sf * i • :' 70 i 47 1 a i 1 r 13 * . .. • 4 : 1 :i : • : : . ' 7 7 7 11 i ; it il 1 t t I 7 7 1:,®(F.)(Do-o-DeeeioeeeetE,o0 i if t:li -e C l !iiiul'; i i 64Y-te tacmaastix, r NATURAL G , PIPELINt 1 g _ x Jr j( Jam/ 3 to)l9N • k \ { 3Dtti0Cus lox) 1 $i al ma l )YSMYS 3dld '41 OIMO'Yfla SOSS3&0100 I A A ! i Lei _ �� fkfv3'0 0 4/ —77 b o Pits __. LJ_ A 0#1003008 110S5311a103 411380dOQld J (3OVaO1s 101+ 'dead i3Ovr1O1s 1QN +load x ,,./- f., 1 f I --, + X00%49-10 I / / ;�- - - - - —x—x-- / • S ld 01'011 A.t. Y o 0rrt 7 7 ■ /§ ■ ■ | Yip1 ± ) 0 >2 < m ; ¥%4k&GAA • • • c7 l m I v P � � 1 9 N tor 2 11 9 A WIL MAIL 'e mrd U A -V13-lO-54LIOL 0 0 Nl a col 1I a° N1OI8O 1NVld L 4W-0' 9V-3" E to UT-IGt CONTRO BUILD1N9 Ft MN iv 1 1 ■ I. i1 n 17 Oliva••".� mirialman mil 1961 �, Eq I I 1 t" MCC ROOM GENERATOR SUITING 90'-0` •at rr!rA.. L 606•-0" 26-4 -�I 1 • is 40 iom111t1.■ 21.610. 111. •fa �0 • 0 E 1_1 IP 4 - Vr, 4 .. a ..r "V.'FY. L G7 C•t • • • n rt n n z 0 2 01 N rn 0 Mr . W 1 .y w G A T (-) m 0 IL Az C rn 0 z C 0 FSCS -1 nm rnC 00 L. IY70-r E. 1400 -0' 0 1 0 i a • • • n 1 3 1 9 1 m 0 1 n 1. m T • le 60 __-_4_ �I __:f _r _ ------------ --t ------ 20'16 PIPELINE DRAINAGE SWALE Mcs �gp rFNr STACK 1 -r CO2 VENT STACK — — NOW LNYld 1 1 v I ra or to • • • PVCMI Land Planning Division 1038 County Road 323 Rifle, CO 81650 Ph. 970-625-5350 Fax 970-625-4522 Email: pvcm@direcway.com direcway.com Project: Williams Production RMT Co.- Parachute Creek Gas Plant Expansion Phase 3 Submittal Item Number: 5. Garfield County Road and Bridge Department Access Issues I met Jake Mall on September 13, 2005 at the intersection of County Road #215 and Man Camp Road. There is an existing Garfield County Access permit for the intersection. The attached map dated 11/8/05 by Construction Surveys details the existing conditions of the intersection and the accel/decal lanes up -valley and down -valley from this intersection. Installation of additional signage and improvements regarding striping of the acceleration and deceleration lanes on County Road #215 occurred in Spring 2005 and were paid for by Williams Production RMT Co. The traffic counts and traffic study are attached and shown on 12.1.D.1. Please contact me with any questions. Sincerely, Philip B. Vaughan President PVCM1 Page 1 of 1 12' THROUGH LANE 17' SHLOR. 6SHLDR. 12' THROUGH LANE 230' TAPER BEGIN R Sto. 13+4GQRGT TAPER Z7t 28 GO STY ROAD #215 Sto. 2791 6 Sta. 0+00.0 IAN CAMP ROAD 13' MEDIAN —1- 1, 0(I 11. , 8' SHLDR;— 4" SOLID - 4" DASH WHITE LINE WHITE UNE 1'. -OD 3L�i)C PLANT ENTRANCE /-` {Sto. 213+50)j% 4" SOLID Ir WtIITE UNE 4- 1i t 4" SOLID YELLOW UNE 715' REDIRECT TARER 4" SOLID WHITE LINE 10' EXIST.] EOP COUNTY ROAD #215 EXIST. EDGE OF PAVEMENT 2' 32 +,J11: _304 PLANT ENTRANCE 500' 725' DECEL. LANE (sta. 334-50) LENGTH CONSTRUCTION R. COUNTY ROAD 1215 1 423' R EXIST, "00 NOT ENTER" SIGN 339' TAPER LENGTH 743' ACCELERATION LENGTH CONSTRUCTION t COUNTY ROAD I235 Rick/.` r{'" RICH (Sta. 22+75) -36 - OC, COUNTY ROAD #215 13.5' THROUGH LANE 00 - 4" SOLID YELLOW UNE 4" SOLID EXIST. WHITE LINE EOP 600' DECELERATION LANE s 00 527' EXIgT REDIRECT TAPER 6" SHLDR" EXISTING- 4 EOP 170' TAPER ry LENGTH co AUXILIARY LANE DETAIL ke..E +••5t' 39+00 �; G 27_j�, COUNTY ROAD #215 27.1.. Sta_ 0+00,0 MAN CAMP ROAD EXIST. --- /`EOP 8$5' R 15' LANE DELINEATOR WIDTH PO5T 13' M EOLAN EXIST. "D0 NOT ENTER" SIGN 4 SOLID WHITE UNE EXIST. STRIPING 40+0[1 171' 12' C4 42+00 6' PAVED Iii-S1H2L'DRLANE -16` SHLDR• `_ �'�-- -`� 12 TLANERt7HUGH ~-- -- ` 8' 1:'AVED SHLR, 17' 43 104102-CI-ILITU 43.15 PROG6661NC1 RLLNT C77lWTY WO= '20 ACCII't.$ E(1Fj1IN(3 cONIDITIONS Willia• ms CON91'12UC1lON $13RYEY6• INC. 0012 eUNRIeg I+I1.i , CO 51692 VO -516.6163 REVISED 9X: !1 DATE: 11 /08/05 cHE4(EO 9Y: SRP O MARK T1 VC[.P ss VICINITY & OWNERSHIP MAP S1/2 SI/2 SEC. 28 + N1,i2 N1/2 SEC. 33, T. 6 S., R. 96 W., 6TH P.M. GARFIELD COUN+f1Y, COLORADO 2171" E 1-00-005 t 217L-194-00-954 UC LAND CO L BLM S PRODUCTION REIT CHUTE CREEK - PUNT, PRASE 3 'f1I1JA1iS PRO CHu1 PLANT, P 2171--28 -00-018 1 EnCan Oil do I Gaa, Inc. ..,�IMO Mill•= 1111JJAW PRDuC'foN Ri1T, MIAC11U, Call= PIAN1' P1,F911 Z IPELINE/SERVICE CORRIDOR MOBIL IL CORP ?IV -123-00-003 M IL OIL CORP. 2171-332-00- S PRODUCT'C . 1 4+2—O04111 PUC 2171-311-00-- PUCKETT LAND r CO. 1 :I • air.._ r' • 1 RUM 2171-324-00-968 CHEVRON USA, INC. 2409-052-00-011 1 O— L J -00-952 SID LI I AUER IVO NI UER L.__ 1 1 1 TOWN : OF ARACHUTE NOTE: Boundary information is based on field surveys and parcel numbers are based on record information os of 11/08/05 +mn woo mm xaa GRAPHIC SCALE CN FEET 1 PO .39Xerfil 1 C,71+lITRlCT10N 1' .iRY1n'b 1NC 04)12 11,A1111M LiLYP. WO, CO 8142 $1i-$16-11143 ,7k►,iTEG 9Y: SRP c' cxrD 9'r ST7P ' OATE_ ofte/oS arc P9pM MEET 111 1 • • • PVCMI Land Planning Division 1038 County Road 323 Rifle, CO 81650 Ph. 970-625-5350 Fax 970-625-4522 Email: pvem@direcway.com Project: Williams Production RMT Co.- Parachute Creek Gas Plant Expansion Phase 3 Submittal Item Number: 7 Garfield County Assessor's Maps Please find attached the following: A. Garfield County Assessor Maps 2171 and 2409 current as of 11110105. The mineral rights of the Williams Production RMT Co. subject property shown on the Garfield County Assessors map as parcel #2171-332-00-019 is: Williams Production RMT Co. 1515 Arapahoe Street Tower 3, Suite 1000 Denver, CO 80202 Please contact me with any questions. incerely, Philip B. Vaughan President PVCM1 Page 1 of 1 • • F 1- L 2 20 — I F 11 F F 21 111:1777:4131.11. 8 Si d1- Fr 1 4 EnCana oil & Gas, Inc. 8 - ettLandCo. 22 - 3 a OF 1 s 27 — 13' Mobile 011 Corp. 23 2414417171747 M 11n•a 11+ 14 NAVAL BALM. 15 serve 8 A A f A 1] V Y Williams Produ tion RMT A T F 6 Puck 81- 32 ti1 ett Land Co. 0 I L al SHALE x eserve B t;+ Reserve 11 zi1 25 18-2 B.L M_ 12 1b -8M 1 35 X11 .4 Hound RESET 3 38 2409-022-00--149 11 12 123456 7e210 11 12131416 _.l 11+ creel Number Used Cs 4 13 American Soda, LLP Bound& Adjoining 2409 YIAO 80F00 4100 T 1200 APPROVED C91J TY *3+72 111- American 4+ 2171 T.6S. — R.96W. • hAtorlifleZ4r1 WPC .t «0 J, Of 7 PVCMI Land Planning Division 1038 County Road 323 Rifle, CO 81650 Ph. 970-625-5350 Fax 970-625-4522 Email:vctn E direcway.com Project: Williams Production RMT Co.- Parachute Creek Gas Plant Expansion Phase 3 Submittal Item Number: 8 Adjacent Property Owners The following is a list of landowners adjacent to or within 200' of the property on which Williams Production RMT Co. is proposing to building the Parachute Creek Gas Plant Expansion Phase 1 Private landowners are identified by Assessor's Parcel Number and public lands are listed by address. This information is accurate as of 11/10/05. 1. Parcel #2171-332-00-019 (Subject Property) Williams Production RMT Co. c/o Logan & Firmine 3615 S Huron St, Ste 200 Englewood, CO 80110 2. Parcel #2171-311-40-006 Puckett Land Company 5460 S Quebec St Ste 250 Greenwood Vlg, CO 80111-1917 3. Parcel #2171-324-00-958 Bureau of Land Management P.Q_ Box 1009 Glenwood Springs, CO 81602-1009 4. Parcel #2171-331-40-020 Encana Oil & Gas Inc. c/o Logan & Firmine, Inc. 333 W Hampden Ave Ste 740 Englewood, CO 80110-2337 Page 1 of 3 • 5. Parcel #2171-291-00-005 Puckett Land Company 5460 S Quebec St Ste 250 Greenwood Vlg, CO 80111-1917 6. Parcel #2171-281-00.118 Encana Oil & Gas Inc. c/o Logan & Firmine Inc. 333 W Hampden Ave Ste 740 Englewood, CO 80110-2337 7 Parcel #2171-123-00-003 Mobil Oil Corp. P.Q. Box 53 Houston, TX 77001 8. Parcel #2171-342-00-017 Puckett Land Company 5460 S Quebec St Ste 250 Greenwood Vlg, CO 80111-1917 9. Parcel #2171-194-00-954 Bureau of Land Management P.Q. Box 1009 Glenwood Springs, CO 81602-1009 10. Parcel #2409-022-00-148 American Soda, Lip c/o Solvay Chemicals Attn. Steve Kovar 1930 Village Center Cir Suite 3 Pmb 442 Las Vegas, NV 89134 11. Parcel #2409-212-00-952 Bureau of Land Management P.Q. Box 1009 Glenwood Springs, CO 81602 Page 2 of 3 12. Parcel #2409-052-00-011 Chevron USA Inc. Cfo Chevrontexaco Propert Tax P.O. Box 285 Houston, TX 77001 13. Garfield County Road #215 c/o Garfield County Road & Bridge P.Q. Box 426 Rifle, CO 81650 Please contact me with any questions. Sincerely, (11 Philip B. Vaughan President PVCMI Page 3 of 3 • • PVCMI Land Planning Division 1038 County Road 323 Rifle, CO 81650 Ph. 970-625-5350 Fax 970-625-4522 Email: pvcm@direcway.com Project: Williams Production RMT Co.- Parachute Creek Gas Plant Expansion Phase 3 Submittal Item Number: 9. Deed and Legal Description Please find attached the following: A. 12/5/01 Davis Graham & Stubbs LLP letter to Dave Cesark B. Bill of Sale recorded 11/5/01 in Garfield County, CO C. QuitClaim Deed dated 10/31/01 and recorded 11/5/01, Lower Valley and Section 1. D. QuitClaim Deed dated 10/31/01 and recorded 11/5/01, Water and well rights and irrigation ditches. E. Special Warranty Deed dated 10/31/01 and recorded 11/5/01. F. Sheet 1 of 1, 9/27/01 prepared by Construction Surveys noting subject property on a wide format plan. Please contact me with any questions. Sincerely, P. Philip B. Vaughan President PVCM1 Page 1 of 1 • • • Davis Graham &Stubbs LLP December 5, 2001 lin !°ir.sr'- Class- Arai/ Dave Cezark 'Williams Production RMT Company P.Q. Box 370 Parachute, Colorado 81635 Re: Unocal Acquisition Garfield County, Colorado -Dear Dave: At the request of Annette Apperson, I enclose the following deeds from Union Oil Company of Cali fornia to Williams Production RMT Company in connection with your recent purchase of surface acreage in Garfield County, Colorado: 1. Special Warranty Deed from Unocal to Williams, which describes the lands by the legal descriptions contained in the numerous deeds through which Unocal acquired the property. Quitclaim Deed from Unocal to Williams, describing the lands by the metes and bounds description contained in the survey prepared for this transaction. 3. Quitclaim Deed from Unocal to Williams, conveying the water rights appurtenant to the property •vhich were not retained by Unocal. 4. Bill of Sale from Unocal to Williams, conveying personal property associated with the lands acquired by Williams. P?ease let me know if you have any questions regarding the enclosed instruments. r JNl-t:cnit Enclosures cc: Aiinette Apperson wish enclosures Si}ely, FIC�t N. Harris for DAVIS GRAHAM 3 STUBBS LLP Jane[ N. Ha11,3. Esq. 301 871 7361 ha rrrsgCgslaw.com 1.60 Stwei•get'rllh Street • Suar• SLC. • Denver (Olir,klo :iO.!+} . iu3 Lite ' tlu . la. PH 801. 13N 08/23/04 NON I7:42 PAX 870 625 2554 JEAN'S PRINTING i litiat11111111111111111111111.11 flit 1111111111111 r31321. 11/03/2001 03:11P 81300 P421 M PLSDORF •1 of 10 R 50.00 D 0.00 GARFIELD COUNTY CO AFTER RECORDING, RETURN TO: Janet N. Harris, Esq. Davis Graham & Stubbs LLP 1550 17`" Street, Suite 500 Denver, CO 80202 • BILL OF SALE KNOW ALL MEN BY THESE PRESENTS, That UNION OIL COMPANY OF CALIFORNIA, a corporation, duly organized and existing under and by virtue of the laws of the State of California, as Seller, for and in consideration of the sum of Ten and no/100 Dollars ($10.00), to it in hand paid by WILLIAMS PRODUCTION RMT COMPANY, a corporation, duly organized and existing under and by virtue of the laws of the State of Delaware, as Purchaser the receipt of which is hereby acknowledged, has bargained and sold and by these presents does grant and convey unto the said Purchaser, its successors and assigns, the following property, goods, and chattels: SEE EXHIBIT A ATTACHED HERETO AND INCORPORATED HEREIN BY REFERENCE together with all lighting, heating, plumbing, ventilating, and air conditioning fixtures, inside telephone wiring and connecting blocks/acks, plants, mirrors, floor coverings, smoke/fire detectors, security systems, intercom systems, sprinkler systems and controls, storm windows, storm doors, window and porch shades, awnings, blinds, screens, window coverings, curtain rods, drapery rods, storage sheds, and all keys, as located on the property and as owned by the Seller as of tate date of this Bill of Sale. located at: SEE EXLHBIT B ATTACHED HERETO AND INCORPORATED HEREIN BY REFERENCE TO HAVE AND TO HOLD the same unto the said Purchaser, its successors and assigns, forever. The said Seller covenants and agrees to and with the Purchaser, Es personal representatives, successors and assigns, to WARRANT AND DEFEND the sale of said property, goods, and chattels, against all persons claiming under Seller. Purchaser agrees that the Property is being sold "AS I5" AND "WHERE IS", WITH ALL FAULTS, IF ANY. SELLER. DOES HEREBY DISCLAIM ANY AND ALL AND MAKES NO REPRESENTATIONS OR WARRAN 11b.S, EXPRESS OR IMPLIED, OF ANY KIND TO PURCHASER, INCLUDING, WITHOUT LIMITATION, RELATING TO THE PHYSICAL CONDITION OF THE PROPERTY OR ITS SUITABILITY FOR ANY PARTICULAR PURPOSE. [REMAINDER OF PAGE INTENTIONALLY LEFT BLANK] tULU 7-9-0 06/23/04 MON 17:43 IAA 970 625 2554 T11111111111111111111111111111111111111 A X111111111111 531321 11/05/2001 03:11P B1300 P422 11 ALSDORF 2 of 10 R 50.00 D 0.00 GARFIELD COUNTY CO • • JEAN'S PRINTING IN WITNESS WHEREOF, the Seiler has caused its corporate name to be hereunto subscribed by its attorney-in-fact, and its corporate seal to be hereunto affixed, on this 29th day of October, 2001, to be effective as of October 31, 2001. UNION OIL COMPANY OF CALIFORNIA, a California corporation By. t G� Edward A. Wong, r tt [Unocal — attach appropriate Acknowledgment] ey-in-Fact 1ooz 08/23/04 MON 17:43 FAX 970 625 Zb54 CALtFORN1A ALL-PURPOSE ACKNOWLEDGMENT JEAN S rK1Nl11vt; rIY•�r✓!lam~1'�� .i��Jl.»rjl.�1�JtrJml�y State of IJ Fd ,//T 111111111111"Et 1111111111111111111111I111111 !Ill Ili 591321 11/05/2001 03:11P 81300 P423 M RLSDORF 3 of 10 R 50.00 D 0.00 GARF1ELD COUNTY CO County of 9 c:2.0 67 before mef't3 c r 7,547Y /r"./j Name are 711e el COM% 14.4- 'lane Doe, iIwary Puer7 it)/4 itb A . Gc1 (.7 ' Ue+e personally appeared personally known to me – OR – ❑ prove ~--; SANDRA E. CAMPBELL Comm, #1188922' Q =FT,: �' W0TARY VUE11_iG-CAL1rOriNIA� I r.GNGECOUNTY my CommHAFlpisis J my 31. 2002 hornets) et SgneriQ d to ire on the basis of satisfactory evidence 10 be the person(jr whose names) is/are subscribed to the within instrument and acknowledged to me that he/s t ey executed the same in his/her/their authorized capacity(ies), and that by his/her/their signatur4eron the instrument the persons}; or the entity upon behalf of which the person(al acted, executed the instrument. WITNESS my hand and official seal. OPTIONAL Though Me irltorrration below is not required by law, it may prove valuable to persons relying on the document and could prevent fraudu,ent removal and reattachment of this torr/ to another document, Description of Attached Document Tolle or Type of Document: W i t c _ O/ 5.4 L Document Date: - MS/ Number of Pages: 9 Signer(s) Other Than Named Above: Capacity(.ies) Claimed by Signer Signer's Name: - A'4 A. 4' ❑ Individual ❑ Corporate Officer Totle(s]: El Partner — 0 Limited 0 General j2 Attomey-in-Fact ❑ Trustee ❑ Guardian or Conservator O Other: Signer Is Representing. 124,,,14; c2/ C' i/ Inn+ 11 t1FSt Top al thumb het/ Signer's Name: ❑ individual Corporate Officer Title(s): ❑ Partner --- I Limited [Yl General C7 Attorney -in -Fact ❑ Trustee • Guardian or Conservator ❑ Other:. Signer Is Representing: 91 Prances! Notary AsaxpI . - 1Z3G Hamrnel Air.. PO 9o1 7541 • Cen rya Pare. CA 95709.7151 Prod NO 9907 Reerder. Cal lea -Fie, 7-910.97 ll JEAN 5 1'IUNT1NC .( 11111111111111111111 11111111111111115 ...111111111 1111 582321 11/05/2001 03:11F B1300 P424 'ti PLSDORF 4 of 10 R 550.00 D 0.00 GRRFIELD COUNTY CO • EXHIBIT A Irrigation Equipment P' CORNFIELD" 1 - Dual King Mover Engine: Model # 19070 Type 401801 Code #90010910 3 8 - 5" x 40' Sideroll Pipe w/76" Wheel & Sprinkler Head 2 - 5" x 20' Sideroll Power Unit Adapter 2 - 4" x 30' Aluminum Tubing 1 - Center Feed Tee 2 - Flushing End Plug 1 - SR -100 Nelson Sprinkler on Spray King Cart (Missing friction collars) 1 - 4"x 3" Valve Opening Elbow 7 - 3" x 30' Aluminum Tubing "MIDDLE CORN FIELD" 1 - Dual King Mover Engine: Model # 194702 Type 4018801 Code # 920300410 33 - 5" x 40' Sideroll Pipe w176" Wheel & Sprinkler 1 - 5" x 40' Sideroll Pipe w/76" Wheel "& Sprinkler (Needs repair) 2 - 5" x 20' Sideroll Power Unit Adapter 1 - 4" x 4" Valve Opening Elbow 2 - 4" x 30' Aluminum Tubing 1 - Center Feed Tee 2 - Flushing End Plug A- 0001 08/23/04 MUN 17:44 FAX 370 625 2554 JEAN'S PRINTING RJ005 11.11111-111111111111111111111111111111L. , 11111 1111 11 11 591321 11/05/2001 03:11P B1300 P425 r fLSQORF - ;5 of 10 R 50.00 D 0.00 GARFIEELD COUNTY CO `•WEST MAN CAMP" • • 1- Harvest King Mover Engine: Model # 190402 Type 401501 Code # 89073112 28 - 5" x 40' Sideroll Pipe w176" Wheel & Sprinkler Head 1 - 5" x 40' Sideroll Pipe w176" Wheel & Sprinkler Head (Needs repair) 2 - 5" x 20' Sideroll Power Unit Adapter 2 - 4' x 30' Aluminum Tubing 1 - 4" x 4" Valve Opening Elbow 1 - 76" Wheel (extra) 1 - Center Feed Tee 2 - flushing End Plug "NORTH MAN CAMP" 1 - Dual King Mover (Less Engine Cover) Engine: Model# 90702 Type 401801 Code #90010910 29 - 5" x 40' Sideroll Pipe w/76" Wheel & Sprinkler 3 - 5" x 40' Sideroll Pipe w/76" Wheel & Sprinkler (Needs repair) 2 - 5" x 20' Sideroll Power Unit Adapter 4 4" x 30' Aluminum Tubing 1- 4" x 30' Aluminum Tubing (Needs repair) 1 - 4" x 4" Valve Opening Elbow 1 - Center Feed Tee 2 - Flushing End Plug A-2 08/23704 NON 17:44 FAX 970 625 2554 1111111 1111111 1E111111 111111 111111 111111.. 41111 1111 1111 591321 11/05/2001 03:11P B1300 P426 11 ALSDORF .6 -of 10 R 50..00 D 0.00 GRRFIELD COUNTY CO • 1 - Dual King Mover Engine: JEAN'S PRINTING 4006 "MIDDLE MAN CAMP" Model # 90702 Type 401801 Code # 90010910 24 - 5" x 40' Siderall Pipe w/76" Wheel & Sprinkler Head 2 - 5" x 20' Siderolt Power Unit Adapter 3 - 4" x 30' Aluminum Tubing 1 Center Feed Tee 2 - Flushing End Plug "SOUTH MAN CAMP" (No Irrigation Equipment Present) A-3 08/23/04 MON 17:44 FAX 970 625 2554 1.41111 Uhl Illlll 111 .1111 11 11 11 11 591321. 11/05/2401 03:11P B1300 P427 11 ALSDORF - 7 of 10 R 50. e0 D 0 , 0F1 GRRFIELD COUNTY CO • JEAN'S PRINTING VJ007 "PUMPS" Diesel Pump (Irrigates the first and middle corn field) John Deere Engine: Serial # T04039T503730 Model # 4039TF001 Berkeley Pump: Model # B5EQBH Serial # G190695 BM# B66052 Imp.Dia 10.437" Electric Pump #1 (Irrigated the four man camp fields) Motor 30 HP 3 Phase 1755 RPM I.D. #E690JR10R221R029F Berkeley Pump: Model # B4IPBH Serial ## 21F89V BM# B58874 Imp. Dia_ 11.375" Electric Pump #2 (irrigates the man camp fields) Motor 15 HP 3 Phase 1755 RPM LD.## B042/RO I p3I3RO I4F Berkeley Pump: Model B3 (The remaining letters are illegible) Serial # 25U8550 ? BM # B53817 A-4 08/23/04 MGN 17:44 FAX 970 625 2554 _11111111111 111111[ 11111111111 dliE111. _,1111111111111 391321 11/03/2001 03:1113 B1300 P429 Fl fLSDORF • .$ oa 10 R 30.00 0 0.00 GARFIELD COUNTY CO MISCELLANEOUS • JEAN'S PRINTING All miscellaneous irrigation system parts and Components currently stored at the Small Vehicle Maintenance Shop. A-5 moos 08/23/04 MON 17:44 FAX 970 625 2554 1111111 11111 Ha 1111 111111 111111 11111L.,.111111111111.1 591321 11/05/20131 03:11P 91300 P429 11 RLSDORF • 9 of 10 R 50.00 D 0.00 GARFIELD COUNTY CO • • JEAN'S PRINTING IQ009 EXHIBIT B LEGAL DESCRIPTION - LOWER VALLEY A tract of land located in Section 4. Township 7 South and in Sections 27, 28, 29, 32, 33 and 34, Township 6 South, all in Range 96 West of the Sixth Principal Meridian, Garfield County, Colorado, being more particularly described as follows: Beginning at the northeast corner of said Section 4, thence S 073709" W along the east fine of said Section 4 a distance of 1341.94 feet to the southeast corner of the NE1/4 NE1/4 of said Section 4; thence N 87°14'02" W along the south line of the said NE1/4 NEI/4 a distance of 130L32 feet to the southwest corner of the said NE1/4 N£ 1/4; thence N 07°39'45" E along the west line of the said NE1/4 NE1/4 a distance of 1314.49 feet to the northwest corner of the said NEI/4 NE1/4; thence N 88°2T23" W along the north line of said Section 4 a distance of 1300.90 feet to the north quarter corner of said Section 4; thence N 00°16'42" E along the north -south centerline of said Section 33 a distance of 132941 feet to the northeast comer of Lot 10 (SEI/4 5W114) of said Section 33; thence N 88°30'49" W along the north hoe of Lots 10 & 9 (51/2 SW 114) a distance D12651_59 feet to the northwest comer of the said Lot 9 (SW 114 SW 1/4); thence N 88°50'57" W along the south line of Lot 5 (NEI/4 SEI14) of said Section 32 a distance of 1360.67 feet to the southwest comer of said Lot 5; thence N 00°]228" E along the west line of said Lot 5 a distance of 1323.15 feet to the northwest corner of said Lot 5; thence N 89°01'03" W along the east -west centerline of said Section 32 a distance of 1348.85 to the center of said Section 32; thence N 89°01'35" W continuing along said east -west centerline a distance of 1339.03 feet to the southwest corner of the SEI/4 NW1/4 of said Section 32; thence N 01°Ol'47` E along the west line of the said SE1/4 NWI/4 and Lot 1 (NEI/4 NW1/4) of said Section 32 a distance of 2666.55 feet to the northwest corner of the said Lot 1; thence N 00°59'42" E along the west line of Lot 11 (SE]/4 SW114) of said Section 29 a distance of 1338.98 feet to the northwest corner of said Lor 11; thence 5118°43'09" E. along the north line of said Lot 11 a distance of 1316.98 feet to the northwest comer of Lot 12 (SW 1/4 SE 1/4) of said Section 29; thence 5 88°41'29" E along the north line of said Lot 12 and the SE1/4 SEI I4 a distance of 2664.16 feet to the northeast corner of the said SEI/4 SEIl4; thence N 01°10'58" E along the east line of said Section 29 a distance of 339.19 feet to.a paint in the center of Parachute Creek; thence along the center of Parachute Creek the following seventeen courses: N 85°09'46" E a distance of 70.44 feet; thence 14 27'58'40" E a distance of 192.27 feet; thence 5 55°46'05" E a distance of 234.65 feet; thence N 88°57'30" E a distance of 55.01 feet; thence N 38°0342" E a distance of 26926 feet; thence N 83°39'35" E a distance of 27.17 feet; thence S 18°5228" E a distance of 123.65 feet; thence 5 02°34'59" E a avarice of 133.14 feet; thence S 19°08'01" W a distance of 103.73 feet; thence 5 18°48'43" E a distance of 96.14 feet; thence 5 02°33'50" W a distance of 67.07 feet; thence S 2.2°2513" E a distance of 68.15 feet; thencc N 61°25'10" E a distance of 152.59 feet; thence 14 86°30'38" E a distance of 82.15 feet; thence S 74°50'45" E a distance of 149.19 feet; thence S 49°20'18" E a distance of 102.83 feet; thence S 02°00'14" W a distance of 22.59 fret to the intersection of the center of Parachute Creek and the north line of the 51/2 SW1/4 of said Section 28; thence S 88°55'16" E along the north line of the said 51)2 SW 114 a distance of 601.13 feet; thence N 50°24'42" E a distance of 783.92 feet; thence 5 48°49'12" E a distance of 460.39 feet to a point on the north -south centerline of said Section 28; thence 1400°08'06" E along said centerline a distance of 1090.98 feet to the center of said Section 28; thence S 88°11'54" E along the east -west centerl.ne of said Section 28 a distance of 1349.87 feet to the northeast corner of Lot 8 (NW 1/4 SEI/4) of said Section 28; thence S DO°33'55" W along the east lint of said Lot 8 a distance of 1308.19 feet to the southeast comer of said Lot 8; thence S 88°03'07`' E along the north line of Lot 13 (SEI/4 SEI/4) of said Section 28 a distance of 1339.74 feet to the northeast corner of said Lot 13; thence S 88°37'54" E along the north line of Lot 13 (SW1/4 SW1/4) of said Section 27 a distance of 1351.61 feet to the northeast corner of said Lot 13; thence 5 00'51'16" W along the east line of said Lot 13 a distance of 1312.64 feet to northeast comer of Lot 2 (NW 1/4 14W114) of said Section 34; thence S 01'27'22" W along the east line of said Lot 2 a distance of 1330.99 feet to the southeast corner of the said Lot 2; thence 14 88°37'31" W along the south line of the said Lot 2 a distance of 1341.75 feet to the southwest corner of said Lot 2; thence N 88°14'04" W along the north line of Lot 5 (SEI/4 NE1/4) of said Section 33 a distance of 132230 feet to the northwest corner of said Lot 5; thence 5 00°34'11" W along the west line of said Lot 5 a distance of 1339.89 feet to the southwest corner of said Lot 5; thence 5 88°34'10" E along the south line of said Lot 5 a distance of 1315.02 feet to the southeast comer of said Lot 5; thence 5 00°52'13" W along the west line of Lot 10 (NW1/4 SW1/4) of said Section 34 a distance of 1293.90 feet to a paint on the west line of said Lot 10, thence 5 88°04'00" E a distance of 209.60 feet; thence psi 01°56'00" E a distance of 559.70 feet; thence S 88°04'00" E a distance of 714.70 feet; thence N 01°58'00" E a distance of 634.10 feet; thence 5 88°01'00" E a distance of 380.13 feet to a point on the east line of said Lot 10; thence 5 01°29'23" W along the east line of Lois 10 & 11 of said Section 34 a distance of 2558.09 feet to the southeast comer of said Lot 11, thence N 88°18'20" W along the south line of said Lot 11 a distance of 1299.91 feet to the northeast comer of said Section 4, the point of beginning, containing 133101 acres more or less. B-1 08/23/04 MON 17:45 FAX 970 625 2554 11111131111 111111 1111111111 11111111111 h. 11111 111 11 11 51321 11/05/2001 03:11P B1300 P430 M RLSDORF '10 of 10 R 50.00 0 0.00 GARFIELD COUNTY CO LEGAL DESCRIPTION SECTION 1 PROPERTY SA tract of land situated in Section 1, Township 7 South, Range 96 West of the Sixth Principal Meridian, Garfield County, Colorado, being more particularly described as follows: JEAN S PRINTING 4010 Beginning at the SW corner of the NW 114 SW 1/4 of said Section 1, thence N 06'°30'11" E along the west line of said Section 1 a distance of 1335.77 feet to the W1/4 corner of said Section 1; thence N 07007'360 E along the west line of said Section 1 a distance of 1142.73 feet to the SW corner of Lot 4 of said. Section 1; thence N 07°09'38" •E along the west line of said Lot 4 a distance of 1159.92 feet to the northwest comer of said Lot 4; thence S 89°20'03" E along the north line of said Lot 4 a distance of 1320.88 feet to the NE corner of said Lot 4; thence 5 06°46'32" W along the east line of said Lot 4 a distance of 1160.24 feet to the SE corner of said Lot 4; thence 5 89°11'01" E along the south line of Lot 3 of said Section 1 a distance of 1327.96 feet to the SE corner of said Lot 3; thence N 06'24'38' E along the east line of said Lot 3 a distance of 1163.73 feet to the NE corner of said Lot 3; thence N 83°10'31" E along the north line of Lot 2 of said Section 1 a distance of 1230.72 feet to the NE comer of said Lot 2; thence 5 05°5618" W along the east line of said Lot 2 a distance of 1245.99 feet to the SE corner of said Lot 2; thence N 86°57'47" E along the south line of Lot 1 of said Section 1 a distance of 1224.86 feet to the SE corner of said Lot 1; thence 5 05°29'5S" W along the east line of said Section 1 a distance of 1327.08 feet to the E114 comer of said Section 1; thence 5 00°44'31" 'W continuing along the east line of said Section 1 a distance of 2665.11 feet to the SE corner of said Section I; thence N 88°5313" W along the south line of said Section 1 a distance of 594.83 feet to the SE corner of the Grand View Industrial Center; thence N 01°08°47" E along the east line of the Grand View Industrial Center a distance of 361.67 Feer, thence N 86°13'49" W along the north line of the Grand View Industrial Center and the EXXON parcel a distance of 2077.00 feet to a point on the north -south centerline of said Section 1; thence N 06°23'14" E along said north -south centerline a distance of 876.15 feet to the NE corner of the SE1/4 SW1/4 of said Section 1; thence N 88453'31- W along the north line of said SE1/4 SW1/4 a distance of 1335.48 feet to the NW comer of said SEI/4 SW//4; thence S 06'26'49" W along the west line of said SE1/4 SW1/4 a distance of 559.54 feet to a point on the southerly right-of-way line of the railroad; thence N 51°43'07" W along said right -of --way a distance of 922.01 feet to a point on the south line of the NWI/4 SW1/4 of said Section 1; thence N 88°5311" W along said south line a distance of 549.47 feet to the SW corner of said NW 114 SW1/4, the point of beginning, containing 432.13 acres. Excluding, however, any tights to or interest in any mineral of any nature wha'soever which might underlie the surface of the 0 lands described above. The foregoing exclusion applies to all lands described on Exhibit B. B-2 f`illl il iil iii 111111111111 11111 111 11111 591319 11/05/2001 03:06P B1300 P410 M RLSDORF 1 of 4 R 20.00 D 0.00 GARFIELD COUNTY CO • • AFTER RECORDING, RETURN TO: Janet N. Harris, Esq. Davis Graham & Stubbs LLP 1550 171" Street, Suite 500 Denver, CO 80202 QUITCLAIM DEED THIS DEED, dated October 31, 2001, between UNION OIL COMPANY OF CALIFORNIA, a corporation duly organized and existing under the laws of the State of California, Grantor, whose legal address 376 S. Valencia Avenue, Brea, California 92823, and WILLIAMS PRODUCTION RMT COMPANY, a corporation duly organized and existing under and by virtue of the laws of the State of Delaware, Grantee, whose legal address is 1515 Arapahoe, Suite 1000, Denver, Colorado 80202: WITNESS, that the Grantor, for and in consideration of the sum of TEN AND NO/100 DOLLARS, the receipt and sufficiency of which are hereby acknowledged, has remised, released, sold and QUITCLAIMED, and by these presents does remise, release, sell and QUITCLAIM unto the Grantee, its successors and assigns forever, all the right, title, interest, claim and demand which the Grantor has in and to the real property, together with improvements, if any, situate, lying and being in the County of Garfield and State of Colorado, described as follows: SEE EXHIBIT A ATTACHED HERETO AND INCORPORATED HEREIN BY REFERENCE with all its appurtenances. IN WITNESS WHEREOF, the Grantor has caused its corporate name to be hereunto subscribed by its attorney-in-fact, and its corporate seal to be hereunto affixed, on this 29th day of October, 2001,.to be effective as of October 31, 2001. UNION OIL COMPANY OF CALIFORNIA, a California corporation By: Edward A. Wong, Atto -Fact [Unocal— attach appropriate Acknowledgment] 1 to CALIFORNIA ALL-PURPOSE ACKNOWLEDGMENT c .err.. ..0rr P OWrrrr .00: C000ZA �rrr. Zeoe. State of Gr/P.�fA-77/2 Al/i9 County of _C/t<'.9 111!!! IlIl it(II 11 IlI (I miiiiuuiuuun 591319 11/05/2001 03:06P B1300 P411 t1 RLSDORF 2 of 4 R 20.00 D 0.ee GRRFIELD COUNTY CO On (ir! Tzr 6 er-- -29 o7 o 0/ before me, c -../41‘-e.(9 e,7mf 6cCL_ /1•16-7,9,CY pare Name and Tale of Pricer ie.g..'JaniDae. Nolan, Pubic') personally appeared /pp A- . fie6— .n.(0 ar s.gnerts). Iris' personally known to me - OR - ❑ proved SANDRA E. CAMPBELL at,rA COMM. # 1188922rNOTARY PUBLIC • CALIF0HNiAl rORANGE coUNTY sy :..�;My Comm. I xpises July 3t, 2 02 r to me on the basis of satisfactory' evidence to be the person( ' whose name.ks1 is/are subscribed to the within instrument and acknowledged to me hat he/site/they executed the same in his/h4ritheif authorized capacity(ioo), and that by his/be Itt eir signature(s)'on the instrument the person( "r or the entity upon behalf of which the personcs1 acted, executed the instrument. WITNESS my hand and official seal. * _d`e -yin r S,gnalure el Notary PubNc /r OPTIONAL Though the Information below is not required by law, it may prove valuable lo persons relying on rhe document and could prevent fraudulent removal and reattachment of this form to another document_ Description of Attached Docurnent Title or Type of Document: r G2(74 -4fl'rt Document Date: /'O I 0/ ,i r Number of Pages: Signer(s) Other Than Named Above: Capacity(ies) Claimed by Signer()' Signer's Name: ED A-'/3 Al 6- O individual O Corporate Officer Title(s): O Partner — ❑ Limited D General El Attorney -in -Fact ❑ Trustee ❑ Guardian or Conservator ❑ Other: Signer is Representing: (47,4,"-atri e to Air 67 /I .11VC RIGHTTIMMISPFUPEr Tap Of tnurnC nefe Signer's Name: O Individual D Corporate Officer Title(s): • Partner — Ct Limited G General O Attorney -in -Fact O Trustee C Guardian or Conservator D Other: Signer Is Representing: RIGHT THIMBPRINT CIFSIGHEW TCii C. Liu -n'.? here 0 1994 Natiznal Nccrary Asscrcietion • 8236 Rummer Are. P O. Box 7184 • Canoga Park, CA 91309.718e Plod. No 5907 Retarder.: CdIl TOM -Flee 7 80,0-876.6827 lli EIti 11i1l1111111111111111111111111..1111111111111 1319 11/05/2001 03:06P 81300 P412 FI ALSDORF ' of 4 R 20.00 D 0.00 GARFIELD COUNTY CO • EXHIBIT A LEGAL DESCRIPTION - LOWER VALLEY A tract of land located in Section 4, Township 7 South and in Sections 27, 28, 29, 32, 33 and 34, Township 6 South, all in Range 96 West of the Sixth Principal Meridian, Garfield County, Colorado, being more particularly described as follows: Beginning at the northeast corner of said Section 4, thence S 07°32'09" W along the east line of said Section 4 a distance of 1341.94 feet to the southeast corner of the NE1/4 NE1/4 of said Section 4; thence N 87°14'02" W along the south line of the said NE1/4 NE1/4 a distance of 1301.32 feet to the southwest corner of the said NE1/4 NEI/4; thence N 07°39'45" E along the west line of the said NE1/4 NE1/4 a distance of 1314.49 feet to the northwest corner of the said NE1/4 NE1/4; thence N 88°2723" W along the north Iine of said Section 4 a distance of 1300.90 feet to the north quarter corner of said Section 4; thence N 00°16'42" E along the north -south centerline of said Section 33 a distance of 1329.61 feet to the northeast corner of Lot 10 (SE1/4 SW 114) of said Section 33; thence N 88°30'49" W along the north line of Lots 10 & 9 (S1/2 SW 1/4) a distance of 2651.59 feet to the northwest corner of the said Lot 9 (SWIM SW 114); thence N 88°50'57" W along the south line of Lot 5 (NE1/4 SE1/4) of said Section 32 a distance of 1360.67 feet to the southwest corner of said Lot 5; thence N 00°12'28" E along the west line of said Lot 5 a distance of 1323.15 feet to the northwest corner of said Lot 5; thence N 89°01'03" W alone the east -west centerline of said Section 32 a distance of 1348.85 to the center of said Section 32; thence N 89°01'35" W continuing along said east -west centerline a distance of 1339.03 feet to the southwest corner of the SE1/4 NW 1/4 of said Section 32; thence N 01°01'47" E along the west line of the said SE1/4 NW1/4 and Lot 1 (NE1/4 NW1/4) of said Section 32 a distance of 2666.55 feet to the northwest comer of the said Lot 1; thence N 00°59'42" E along the west line of Lot 11 (SE1/4 SW 1/4) of said Section 29 a distance of 1338.98 feet to the northwest corner of said Lot 11; thence 5 88°43'09" E along the north line of said Lot 11 a distance of 1316.98 feet to the northwest corner of Lot 12 (SW 1/4 5E1/4) of said Section 29; thence 5 88°41'29" E along the north line of said Lot 12 and the SE1/4 5E114 a distance of 2664.16 feet to the northeast corner of the said 5E1/4 SE1/4; thence N 0i°10'58" E along the east line of said Section 29 a distance of 339.19 feet to a point in the center of Parachute Creek; thence along the center of Parachute Creek the following seventeen courses: N 85°09'46" E a distance of 70.44 feet; thence N 27°58'40" E a distance of 192.27 feet; thence 5 55°46'05" E a distance of 234.65 feet; thence N 88°57'30" E a distance of 55.01 feet; thence N 38°03'42" E a distance of 269.26 feet; thence 83°39'35" E a distance of 27.17 feet; thence S 18052'28" E a distance of 123.65 feet; thence S 02°34'59" E a distance of 33.14 feet; thence S 19°08'01" W a distance of 103.73 feet; thence 5 18°48'43" E a distance of 96.14 feet; thence 5 02°33'50" W a distance of 67.07 feet; thence 5 22°25'33" E a distance of 68.15 feet; thence N 61°25'10" E a distance of 152.59 feet; thence N 86°30'38" E a distance of 82.15 feet; thence S 74°50'45" E a distance of 149.19 feet; thence S 49°20'18" E a distance of 102.83 feet; thence 5 02°00'14" W a distance of 22.59 feet to the intersection of the center of Parachute Creek and the north line of the 51/2 SW1/4 of said Section 28; thence 5 88°55"16" E along the north line of the said Si12 SW 1/4 a distance of 601.13 feet; thence N 50°24'42" E a distance of 783.92 feet; thence 5 48°49'12" E a distance of 460.39 feet to a point on the north -south centerline of said Section 28; thence N 00°08'06" E along said centerline a distance of 1090.98 feet to the center of said Section 28; thence S 83°11'54" E along the east -west centerline of said Section 28 a distance of 1349.87 feet to the northeast corner of Lot 8 (NW 114 SE1/4) of said Section 28; thence 5 00°33'55" W alone the east line of said Lot 8 a distance of 1308.19 feet to the southeast comer of said Lot 8; thence S 88°03'07" E along the north line of Lot 13 (SE1/4 SE1/4) of said Section 28 a distance of 1339.74 feet to the northeast corner of said Lot 13; thence 5 88°37'54" E along the north line of Lot 13 (SW1/4 SW114) of said Section 27 a distance of 1351.61 feet to the northeast corner of said Lot 13; thence 5 00°51'16" W along the east line of said Lor 13 a distance of 13 12.64 feet to northeast comer of Lot 2 (NW i/4 NW 1/4) of said Section 34; thence S 01°27'22" W along the east line of said Lot 2 a distance of 1330.99 feet to the southeast corner of the said Lot 2; thence N 88°37'31" W along the south line of the said Lot 2 a distance of 1341.75 feet to the southwest comer of said Lot 2; thence N 88°14'04" W along the north line of Lot 5 (SE 1/4 NE 1/4) of said Section 33 a distance of 1322.30 feet to the northwest comer of said Lot 5; thence 5 00'34'11" W alone the west line of said Lot 5 a distance of 1339.89 feet to the southwest corner of said Lot 5; thence 5 88°34'10" E along the south line of said Lot 5 a distance of 1315.02 feet to the southeast corner of said Lot 5; thence 5 00°52'13" W along the west line of Lot 10 (NW1/4 SWI/4) of said Section 34 a distance of 1293.90 feet to a point on the west line of said Lot 10; thence 5 88°04'00" E a distance of 209.60 feet; thence N 01°56'00" E a distance of 559.70 feet; thence S 8S°04'00" E a distance of 714.70 feet; thence N Dl°58'00" E a distance of 634.10 feet; thence 5 88°01'00" E a distance of 380.13 feet to a point on the east line of said Lot 10; thence S 01°29'23" W along the east line of Lots 10 & 1 1 of said Section 34 a distance of 2558.09 feet to the southeast corner of said Lot 11, thence N 38°18'3.0" W along the south line of said Lot 11 a distance of 1299.91 feet to the northeast corner of said Section 4, the point of beginning, containing 1333.01 acres more or less. • A -I 1111111) 111111 1111 111111 111111 11111':rs /IIII 1111 1111 31319 11/05/2001 03:06P B1300 P413 M fLSDORF of 4 R 20:00 D 0.00 GARFIELD COUNTY' CO LEGAL DESCRIPTION - SECTION 1 PROPERTY Ootract of land situated in Section 1, Township 7 South, Range 96 West of the Sixth Principal Meridian, Garfield County, lorado, being more particularly described as follows: Beginning at the SW corner of the NW 1/4 SW1/4 of said Section 1, thence N 06°30'11" E along the west line of said Section 1 a distance of 1335.77 feet to the W 1/4 corner of said Section 1; thence N 07°07'36" E along the west line of said Section 1 a distance of 1142.73 feet to the SW corner of Lot 4 of said Section 1; thence N 07°09'38" E along the west line of said Lot 4 a distance of 1159.92 feet to the northwest comer of said Lot 4; thence 5 89°20'03" E along the north line of said Lot 4 a distance of 1320.88 feet to the NE corner of said Lot 4; thence S 06°4612" W along the east line of said Lot 4 a distance of 1160.24 feet to the SE corner of said Lot 4; thence 5 89°11"01" E along the south line of Lot 3 of said Section 1 a distance of 1327.96 feet to the SE corner of said Lot 3; thence N 06°24'38" E along the east line of said Lot 3 a distance of 1163.73 feet to the NE corner of said Lot 3; thence N 83°10'31" E along the north line of Lot 2 of said Section 1 a distance of 1230.72 feet to the NE corner of said Lot 2; thence 5 05°56'38" W along the east line of said Lot 2 a distance of 1245.99 feet to the SE corner of said Lot 2; thence N 86°5T47" E along the south line of Lot 1 of said Section 1 a distance of 1224.86 feet to the SE comer of said Lot 1; thence S 05°29'58" W along the east line of said Section 1 a distance of 1327.08 feet to the E1/4 corner of said Section 1; thence 5 00°44'31" W continuing along the east line of said Section 1 a distance of 2665.11 feet to the SE corner of said Section 1; thence N 88°53'33" W along the south line of said Section 1 a distance of 594.83 feet to the SE corner of the Grand View Industrial Center; thence N 01°08'47" E along the east line of the Grand View Industrial Center a distance of 361.67 feet; thence N 86°13'49" W along the north line of the Grand View Industrial Center and the EXXON parcel a distance of 2077.00 feet to a point on the north -south centerline of said Section 1; thence N 06°23'14" E along said north -south centerline a distance of 876.15 feet to the NE corner of the SE1/4 SW 1/4 of said Section 1; thence N 88°53'31" W along the north line of said SE1/4 SW1/4 a distance of 1335.48 feet to the NW corner of said SE1/4 5W1/4; thence 5 06°26'49" W along the west line of said SE I14 SW 1/4 a distance of 559.54 feet to a point on the southerly right-of-way line of the railroad; thence N 51°43`07" W along said right-of-way a distance of 922.01 feet to a point on the south line of the NW1/4 SWII4 of said Section 1; thence N 88°53'31" W along said south line a distance of 549.47 feet to the SW corner of said NW1/4 SW 1/4, the point of beginning, containing 432.13 acres. cluding, however, any rights to or interest in any mineral of any nature whatsoever which might underlie the surface of the nds described above. The foregoing exclusion applies to all lands described on Exhibit A. • .I Ill cilli 1EEI11 LE 1111111111 ,.11lI 1111 IIII .1,320 11/I05/2001 03:09P B1300 P414 t1 ALSDORF .'of 7 R 35.00 D 0.00 GARFIELD COUNTY CO AFTER RECORDING, RETURN TO: •Janet N. Harris, Esq. Davis Graham & Stubbs LLP 1550 17th Street, Suite 500 Denver, CO 80202 • • QUITCLAIM DEED THIS DEED, dated October 31, 2001, between UNION OIL COMPANY OF CALIFORNIA, a corporation duly organized and existing under the laws of the State of California, Grantor, whose legal address 376 S. Valencia Avenue, Brea, California 92823, and WILLIAMS PRODUCTION RMT COMPANY, a corporation duly organized and existing under and by virtue of the laws of the State of Delaware, Grantee, whose legal address is 1515 Arapahoe, Suite 1000, Denver, Colorado 80202: WITNESS, that the Grantor, for and in consideration of the sum of TEN AND NO/100 DOLLARS, the receipt and sufficiency of which are hereby acknowledged, has remised, released, sold and QUITCLAIMED, and by these presents does remise, release, sell and QUITCLAIM unto the Grantee, its successors and assigns forever, all the right, title, interest, claim and demand which the Grantor has in and to the following described water rights and well rights: SEE EXHiBIT A ATTACHED HERETO AND INCORPORATED HEREIN BY REFERENCE Said water rights and well rights being appurtenant to the following described real property, situate, lying and being in the County of Garfield and State of Colorado, described as follows: SEE EXHIBIT 13 ATTACHED HERETO AND INCORPORATED HEREIN BY REFERENCE [REMAINDER OF PAGE INTENTIONALLY LEFT BLANK] 1 1111 Mil1111111ll il111111111111E_dil1111I111 1320 11/05/2001 03:09P 91300 P415 hS RL5DORF )f 7 R 35.00 D 0.00 GRRFIELD COUNTY CO • IN WITNESS WHEREOF, the Grantor has caused its corporate name to be hereunto subscribed by its attorney-in-fact, .and its corporate seal to be hereunto affixed, on this 29th day of October, 2001, to be effective as of October 31, 2001. UNION OIL COMPANY OF CALIFORNIA, a California corporation By: Edward A. Wong, Att y -in -Fact [Unocal — attach, appropriate Acknowledgment] :CALIFC3NIA ALL-PURPOSE ACKNOWLEDGMENT sIle of: C ctrlty of Q /eht/U'&6 Ci7-4VieLie0 .a2(/ Dale before me, •Z` p anally appeared .0O2)t)."R prsonally known to me — OR – ❑ proved lti --- h A_ ,0%._ - A Jf1 SANDRA E. CAMPBELL COMM. #1188922 -0 NOTARY Puauc • CALIFORNIA - ORANGE COUNTY r•,. My Comm. txpires July 31.2042 1111!111111111111111111111 1IlI1 !1111111111111!!1 1111 91320 11/0512001 03:09P B1300 P416 11 ALSDOiRF 3 of 7 R 35,0 D 0.00 GARFIELD COUNTY CO ame anci rtie of OClicex (e•1)„ 'ran. 4. 66)41/1/o- /TA- prsonally -)d/1/o- /1417: . Notary Pubbc1 Nametsi of Signer(s) to me on the basis of satisfactory evidence to be the persons whose name) is/a subscribed to the within instrument and acknowledged to me that held It ey executed the same in his/#efitheir authorized capacity(ies), and that by his/ +er/tl k-signaturefrs)'on the instrument the person($ or the entity upon behalf of which the person(zracted, executed the instrument. WITNESS my hand and official seal_ OPTIONAL tz-extil Wre Nolan/ Signa ry T7Nugh the information below is not required by law, if may prove valuable ro persons relying on the document and could prevent fraudulent removal and reattachment of this farm to another document. Description of Attached Document Title or Type of Document: r' c i- -' P Dow -tient Date- /0/3/ / d ( Number of Pages: 6 Siger(s) Other Than Named Above: Opacity(i-es) Claimed by Signer(s)' Sigler's Name: .F�1a ai .4. tc7 eAl ID Individual O Corporate Officer Ttle(s): O Partner — 0 Limited 0 General . Attorney -in -Fact O Trustee O Guardian or Conservator O Other: Signer Is Representing: /I ire/1 a/ (tar /J 1 e ; I / RIGWt7H171NBPFUNT vOFS1GN€F# >" Top of thumb here Signer's Name: ❑ Individual ❑ Corporate Officer Title(s): • Partner — 0 Limited ❑ Attorney -in -Fact ❑ Trustee ❑ Guardian or Conservator ❑ Other: 0 General Signer Is Representing: 01994 NaIlona! Nctary AssoctaIon • 0236 Rernmet Ave , P.O. Bax 7184 • Canoga Park, CA 91909.7184 1 r. Top of thumb here Prod. No. 491)7 Reorder Call To6 Free 1.800.676.6827 Hill Hill Milli 1111111111111i1111I P, Jill Hl 1111 1320 11/05/2001 03:09P B1u0 P417 ii ALSDORF of 7 R 35.00 D 0.00 GARFIELD COUNTY CO EXHIBIT A 11/ Water and Well Rieghts 1. Union 76 Water Well No. 6: (a) (b) Location: In the NW 1/4 of the NE1/4 of Section 33, Township 6 South, Range 96 West of the 6`h P.M., at a point 1150 feet from the north section line and 2300 feet from the east section line of said Section 33. Decree: Decree entered by the District Court in and for Water Division No. 5, State of Colorado in Case No. 82CW433 on April 19, 1985. By decree entered by the same court in Case No. 95CW164 on April 12, 7996, the conditional water right for this well was made partially absolute and the remaining conditional water right was abandoned. (c) Decreed rate of flow: 0.722 cubic feet per second (325 gallons per minute), absolute. (d) Well Permit No. 26068-F. 2, Union 76 Water Well No. 6A. • (a) • (b) (c) Location: In the SW 114 of the NE1/4 of Section 33, Township 6 South, Range 96 West of the 6th P.M., at a point 1 500 feet from the north section line and 2150 feet from the east section line of said Section 33. Decree: Decree entered by the District Court in and for Water Division No. 5, State of Colorado in Case No. 82CW433 on April 19, 1985. The conditional water rights associated with this well were subsequently cancelled by decree of the same court in Case No. 95CW164 entered on April 12, 1996. Decreed rate of flow: This well was originally decreed as a supplemental well to Union 76 Water Well No. 6 in the amount of 0.134 cubic feet per second (60 gallons per minute), conditional, provided that the combined pumping rate of this well and Union 76 Water Well No, 6 was not to exceed 1.0 cubic feet per second. The water right for this well was not exercised by Union 01.1 Company and the conditional water right associated with this well was cancelled by the decree in Case No. 95CW164. (d) \\Tell Permit No. 26069-F. Union 76 Water Well Nos. 6 and 6A were previously included in a plan for augmentation approved by decree of the District Court in and for Water Division No. 5, State of Colorado, in A-1 11111(11111111111 1111 111 111 111111 .1111111111111 591320 11/05/2001 03:09P 81300 P418 M RLSOORF 5 of 7 R 35.00 D 0.00 GARFIELD COUNTY CO Case No. W-2206. The conveyance of Union 76 Water Well Nos. 6 and 6A and the water rights described above includes no interest in the augmentation plan approved in Case No. W-2206 and no interest in any of the water rights included in the decree in Case No. W-2206. • Union 76 Water Well Nos. 6 and 6A were also adjudicated as alternate points of diversion for water rights of the Pumping Pipeline of Union Oil Company of California in a decree of the District Court in and for Water Division No. 5, State of Colorado in Case No. 81CW319 on May 5, 1983. The conveyance of Union 76 Water Well Nos. 6 and 6A and the water rights described above includes no interest in the Pumping Pipeline water rights and no interest in any other water rights involved in Case No. 81CW319. Unocal makes no representation or warranty concerning the amount of water that may be available in priority to the wells under the water rights adjudicated in Case No. 82CW433. Pursuant to the decree in Case No. 82CW433, the pumping rate of Union 76 Water Well Nos. 6 and SA, combined with that of Union 76 Water Well Nos. 2, 3, 4 and 5, was limited to 1000 gpm. Union 76 Water Well. Nos. 2, 3, 4 and 5 have decreed priorities senior to that of Union 76 Water Well Nos. 6 and GA. Consequently, the pumping from Union 76 Water Well Nos. 6 and 6A may be limited if the total pumping, when combined with that of Union 76 Water Well Nos. 2, 3, 4 and 5, would exceed 1000 gallons per rninute. Interest in Irrigation Ditches and Related Easements The subject property was historically irrigated with diversions from the following ditches: 1. The Low Cost Ditch, the headgate of which is located on Parachute Creek in Lot 13 of Section 17, Township 6 South, Range 96 West of the 6th P.M. at a point whence the south quarter corner of said Section 17 bears south 18 11' west a distance of 789.61 feet. 2. The Riley Ditch, the headgate of which is located on Parachute Creek in Lot 1 of Section 4, Township 7 South, Range 96 West of the 6th P.M. at a point whence the northeast corner of said Section 4 bears north 74 08'07" east a distance of 524.04 feet. 3. The Starkey Gulch Ditch, the headgate of which is located at a point on the south bank of Starkey Gulch whence the northwest corner of Section 33, Township 6 South, Range 96 West of the 6th P.M. bears north 60 27' east a distance of 1073 feet. The water rights associated with the above-described ditches have been previously sold by Unocal. Therefore, no interest in any water rights associated with said ditches is included in the conveyance by Unocal to Williams. To the extent Unocal retains any interest in the ditch structures or related easements for use, operation or maintenance of said ditches, Unocal hereby quit claims such interest to Williams. A-2 WI 1111111 11111 ... 4111111141111 '191320 11/05/2001 03:09P B1300 P419 M PLSDORF of 7 R 35.00 0 0.00 GARFIELD COUNTY CO EXHIBIT B LEGAL DESCRIPTION - LOWER VALLEY A tract of land located in Section 4, Township 7 South and in Sections 27, 28, 29, 32, 33 and 34, Township 6 South, all in Range 96 West of the Sixth Principal Meridian, Garfield County, Colorado, being more particularly described as follows_ Beginning at the northeast corner of said Section 4, thence 5 07°32'09" W along the east line of said Section 4 a distance of 1341.94 feet to the southeast corner of the NE1/4 NE1/4 of said Section 4; thence N 8714'02" W along the south line of the said NE1/4 NEI/4 a distance of 1301.32 feet to the southwest corner of the said NE1/4 NE1/4; thence N 07°39'45" E along the west line of the said NE1/4 NE1/4 a distance of 1314.49 feet to the northwest comer of the said NE114 NE1/4; thence N 88°2773" W along the north line of said Section 4 a distance of 1300.90 feet to the north quarter corner of said Section 4; thence N 00°16'42" E along the north -south centerline of said Section 33 a distance of 1329.61 feet to the northeast comer of Lot 10 (SE114 SW1/4) of said Section 33; thence N 88°30'49" W along the north line of Lots 10 & 9 (S1/2 SW1/4) a distance of 2651.59 feet to the northwest corner of the said Lot 9 (SW1/4 SW1/4); thence N 88°50'57" W along the south line of Lot 5 (NE1/4 SEI/4) of said Section 32 a distance of 1360.67 feet to the southwest corner of said Lot 5; thence N 00°1278" E along the west line of said Lot 5 a distance of 1323.15 feet to the northwest corner of said Lot 5; thence N 89°01'03" W along the east -west centerline of said Section 32 a distance of 1348.85 to the center of said Section 32; thence N 89°01'35" W continuing along said east -west centerline a distance of 1339.03 feet to the southwest corner of the SEI/4 NWI/4 of said Section 32; thence N 01°01'47" E along the west line of the said 5E1/4 NW 1 /4 and Lot 1 ('NE 114 NW 114) of said Section 32 a distance of 2666.55 feet to the northwest comer of the said Lot 1; thence N 00°59'42" E along the west line of Lot 11 (SE I14 SW1/4) of said Section 29 a distance of 1333.93 feet to the northwest corner of said Lot 11; thence 5 88°43'09" E along the north line of said Lot 11 a distance of 1316.98 feet to the northwest corner of Lot 12 (SW1/4 SE1/4) of said Section 29; thence S 88°4179" E along the north line of said Lot 12 and the SEI/4 SE1/4 a distance of 2664.16 feet to the northeast corner of the said SE1/4 SE1/4; thence N 01010'58" E along the east line of said Section 29 a distance of 339.19 feet to a point in the center of Parachute Creek; thence along the center of Parachute Creek the following seventeen courses: N 85°09'46" E a distance of 70.44 feet; thence N 27°58'40" E a distance of 192.27 feet; thence S 55°46'05" E a distance of 234.65 feet; thence N 88°57'30" E a distance of 55.01 feet; thence N 38°03'42" E a distance of 26926 feet; thence 83°39'35" E a distance of 27.17 feet; thence S 18°52'28" E a distance of 123.65 feet; thence 5 02°34'59" E a distance of 33.14 feet; thence 5 19°08'01" W a distance of 103.73 feet; thence S 18048'43" E a distance of 96.14 feet; thence 111, S 02°33'50" W a distance of 67.07 feet; thence S 22°25'33" E a distance of 68.15 feet; thence N 61°25'10" E a distance of 152.59 feet; thence N 86°30'38" E a distance of 82.15 feet; thence S 74°50'45" E a distance of 149.19 feet; thence 5 49°20'18" E a distance of 102.83 feet; thence S 02°00'14" W a distance of 22.59 feet to the intersection of the center of Parachute Creek and the north line of the 51/2 SW1/4 of said Section 28; thence 5 82055'16" E along the north line of the said 51/2 SW1/4 a distance of 601.13 feet; thence N 50°24'42" E a distance of 783.92 feet; thence S 48°49'12" E a distance of 460.39 feet to a point on the north -south centerline of said Section 28; thence N 00008'06" E along said centerline a distance of 1090.98 feet to the center of said Section 28; thence S 88°11'54" E along the east -west centerline of said Section 28 a distance of 1349.87 feet to the northeast corner of Lot 8 (NWI/4 SEI/4) of said Section 28; thence 5 00°33'55" W along the east line of said Lot 8 a distance of 1308.19 feet to the southeast corner of said Lot 8; thence 5 88°03'07" E along the north line of Lot 13 (SE1/4 SEI/4) of said Section 28 a distance of 1339.74 feet to the northeast corner of said Lot 13; thence S 88°37'54" E along the north line of Lot 13 (SW1/4 SW1/4) of said Section 27 a distance of 1351.61 feet to the northeast corner of said Lot 13; thence 5 00°51'16" W along the east line of said Lot 13 a distance of 1312.64 feet to northeast comer of Lot 2 (NW 114 NW 114) of said Section 34; thence 5 01°27'22" W along the east line of said Lot 2 a distance of 1330.99 feet to the southeast corner of the said Lot 2; thence N 88°37'31" W along the south line of the said Lot 2 a distance of 1341.75 feet to the southwest comer of said Lot 2; thence N 83014'04" W along the north line of Lot 5 (5E1/4 NE1/4) of said Section 33 a distance of I322.30 feet to the northwest corner of said Lot 5; thence S 00°34'11" W along the west line of said Lot 5 a distance of 1339.89 feet to the southwest corner of said Lot 5; thence S 88°34'10" E along the south line of said Lot 5 a distance of 1315.02 feet to the southeast corner of said Lot 5; thence 5 G0°52'13" W along the west line of Lot 10 (NW 114 SWI/4) of said Section 34 a distance of 1293.90 feet to a point on the west line of said Lot 10; thence 5 83004'000 E a distance of 209.60 feet; thence N 01°5600" E a distance of 559.70 feet; thence 5 88°04'00" E a distance of 714.70 feet; thence N 01°58'00" E a distance of 634.10 feet; thence 5 8S°01'00„ E a distance of 380.13 feet to a point on the east line of said Lot 10; thence S 01°2973" W along the east line of Lots 10 & 11 of said Section 34 a distance of 2558.09 feet to the southeast comer of said Lot 11, thence N 88°18'20" W along the south line of said Lot 11 a distance of 1299.91 feet to the northeast corner of said Section 4, the point ofbeginning, containing 1333.01 acres more or less. 0 B-1 1�}1L 111illlllIkI111t1i1111111311(,..�llli 91323 11105/2001 03:e9P 131340 P420 M RLSDORF ` of 7 R 35, Oe D 0.03 GRRFIELD COUNTY CO LEGAL DESCRIPTION - SECTION 1 PROPERTY 0tract of land situated in Section 1, Township 7 South, Range 96 West of the Sixth Principal Meridian, Garfield County, Colorado, being more particularly described as follows: Beginning at the SW corner of the NW 114 SW1/4 of said Section 1, thence N 06'30'11" E along the west line of said Section 1 a distance of 1335.77 feet to the W1/4 comer of said Section 1; thence N 07°07'36" E a1ong the west line of said Section 1 a distance of 1142.73 feet to the SW corner of Lot 4 of said Section 1; thence N 07°09'38" E along the west line of said Lot 4 a distance of 1159.92 feet to the northwest corner of said Lot 4; thence S 89°20'03" E along the north line of said Lot 4 a distance of 1320.88 feet to the NE corner of said Lot 4; thence S 06°46"32" W along the east line of said Lot 4 a distance of 116024 feet to the SE corner of said Lot 4; thence 5 89'11'01" E along the south line of Lot 3 of said Section 1 a distance of 1327.96 feet to the SE corner of said Lot 3; thence N 0624"38" E along. the east line of said Lot 3 a distance of 1 163.73 feet to the NE corner of said Lot 3; thence N 83°10'31" E along the north line of Lot 2 of said. Section 1 a distance of 1230.72 feet to the NE corner of said Lot 2; thence S 05°56'38" W along the east line of said Lot 2 a distance of 1245.99 feet to the SE corner of said Lot 2; thence N 86°57'47" E along the south line of Lot 1 of said Section 1 a distance of 1224.86 feet to the SE corner of said Lot 1; thence 5 O5°29'58" W along the east line of said Section 1 a distance of 1327,08 feet to the E1/4 comer of said Section 1; thence 5 00°44'31" W continuing along the east line of said Section 1 a distance of2665.1 1 feet to the SE corner of said Section 1; thence N 88°53'33" W along the south line of said. Section 1 a distance of 594.83 feet to the SE corner of the Grand View Industrial Center; thence N 01°08'47" E along the east line of the Grand View industrial Center a distance of 361.67 feet; thence N 86°13'49" W along the north line of the Grand View Industrial Center and the EXXON parcel a distance of 2077.00 feet to a point on the north -south centerline of said Section 1; thence N 06°23'14" E along said north -south centerline a distance of 876.15 feet to the NE corner of the 5E1/4 SWI/4 of said Section 1; thence N 88°53'31" W along the north line of said SEI14 SW1/4 a distance of 1335.48 feet to the NW corner of said SE114 SW1/4; thence S 06°26'49" W along the west line of said 5E1/4 SW 114 a distance of 559.54 feet to a point on the southerly right-of-way line of the railroad; thence N 51'43'07" W along said right-of-way a distance of 922.01 feet to a point on the south line of the NW 114 SW1/4 of said Section 1; thence N 83°53'31" W along said south line a distance of 549.47 feet to the SW corner of said NW 114 SW1/4, the point of beginning, containing 432.13 acres. 0xcluding, however, any' rights to or interest in any mineral of any nature whatsoever which might underlie the surface of the inds described above. The foregoing exclusion applies to all lands described an Exhibit B. B-2 IllI H1 111 IIIIIIIIiIIII III VIII, 111! III 591318 11/05/2001 02:59P B1300 P392 M ALSDARF 1 of 18 R 50.00 0 153.60 GARFIELD COUNTY CO AFTER RECORDING, RETURN TO: Janet N. Harris, Esq. Davis Graham & Stubbs LLP 1550 17th Street, Suite 500 Denver, CO 80202 SPECIAL WARRANTY DEED GRANTOR, UNION OIL COMPANY OF CALIFORNIA, a corporation duly organized and existing under and by virtue of the laws of the State of California, whose legal address is 376 S. Valencia Avenue, Brea, California 92823, for the consideration of Ten and 001100t Dollars ($10.00), in hand paid, hereby sells and conveys to WIT LIAMS PRODUCTION RMT COMPANY, a corporation duly organized and existing under and by virtue of the laws of the State of Delaware, Grantee, whose legal address is 1515 Arapahoe Street, Tower 3, Suite 1000, Denver, Colorado 80202, all the real property, together with improvements, if any, situate, lying and being in the County of Garfield and State of Colorado, to wit: SEE EXHIBIT A ATTACHED HERETO AND INCORPORATED HEREIN BY REFERENCE with all its appurtenances, and warrants the title to the same against all persons claiming under Grantor, subject to taxes for the current year, a lien not yet due or payable, and subject to all matters listed an attached Exhibit B. The preceding warranty is intended by Grantor to be made to Grantee only and is not intended to benefit any future owner or encumbrancer of the property and shall not run with the land. IN WITNESS WHEREOF, the Grantor has caused its corporate name to be hereunto subscribed by its attorney-in-fact, and its corporate seal to be hereunto affixed, on this 29th day of October, 2001, to be effective as of October 31, 2001. UNION OIL COMPANY OF CALIFORNIA, a California corporation By: Edward A. Wong, At o ey-in-Fact [Unocal — attach appropriate Acknowledgrnentj 1 CALIFORNIA ALL-PURPOSE ACKNOWLEDGMENT State of County of /r 1- r Fv it' /1///7 On UOTr of 9 Dale personally appeared 11111 Alii 1111111111111111111111111 11111111 ID 591318 11/05/2001 02:59P 81300 P393 n PLSDCRF 2 of 18 R g0,00 D 153,60 GARFIELD COUNTY CO before me Dr°,v /r.f)r77[/7174rCsf-61/e Name and TTCle 6r Cr1cer {e „g., 'Jane ride, 'apiary Public") J3''personally known to me -- OR – ❑ proved f1 SANDRA E. CAMPBELL COMM. #11B8922 4' J - NOTARY PU81-FC • CALIFORNIA ORANGE COUNTY My Cohn Expires _My 31, 2002 Namets) of S,perlsj to me on the basis of satisfactory evidence to be the person(e whose namefs) islai a subscribed to the within instrument and acknowledged to me that helsh-elthey executed the same in hislberltbeir authorized capacity(ie`s), and that by his/r/their signature(sron the instrument the person(ar or the entity upon behalf of which the person acted, executed the instrument. WITNESS my hand and official seal. Signature 01 Nolary Public OPTIONAL Though the information below is not required by law, it may prove valuable to persons retying on the document and could prevent fraudulent removal and reattachment of this form t0 another document. Description of Attached Doctament Document Date: Title or Type of Document: Signer(s) Other Than Named Above: Capacity(ies) Claimed by Signer(s) Signer's Name: E -ID AeVEDA. Gz DN' Number of Pages: /t7 ❑ Individual • Corporate Officer Title(s): El Partner — ❑ Limited Cl General O Attorney -in -Fact ❑ Trustee O Guardian or Conservator O Other: Signer 1s Representing: L24a'.7 rJ/C�1'Pe7 c 6/: 76r4/ - S gner's Name: - {� Individual O Corporate Officer Title(s): O Partner — G Limited 0 General O Attorney -in -Fact ❑ Trustee O Guardian or Conservator ❑ Other: Signer Is Representing: I• Prod. No. 5907 Reorder Cad Toile -Free l-5oa875.582? 1111111 11111111111111111111111111111111 1111 1111111 591318 11/05/2041 02::59P 613071 P394 11 R RF 3 of 18 R 90.00 D 153.64 GARFIELD COUNTY CO • • EXHIBIT A Legal Description Parcel Number 7684 Book: 320 Pau: 50 Date: August 31, 1959 Grantor: United States of America Grantee: Union Oil Company of California Lots 11 and 12 in Section 29, Lot 1 in Section 32, Lots 4, 7 and 8 in Section 33, T. 6 S., R. 96 W., of the 6th P.M., Garfield County Colorado. Parcel Number 7674 Book: 296 Page: 39 Date: October 20, 1956 Grantor: Mary B. Bailey Grantee: Union Oil Company of California. All of the SE °h SE 1/4 of Section 29, all of the N '/2 NE '/4, the SW V. NE °/ and the SE 1/4 NW '/ of Section 32, and that portion of the W %2 W '14 of Section 28 and of the N '/2 NW 1/4 of Section 33, described as follows, to -wit: Beginning at a point which is the Section comer common Sections 28, 29, 32 and 33; thence N. 0°30'W., 1690 feet to Corner No. 1; thence N. 86°42'E., 339 feet to comer No. 2; the Course and distance corner No. 1 and comer No. 2 being the center line of Parachute Creek; thence S. 12°56'W., 788 feet to corner No. 3; thence S. 40°59'E., 660 feet to corner No. 4; thence S. 4°06'E., 755 feet to Comer No. 5; thence S. 69°29'E., 423 feet to Comer No. 6; thence S. 37°11'E., 797 feet to Comer No. 7; thence S. 42°28'E., 342 feet to corner No. 8; thence S.89°18' W., 1703 feet to comer No. 9; thence N.1 °50' W., 1367 feet to the point of beginning. All in T. 6 S., R. 96 W. of the el P.M. Also, that land conveyed to grantor herein, by deed recorded as Document No. 134699 in book 192 at page 367 of the Garfield County Records. Parcel Number 7685 Book: 336 Page: 581 Date: September 27, 1961 Grantor: United States of America Grantee: Union Oil Company of California Lots 4 and 5, Section 32, T. 6 S., R. 96 W. of the 6th P.M., Garfield County Colorado. A-1 iiniiumuiiimii sii 111 111..nuEll ill . 591318 11/05/2001 02:59P 81300 P395 11 RLSDORF 4 of 18 R 90.01 D 153.60 GARFIELD COUNTY Co • • • Parcel Number 7672 A&B Book:326 Page:220-222 Date: June 2, 1960 Grantor: L.L. Tuck Grantee: Union Oil Company of California The following lands in Section 33, T 6 5, R 96 W, of the 6th P.M., Garfield County, Colorado: The SE 1/4 NW 1/4, the SW 114 NE 1/4 and the SE 1/4 (Lots 6,11, 12 and NW 1/4 SE 1/4 ). The following lands in Section 4, T 7 5, R 96 W, of the 6th P.M., Garfield County, Colorado: Lot 1 (NE 1/4 NE 1/4 ). Parcel Number 7670 A Book:326 Page:220-222 Date: June 2, 1960 Grantor: L.L. Tuck Grantee: Union Oil Company of California The following lands in Section 34, T 6 5, R 96 W, of the 6th P.M., Garfield County, Colorado: Lot 10(NW 1/4 SW 1/4)and Lot ll (SW 1/4 SW 1/4) Except that part of Lot 10 ( NW 1/4 SW 1/4 ) of Section 34, Township 6 South, Range 96 W. of the 6-11 P.M. lying North and West of a line described as beginning at a point, Corner No. 1, on the Westerly right of way line of the County Road, whence the west 1/4 corner of said Section 34, bears N.83°42' W., 1316 feet; thence N. 88°01'W., 363.5 feet to Corner No. 2; thence S. 1°58'W., 634.1 feet to Comer No. 3; thence N. 88°04'W. 714.7 feet to Corner No. 4; thence S. 1°56'W., 559.7 feet to Comer No. 5; thence N. 88°04'W.,167 feet more or less to Corner No.6, a point on the West line of said Section 34. Parcel Number 7667 Book:326 Page:220-222 Date: June 2, 1960 Grantor: L.L. Tuck Grantee: Union Oil Company of California Parcel 7667 is more particularly described in Book 297, Page 568 as follows:: All the following described lots or parcels of land, to -wit: Beginning at a point in the North and South centerline of Section 33, T. 6 S., R. 96 W. of the 66 P.M. Garfield County, Colorado, which point bears A-2 1E11111 IiIi 1111 11111 111i111Jill h. 4 11 1111 591318 11/05/2001 02:59P 61300 P345 tt RLSDORF 5 of 18 R 90.00 D 153.60 GARFIELD COUNTY CO • • • S. I°22'E_, 250 feet from the N 1/4 corner of said Section 33; thence S. 1°22'E, 50 feet along said centerline of Sec. 33; thence south easterly to a point in the east boundary line of the NW 1/4 NE t/., or Lot 2, of said Section 33, which point bears S. 1°05'E., 472 feet from the NE corner of said Lot 2; thence N. 1°05'W., 472 feet to the NE corner of said Lot 2; thence N 0°55' W., 442' along the E. boundary of the SW 1/4 SE 'I4, or Lot 12, of Section 28, T. 6 S., R. 96 W. of the 6th P.M.; thence N. 49018'W., 74 feet; thence S. 60°02'W., 1460 feet to the place of beginning, containing 17.38 acres, more or less. Together with a tract of land situated in the SE °/. SW 1/4, SW 1/4 SE 1/4, Section 28, and the NW 1/4 NE'/., Section 33, all in T. 6 S., R. 96 W. of the 6th P.M., Garfield County, Colorado, and more fully described as follows: Beginning at the S '/. corner of said Section 28; thence S.1°22'E., 250 feet; thence N. 60°02'E., 1460 feet; thence N. 49°18'W., 255 feet; thence N. 50041'W., 89.12 feet; thence S.56°31'W., 1274.86 feet to the South line of said Section 28; thence N. 88039'E., 55.1 feet to the point of beginning, containing 8.72 acres, more or less. EXCEPT those portions thereof lying within Garfield County Road No. 215. Parcel Number 7676 Book:326 Page:220-222. Date: June 2, 1960 Grantor: L.L. Tuck Grantee: Union Oil Company of California Parcels 7676 more particularly described in Book 297, Page 458-459 as follows: A tract of land described as beginning at a point in the South line of Section 28, T.6.S., R.96.W. of the 6th P.M., which point bears S. 8$ 39'W., 1676.6 feet from the South'/. corner of said Section 28; thence N. 1°10'W., 1318 feet to a point in the North line of the SW 1/4 SW '/, or Lot 10 of said Section 28; thence N. 89°50'E. along said North line of said Lot 10, to the centerline of Parachute Creek, thence Southeasterly down the centerline of said Parachute Creek to its intersection with the South line of said Section 28, thence S. 88°39'W. along the South line of said Section 28, to the place of beginning. Beginning at a point in the North line ofa SW'/. SE "/. or Lot 12 of Section 28, T.6 S., R.96.W. of -the 6th P.M., which point bears S. 89°50'W., 535 feet from the NE corner of said Lot 12; thence S. 89°50'W., 416 feet along the North line of said Lot 12; thence S. 45 °44'E., 116.8 feet; thence S. 20°02' W., 302.5 feet; thence S. 34°15'W., 59 feet; thence N. 82°26'E., 272 feet; thence N. 29°25'E., 116 feet; thence N. 27°04'E., 313 feet to the place of beginning, except right of way for County road as now located containing 2.59 acres, more or less. Also beginning at a point in the South line of said Section 28 which point bears S. 88039'W., 224 feet from the South quarter corner of said Section 28; thence N.41°43'E., 492.7 feet; thence N. 1°07'E., 384 feet; thence S. 5727'W., 1167 feet; thence S. 18°08'W., 147.5 feet to a point in the South line of said Section 28; thence N. 88°39'E., 695.6 feet along the South line of said Section 28 to the place of beginning, containing 8.59 acres, more or less. A-3 JIiH 111111111111111 1111 1'flii 11111t� � 11� I 1ii11! 591318 11/05/2001 02:59P 81300 P397 11 ALSDORF e of 18 R 90.00 D 153.60 GARFIELD COUNTY CO • • A tract of land situated in the SE % SW ''A and SW '/YSE''A Section 28, T.6.S, R.96.W. of the 6th P.M., and more fully described as follows: Beginning at a point whence the 5 'A comer of said Section 28 bears N. 88°39'E., 55.1 feet; thence N. 56°31'E., 1274.86 feet; thence N. 50°41'W., 481.88 feet; thence 5 29°25'W., 116.0 feet; thence S.82°26'W., 272.0•feet; thence S.57°59'W., 233.0 feet; thence S. 1°07'W., 384.0 feet; thence S. 41°43'W., 492.7 feet to the South line of said. Section 28; thence N 88°39'E., 168.9 feet to the point of beginning containing 10.47 acres more or less. EXCEPT those portions thereof lying within Garfield County Road No. 215. All the above-described land is situate in the County of Garfield, State of Colorado. Parcel Number 7677 Book:326 Page:220-222 Date: June 2, 1960 Grantor: L.L. Tuck Grantee: Union Oil Company of California Parcels 7677 are more particularly described in Book 296, Page 473-474 as follows: All of lot 8, Sec. 28, T.6.S., R.96.W. of the 6th P.M., containing 40.28 acres; Also beginning at a point in the North line of the SW '/ SE 'A, or Lot 12, of Sec. 28, T.S.S., R.96.W. of the 6th P.M., which point bears S 89°50'W., 951 feet from the NE comer of said Lot 12, thence S 89°50'W., 1148 feet along the N. line of said Lot 12 produced, thence S 18°32'E., 962 feet, thence N 57°27'E., 702 feet, thence N 57°59'E., 233 feet, thence N 34°15E., 59 feet, thence N 20°02'E., 302.5 feet, thence N 45°44'W., 116.8 feet to the place of beginning, excepting a right-of-way for the County road as now located and containing 15.97 acres, more of less. Also beginning at the NE comer of said SW '/< SE'/, or Lot 12, thence S 0°55'E., 857 feet along the East line of said Lot 12, thence N 49°18'W., 329 feet; thence N 50°41'W., 571 feet, thence N 27°04'E., 313 feet to a point in the North line of said Lot 12, thence N 89050'E., 535 feet along the North line of said Lot 12 to the place of beginning, excepting right-of-way for the County road as now located, and containing 8.41 acres, more or less. Also that pari of the NE 'A SW ''A of Section 28, described as follows: Beginning at the SE corner of said NE ''A SW '/, thence N, 214 feet, thence N 470 W., 463 feet, thence S 50° W., 798 feet; thence E, 965 feet to the place of beginning, containing 6.45 acres, more or less. Also that part of the S '/ SW '/. of said Section 28 described as follows: Beginning at a point which is 453 feet East of the NE corner of the SW ''A SW '/. of said Section 28, thence W. 675 feet to Parachute Creek, thence in a southeasterly direction along said Parachute Creek 200 feet to a fence now constructed and in place, thence in a Northeasterly direction along said fence 621 feet to the point of beginning, containing 1 acre, more or less. A-4 1 111111 Hill 11 111 1 11111 111 Illl 111111 4111111111 591318 11/05/2001 02:59P 81300 P338 M RLSDORF 7 of 18 R 90.00 D 153.60 GARFIELD COUNTY CO • • Also beginning at a point where the East and West centerline of the S '/2 of said Section 28 intersects the Westerly line of the County Road as now constructed and in place, thence West along said centerline to a point on the west bank of the Low Cost Ditch, as now constructed and in place, thence Southerly along said West bank to a point where said bank intersects the Northerly line of what is known as the Wheeler road as now constructed and in place, thence along said Northerly line to a point where it intersects the said Westerly line of the County road, thence along said Westerly line of the County road to a point of beginning, containing approximately 1 '/x acres and being in the SW 'A SE 'A and the SE 'X SW ''/ of said Section 28; EXCEPT those portions thereof lying within Garfield County Road No. 215. All the above-described land is situate in the County of Garfield, State of Colorado. Parcel Number 7666 Book: 326 Page: 220-222 Date: June 2, 1960. Grantor: L.L. Tuck Grantee: Union Oil Company of California Parcel 7666 is more particularly described in Book 295, Page 41 as foIIows: Lot 13 of Section 27, Lot 13 of Section 28 and Lot 2 of Section 34, all in T.6.S., R.96.W of the 6th P.M., Garfield County, Colorado. Also, a certain tract of land containing 6.266 acres, more or less, described as follows, to -wit: Beginning at a point, Corner No.1, whence the 1/4 corner common to Sections 33 and 34, Township 6 South, Range 96 W. of the 6th P.M., bears 5 23°18' E, 2376.5 feet; thence N 26°08' E, 554.4 feet to Corner No.2; thence N 88°36' W, 695.6 feet to Corner No.3; thence S 4° E, 468.7 feet to Corner No.4; thence S 83°44' E, 425.1 feet to Comer No.1, the point of beginning. EXCEPT those portions thereof lying within Garfield County Road No. 215. Parcel Numbers 7694 13 Book: 414 Page: 62-78 Date: October 15,1970 Grantor: ARCO,CLIFFS,SOHIO & TOSCO Grantee: Union Oil Company of California Parcels 7694B are more particularly described in Book 411, Page 576, A-5 1 11 111111111 111111 III II1H lIIll 1111 lir =i 111111 ifli 591318 11/05/2001 02:59P 81300 P399 M ALSDORF 8 of 18 R 90.00 D 153.60 GARFIELD COUNTY CO • • • Parcel A: The East 10 acres of the NE 1/4 NE 1/4 of Section 33, T.6.S., R.96.W. of the 6th P.M., Garfield County, Colorado. EXCEPT those portions thereof lying within Garfield County Road No. 215. Parcel B: That part of the NE 1/4 NE 1/4 of Section 33, T.6.S., R.96.W. of the 6th P.M., Garfield County, Colorado, described as follows: Beginning at a point whence the 1/4 corner common to Sections 33 and 34, said Township 6, bears South 23°18' East 2376.5 feet, said point being the SE corner of the Sandstrom land; thence North 26'°08' East along the Sandstrom easterly line, 554.4 feet to the North line of said NE 1/4 NE 1/4; thence East to the NW corner of the East 10 acres of said NE 1/4 NE 1/4; thence South along the West line of said East 10 acres to Benton Lane, being a point 20 feet North of the South line of said NE 1/4 NE 1/4; thence West along the North line of said Benton Lane, -682 feet; thence North 845 feet to the Southerly line of the Sandstrom land; thence South 83°44' East along the Sandstrom southerly line, to the point of beginning. EXCEPT those portions thereof lying within Garfield County Road No. 215. Parcel C: Beginning at a point in the South line of Section 28, T. 6. S., R.96.W. of the 6th P.M., Garfield County, Colorado, which point bears S 88°39' W., 919.6 feet from the South 1/4 comer of said Section 28; thence N.18°08'E., 147.5 feet; thence N 57°27'E., 465 feet; thence N 18°32'W., 962 feet to a point in the North line of the SE'/. SW '/ or Lot 11, of said Section 28; thence 5 89°50'W. along the North line of said Lot 11 produced, to the centerline of Parachute Creek; thence Southeasterly down the centerline of said Parachute Creek to the South line of said Section 28; thence N 88°39'E. along the South line of said Section 28 to the place of beginning. Parcel Number 7698 Book: 582 Page: 352 Date: September 11, 1981 Grantor: Evelyn G. McKay Grantee: Union Oil Company of California A parcel of land situate in the SW 1/4 SW 1/4 of Section 1, T. 7 S., R. 96 W. of the 6'" P.M., more particularly described as follows: Beginning at the NE Corner of the SW '/ SW 1/4 of said Section 1; thence along the East line of said SW 1/4 SW 1/4, S06°26' 13"W. 77.0 feet with ail bearings contained herein being Colorado Grid Bearings (Central Zone). True Bearings are obtained by rotating bearings herein counter -clockwise O1°37'28"; thence S 41°25'02"W. 411.02 feet to the intersecting point with the southwesterly right-of-way of a railroad alignment; thence along, said southwesterly right-of-way A-6 1Ill Ii 11III11111(1Il1II 1111111 111 591318 11/05/2001 02:59P B1300 P40@ M ALSDORF 9 of 18 R 90.00 0 153.60 GRRFIELD COUNTY CO • • N51°43'07"W. 63.24 feet to a point alongside a fence bearing northeasterly and southwesterly; thence alongside and a projection of said fence N39°37'28"E. 311.11 feet to a point alongside a fence bearing northerly and southerly; thence alongside said fence N00°28'22"E. 108.35 feet to a point on the North line of said SW '/ SW '/ ; thence S88°56'44"E. 130.9 feet to the point of beginning. Parcel Number 7628 Book: 138 Page: 360 Date: March 19, 1923 Grantor: Frank A. Hardy & Ruth W. Hardy Grantee: Union Oil Company of California All of the following described lot or parcel of land situate, lying and being in the County of Garfield and State of Colorado, to -wit: The 5 '/z of the NW '/4, the NW 1/4 of the SW 'l. and Lot 4 of Section 1, T. 7 S., R. 96W. of the 6`h P.M., in said County and State, containing 160.39 acres. Parcel Number 7635.6 Book: 134 Page: 98 Date: December 12, 1921 Grantor: Roderick D. Burnham & Isabel Burnham Grantee: Union Oil Company of California The S 112 SE 1/4, the NW 1/4 SE 1/4 and the NE 1/4 SW 1/4 of Section 1, T. 7 S., R. 96 W. of the 6th P.M. Garfield County Colorado, excepting therefrom that part described as follows, to -wit, beginning at a point on the west line of said SE 1/4 which is 458 feet from the southwest corner of said SE 1/4; thence south on said line to said southwest corner; thence east to the southwest corner of the SE 1/4 SE 1/4 of said Section 1; thence 761 feet east along the south line of said SE 1/4 SE 1/4; thence north 361 feet; thence westerly to the point of beginning. Parcel Number 7635.5 Book: 134 Page: 98 Date: December 12, 1921 Grantor: Roderick D. Bumham & Isabel Burnham Grantee: Union Oil Company of California The NE °/• SE 1/4, the S '/2 NE 'A and Lot 2, all in Section 1, T. 7 S., R. 96 W. of the 6th P.M., Garfield County, Colorado, containing 160.22 acres more or less. A-7 1111111IIII IEll 111111111111111(Illy...11111 11 11 11 591318 11/05/2001 02:59P 51300 P401 n RLSDORF 10 of 18 R 90,00 D 153.50 GRRFIELD COUNTY co, • • • Parcel Number 7698 Book: 578 Page: 699 Date: August 6, 1981 Grantor: ALIO Development, Inc. Grantee: Union ail Company of California A parcel of land situate in the SW SW VI of Section 1, T. 7 S., R. 96 W. of the 66 P.M., said parcel of land contains along and within its boundaries 100.00 foot strip of land for railroad right-of-way purposes, said parcel of land is more particularly described as follows: Beginning at the corner common to Sections 1, 2, 11 and 12 of said Township and Range, whence the witness corner (an iron post with brass cap) of bears N.88°21'31 "W., 220,00 feet; thence N.62°19'54"E., 1607.23 feet to the intersecting point with the East line of said SW 1/4 SW 1/4 Section 1 and the Southwesterly right-of-way of a railroad alignment, the True Point of Beginning: with all bearings contained herein being Colorado Grid Bearings (Central Zone). True Bearings are obtained by rotating all bearings herein counter -clockwise 01°37'28"; thence along said southwesterly right-of-way N.51 °43'07"W., 340.63 feet; thence leaving said southwesterly right-of-way N.39°37'28"E., 311.11 feet; thence N.00°28'22"E., 108.35 feet to a point on the North line of said SW I14 SW 1/4; thence along said North line S.88°56'44"E., 130.90 feet to the Northeast corner of said SW 1/4 SW 1/4; thence along the East line of said SW 114 SW 1/4 S.06°26'13" W., 560.13 feet to the True Point of Beginning and containing two acres, more or less. Parcel Number 7697 Book: 574 Page: 327-328 Date: June 12, 1981 Grantor: Evelyn G. McKay Grantee: Union Oil Company of California A parcel of land situate in the SW 1/4 SW 1/4 of Section 1, T. 7 S., R. 96 W. of the 6th P.M., said parcel of land is more particularly described as follows: Beginning at the corner common to Sections 1, 2, 11 and 12 of said Township and Range, whence the witness corner (an iron post with brass cap) of bears N.88°21'31 "W. 220.00 feet, thence N.27°58'45"E. 1491.75 feet to the intersecting point with the North line of said SW 1/4 SW 1/4 and the southwesterly right-of-way of a railroad alignment, the True Point of Beginning; with all bearing contained herein being Colorado Grid Bearings (Central Zone). True Bearings are obtained by rotating all bearings herein counter -clockwise 01°37'28"; thence along said North line of the SW 1/4 SW 1/4 S.88°56'44"E. 655.61 feet; thence leaving the North line S.00°28'22"W. 108.35 feet; thence S.39°37'28W. 311.11 feet to a paint on said southwesterly railroad right-of-way alignment; thence along said southwesterly right-of- way-N,51°43'07"'W. 581.16 feet to the True Point of Beginning. Said parcel of land contains 2.89 acres more or less. A-8 11111111111111111111111111111.111111111;1 1111111111111 591318 11/e15/2001 02:59P 813013 P402 11 RLSDORF 11 of 18 R 90.00 D 153.68 GRRFIELD COUNTY CO Parcel Number 7675A Book: 326 Page: 220-222 Date: June 2, 1960 Grantor: L.L. Tuck Grantee: Union Oil Company of California Parcel 7675A is more particularly described in Book 296, Page 135 as follows: The N 112 N 1/2 of Section 33, and that part of the W 1/2 SW 1/4 of Section 28, described as beginning at the section corner common to Sections 2.8,29,32 and 33 in Township 6 South, Range 96 West of the 6th P.M., thence North 1787 feet, thence in a meander course down Parachute Creek 1207 feet, thence in a Southeasterly direction 496 feet, thence South 1114 feet, thence West 990 feet to the place of Beginning, all in Township 6 South, Range 96 West of the 6th P.M., Garfield County, Colorado.. EXCLUDING, however, any rights to or interest in any mineral of any nature whatsoever which might. underlie the surface of the lands described above. The foregoing exclusion applies to all lands described on Exhibit A. 111 II 11111E11H I HM 11I11 A 1111111 591318 11/05/2001 02:59P B1300 P4.03 11 PLSDORF 12 of 18 R 50.00 D 153.60 GARFIELD COUNTY CO • EXHIBIT ''BH COMMITMENT SCHEDULE B Section 2 Exceptions The policy or policies to be issued pursuant to this Commitment will contain exceptions to ine following matters unless the same are disposed of to the satisfaction of the Company: Order No. 500720-C4 Any loss or damage, including attorneys fees, by reason of the matters shown below: 1. Any facts, rights, interests or claims which are not shown by the public records, but which could be ascertained by an inspection of said land or by nuking inquiry of persons in possession thereof. 2. Easements, or claims of easements, not shown by the public records. 3. Discrepancies, conflicts in boundary lines, shortages in area, encroachments, and any other facts which a correct survey would disclose and which are not shown by the public records. 4. Any lien or right to a lien, for services, labor or material heretofore or hereafter furnished, imposed by law and now shown by the public records. 5. Defects, liens, encumbrances, adverse claims or other matters, if any, created, first appearing in the public records or attaching subsequent to the effective date Hereof, but prior to the date the proposed insured acquires of record for value the estate or interest or mortgage covered by this Commitment. 6. Taxes due and payable; and any tax, special assessment, charge or lien imposed for water or sewer service or for any other special taxing district. 7. Right of the Proprietor of a Vein or Lode to extract or remove his ore therefrom, should the same be found to penetrate or intersect the premises hereby granted, as reserved in United States Patents of record, including but not limited to the following: April 25, 1896, in Book 12 at Page 419; December 23, 1899, in Book 12 at Page 531; June 21, 1906, in Book 56 at Page 552;. October 7, 1908, in Book 71 at Page 355; September 25, 1909, in Book 71 at Page 380; September 25, 1909, in Book 71 at Page 381; November 10, 1910, in Book 71 at Page 442; December 18, 1919, in Book 71 at Page 624; April 22, 1921, in Book 73 at Page 124; November 19, 1941, in Book 71 at Page 636; August 31, 1959, in Book 320 at Page 50; September 27, 1961. in Book 336 at Page 581; and October 26, 1976, in Book 489 at Pages 633, 634, 635 and 636. 411 8. Right of way for ditches or canals constructed by the authority of the United States, as reserved in United States Patents of record, including but not limited to the following: FIRST AMERICAf1V TITLE INSURAiVCE COMPANY 111111 11 1111 '6,.1'111111 11 113F 1111 11 111 551318 11/Zq/2001 02:5SP 813010 P404 11 PLSDORF 13 of 18 R s0.00 0 153.60 CRRFIEL.O COUNTY CO' April 25, 1896, in Book 12 at Page 419; December 23. 1899, in Book 12 at Page 531; June 21, 1906, in Book 56 at Page 552; October 7, 1908, in Book 71 at Page 355; September 25, 1909. in Book 71 at Page 380; September 25. 1909. in Book 71 at Page 381; November 10, 1910,.in Bock 71 at Pack 442; December 18. 1919, in Book 71 at Page 624; April 22, 1921, in Book 73 at Page 124; October 14, 1933, in Book 172 at Page 538; November 19, 1941, in Book 71 at Page 636; August 3 i , 1959, in Book 320 at Page 50; September 27, 1961, in Book 336 at Page 581; and October 26, 1976, in Hook 489 at Pages 633, 634, 635 and 636. 9. All oil and gas, together with the right to prospect for, mine and remove the same, as reserved in United States Patents of record, including but not limited to the United States Patents recorded August 31, 1959, in Book 320 at Page 50, and September 27, 1961, in Book 336 at Page 581. 10. All the oil and gas and all shale or other rock valuable as a source of petroleum and nitrogen in the lands so patented and to it (i.e., the United States), or persons authorized by it, the right to prospect for, mine and remove such deposits from the same upon compliance with the conditions and subject to the provisions and limitations of the Act of July 17, 1914 (38 Stat.509), as reserved in United States Patents of record, including but not limited to the [United States Patent recorded October 14, 1933, in Book 172 at Page 538. 11. Easement and right of way for unspecified purposes, as granted by R. A. Wallace to Thomas Glover by the Deed recorded June 3, 1901, in Book 55 at Page 151, the precise location of which is not defined. 12. Ditches and laterals, together with headgates and flumes used in connection therewith, and easements and rights of way therefor, 'including but not limited to the following: Helm Ditch, as evidenced by Ditch Map filed February 17, 1902, at Reception No. 7627, and Ditch Decree recorded .August 15, 1910, in Book 80 at Page 172; Daisey Ditch, as evidenced in the Deed from George Edinger to Peter R. Barthell recorded December 23, 1903, in Book 62 at Page 330; Low Cost Ditch, as evidenced by the Deeds from Charles W. Wilson to George H. Benton and J. F. Wheeler recorded May 20, 1919, in Book 1 1 0 at Pages 422 and 423; Cornell Ditch, as evidenced by the Map and Statement Filed January 16, 1859, at Reception No. 8281, and filed November 11, 1890, at Reception No. 10947; Glover Ditch No. 1, Glover Ditch No. 2, Spring Valley Ditch, and Riley Ditch, as evidenced by various and sundry instruments of record. 13. Easement and right of way for road purposes. as granted by Jacqueline Cox and A. C. Wiseman to John Crawford, et al., by the Deed recorded January 9, 1930, in Book 1 7 1 at Page 42._ FIRST AMERICAN TITLE INSURANCE COMPANY ilk 111111 111 1111 1 I1 1I1EI 111, 1111 Mill . 591318 11105/2001 02:59P 81300 P4e15 11 RLSDCRF 14 of 18 R 90.00 0 153.60 GPRFIELD COUNTY CO 14. Right to tisc the natural drainage through the draws crossing said described land as ditches for the • carrying of irrigation water, as reserved by Rose Benton Bruckner in the Deed to J. F. Wheeler recorded September 21, 1921, in Book 171 at Page 416. 15. Right to use a lane 12 feet in width, as granted by Martel Sherwood to Floyd Bruckner and Maude Bruckner by the Dccd recorded May 3, 1943, in Book 207 at Page 399. 16. An undivided one-half interest in and to all oil, petroleum and mineral products, as reserved by LeMont Robertson and Florence Ml. Robertson in the Deed to Theodore R. McQuiston, el al., recorded January 21, 1952, in Book 262 at Page 571, and any and all assignments thereof or interests therein. 17. An undivided forty percent interest in and to all oil, gas and other minerals, as reserved by Beryl D. Miner in the Deed to Rea L. Eaton recorded February 6, 1954, in Book 275 at Page 123, and any and all assignments thereof or interests therein. 18. Easement and right of way to construct, operate and maintain its electric transmission line and related facilities, as granted by Carl D. Tucker and Kathryn M. Tucker to Public Service Company of Colorado by the instrument recorded August 25, 1955,.in Book 287 at Page 27, said easement being over and across n portion of the NE1/4 SE114 and a portion of the E1/2 NW 114 SE114, Section 34, Township 6 South, Range 96 West of the 6°12 P.M., all as more particularly described therein. 19. Easement and right of way to construct, operate and maintain its e;ectric transmission line and related facilities, as granted by Stanley D. McKay and Evelyn McKay to Public Service Company of Colorado by the instrument recorded August 10, 1955, in Book 287 at Page 33, said easement being over and across portions of Section 1, Township 7 South, Range 96 West of the 6th P.M., all as more particularly described therein. 20. Easement and right of way to construct, operate and maintain its electric transmission line and related facilities, as granted by Union Oil Company of California to Public Service Company of Colorado by the instrument recorded October 11, 1955, in Book 288 at Page 45, said easement being over and across portions of Sections 1 and 4, Township 7 South, Range 96 !Vest of the 6`'' P.M., all as more particularly described therein. 21. An undivided one-half interest in and to all oil, gas and other minerals, as reserved by Robert. Davidson in the Deed to L. L. Tuck recorded August 27, 1956, in Book 295 at Page 41, and any and all assignments thereof or interests therein. 22. An undivided one-half interest in and to all oil, gas and other minerals, as reserved by Rea L. Eaton in the Deed to L. L. Tuck recorded September 26, 1956, in Book 295 at Page 334, and any and all assignments thereof or interests therein. 23. Road Spur Easements between Union Oil Company of California and Mobil Oil Corporation recorded December 11, 1982, in Book 614 at Page 698, and March 22, 1983, in Book 622 at Page 580, as amended by instrument recorded January 21, 1996, in Book 682 at Page 301. 24. Boundary Line Agreement between Union Oil Company of California, a California corporation, and Atlantic Richfield Company, a Pennsylvania corporation, recorded July 19, 1983, in Book 630 at Page 883. FIRST AMERICAN TITLE INSURANCE COMPANY 11111111111111111 !1111 11111111,.. 1 !1111111 591318 11/05/2001 02:59P 81300 P4E6 t1 RLSDORF 15 of 13 R 9e.eo D 153.60 GARFIELD COUNTY CO • • 25. Memorandum of Agrcenient between Atlantic Richfield Company, a California corporation, Chevron Shale Oil Company, a California corporation, Eaton Shale Company, a Colorado corporation, Exxon Corporation, a New Jersey corporation, Mobil Oil Corporation, a New York corporation, The Oil Shale Corporation, a Delaware corporation, Exxon Company, U.S.A. and Union Oil Company of California, a California corporation, recorded August 22, 1983, in Book 633 at Pages 461 through 484, inclusive, and the Assignment and Assumption Agreement attached thereto in Book 633 at pages 485 through 488, inclusive, and the Grant of Easement and Agreement Creating Restrictive Covenant attached thereto as Exhibit 1 in Book 633 at Pages 489 through 518, inclusive, the Grant of Easement and Agreement Creating Restrictive Covenant attached thereto as Exhibit 2 in Book 633 at Pages 519 through 546, inclusive, the Grant of Easement and Agreement Creating Restrictive Covenant attached thereto as Exhibit 3 in Book 633 at Pages 547 through 582, inclusive, the Grant of Easement and Agreement Creating Restrictive Covenant attached thereto as Exhibit 4 in Book 633 at Pages 583 through 612, inclusive, the Grant of Easement and Agreement Creating Restrictive Covenant attached thereto as Exhibit 5 in Book 633 at Pages 6 1 3 through 645, inclusive, as amended by instruments recorded February 10, 1989, in Book 748 at Page 863, October 10, 1996, in Book 995 at Pages 740, 749, 757, 765 and 773, June 20, 1997, in Book 1022 at Page 990, July 21, 1997, in Book 1026 at Page 777, January 5, 1998, in Book 1049 at Pages 112, 118, 124, 130 and 136; and June 14, 2000, in Book 1 192 at Page 326. 26. License by and between Union Oil Company of California, a California corporation, and Exxon Corporation, a New Jersey corporation, recorded December 22, 1983, in Book 640 at Page 846. 27. Boundary Agreement between Union 01I Company of California, a California corporation, and Mobil Oil Corporation, a New York corporation, recorded January 21, 1986, in Book 682 at Page 294. 28. Oil and Gas Lease between Union Oil Company of California, as Lessor, and Barrett Energy Company, as Lessee, recorded Jun 16, 1986, in Book 689 at Page 895, and any and all assignments thereofor interests therein. :9. Resolutions No. 87-B0E-277, 87 -BOE -276, and 87-B0E-280 of the Board of County Commissioners, sitting as the Board of Equalization, for Garfield County, Colorado recorded July 31, 1987, in Book 718 at Pages 68, 70 and 74, respectively. 30. Communitization Agreement between TIie Bureau of Land Management and Barrett Energy Company recorded August 17, 1987, in Book 719 at Page 220, 31. Od and Gas Lease between Union Oil Company of California, as Lessor, and Barrett Energy Company, as Lessee, recorded July 10, 1989, in Book 757 at Page 974, and any and all assignments thereof or interests therein. 32. Qi! and Gas Leases between Union Oil Company of California, a California corporation, as Lessor, and Barrett Resources Corporation, as Lessee, recorded December 21, 1989, in Book 769 at Page 484; March 22, 1990, in Book 775 at Page 402; September 13, 1990, in Book 788 at Page 791; October 1, 1990, in Book 789 at Page 915, re-recorded November 19, 1990, in Book 793 at Page 524; July 26, 1993, in Book 869 at Page: 992; and July 26, 1996, in Book 956 at Page 825; and any and all assignments thereof or interests therein. 33. Communitization Agreements between The Bureau of Land Mtanagernent and Barrett Resources Corporation recorded April 12, 1990, in Book 776 at Page 622; June 19, 1991, in Book 806 at Pages 424, 514 and 558 - FIRST AMERICAN TITLE INSURANCE COMPANY till 1111 III IIII IIII 1 Illi! I1II �, .i III IIS IIII - 591318 1,/05/2001 02:59P B1300 P407 M HLSDCRF 15 of 18 R 90.00 D 153.60 GARFIELD COUNTY CO 34. Declarations of Pooling and/or Pooling Agreements between Barrett Resources Corporation, et al., recorded July 27, 1990, in Book 784 at Page 618; August 6, 1990, in Book 785 at Page 393; April 20, 1994, in Book 899 at Page 414; September 14, 1998, in Book 1088 at Page 403; January 19, 1999, in Book 1 109 at Page 728. 35. Resolution No. 91-027 of the Board of County Commissioners of Garfield County, Colorado recorded April 2, 1991, in Book 801 at Page 520. NOTE: Upon receipt of an affidavit, satisfactory to the Company, that the above Resolution is no longer in affect, Exception No. 35 will be deleted. 36. Resolution No. 92-101 or the Board of County Commissioners or Garfield County, Colorado recorded November 10, 1992, in Book 846 at Page 952. 37. Access License Agreement (Hayes Gulch Road) between Union 011 Company of California, a California corporation, and the United States of America, Department of Energy, recorded August 26, 1994, in Book 913 at Page 795. 38: Rights -of -Way and Easements between Union 011 Company of California, a California corporation, and Piceance natural Gas, Inc. recorded November 4, 1996, in Book 998 at Page 532; August 11, 1999, in Book 1 144 at Page 858. 39. Access License Agreements between Barrett Resources Corporation, a Colorado corporation, and Union Oil Company of California, dila UNOCAL, a California corporation, recorded December 30, 1996, in Book 1004 at Pages 752, 821 and 832; October 9, 1997, in Book 1037 at Pages 462, 475, 622, 636, 691, 751, 762, 788, 800, 814 and 860; December 22, 1997, in Book 1047 at Page 279; March 2. 1998, in Book 1055 at Pages 516, 530, and 544; April 29, 1998, in Book 1064 at Pages 961 and 975; June 18, 1998, in Book 1073 at Pages 426 and 456; January 1, 1999, in Book 1 109 at Pages 653, 688 and 703; February 16, 1999, in Book 1114 at Pages 759, 771, 785, 801, 817 and 833; June 1, 1999, in Book 1 132 at Page 328; June 14, 1999, in Book 1134 at Pages 979 and 995, and in Book 1 135 at Pages 1 and 10; August 12, 1999, in Book 1145 at Pages 1 and 16; July 24, 2000, in Book 1 198 at Page 730; and February 9, 2001, in Book 1231 at Pages 84, 102 and 118. 40. Pipeline Easement and Usage Right Agreement between Union Oil Company of California, a California corporalion. Rulison Gas Company, L.L.C., a Colorado limited liability company, and Wildhorse Energy Partners, L.L.C., a Delaware limited liability company, recorded May 5, 1997, in Book 1017 at Page 653, and re-recorded February 9, 1998, in Book 1052 at Page 821. 41. Communitization Agreement between The United States Department of Energy and Barrett Resources Corporation, et al., recorded June 6, 1997, in Book 1021 at Page 373. 42. Right -of Way and Easement between Union Oil Company of California, a California corporation and Rulison Gas Company, LLC, a Colorado corporation recorded July 24, 1997, in Book 1027 at Page 420. 43. 'Rights -of -Way and Easements between Union Oil Company of California, a California corporation, and Barrett Resources Corporation, a Colorado corporation, recorded October 9, 1997, in Book. 1037 at Pages 489, 520, 540 and 573; December 22, 1997, in Book 1047 at Pages 287 and 300; June 1, 1998, in Book 1070 at Pages 141, 154 and 167; January 19, 1999, in Book 1109 at Pages 678 and 718; April 14, 1999, in Book 1124 at Pages 454 and 584; August 12, 1999, in Book 1 144 at Page 997; October 1,1999, in Book 1153 at Paces 302 and 312; November 5, 1999, in Book 1 159 at Pages FIRST Arl•'IERICAN TITLE INSURANCE COMPANY I 111111E1 1E11111 111 111 lIIl1 llI1 111111 IIS AI . 591318 11/05/2001 02:59P B1300 P405 M PLSDORF 17 of 18 R 90.00 D 153.60 GARFIELD COUNTY CO • 210 and 22 1 ; April 26, 2000, in Book 1 184 at Pages 89 and 99; and March 14, 2001, in Book 1237 at P'agcs 401, 412 and 423. 44. Utility Easements Agreement between Union Oil Company of California, a California corporation, and American Soda, L.L.P., a Colorado limited liability partnership, May 12, 1999, in Book 1 129 at Page 117. 45. Assignment of Leases, Bill of Sale and Assignment of Intangible Contractual Rights and other Intangible Property by Union Oil Company of California, a California corporation, to Tom Brown, Inc., a Delaware corporation, recorded July 19, 1999, in Book 1140 at Page 838. 46, Lease Agreement between Union Oil Company of California, a California corporation, as Lessor, and Tom Brown, Inc., as Lessee, recorded October 7, 1999, in Book 1 154 at Page 492. 47. Easement and right of way for the Colorado Interstate Gas Parachute Creek Pipeline, as evidenced by the Plat filed October 20, 1999, at Reception No. 553995. 48. Access License Agreements between Barrett Resources Corporation, a Delaware corporation, and Llnion 011 Company of California, dba UNOCAL, a California corporation, recorded November 5, 1999, in Book 1 159 at Page 195; December 2, 1999, in Book 1 162 at Page 874; March 7, 2000. in Book 1175 at Pages 749, 764 (as amended by instrument recorded January 25, 2001, in Book 1228 at Page 797), 779, 818 and 833; April 26, 2000, in Book 1 184 at Pages 74, 127, 142 and 157; May 12, 2000, in Book 1187 at Page 304; August 23, 2000, in Book 1203 at Page 401; October 10, 2000, in Book 1211 at Pages 745 and 760; January 8, 2001, in Book 1225 at Pages 880 and 896; February 9, 2001, in Book 1231 at Pages 84, 102 and 118; February 23, 2001, in Book 1233 at Page 438; March 29, 2001, in Book 1240 at Pages 683, 699, 709, 725, 741, 757, 773 and 789 and June 25, 2001, in Book 1263 at Page 310. 49. Rights -of -Way and Easements between Union Oil Company of California, a California corporation, and Barren Resources Corporation, licensed to do business in the State of Colorado, recorded March. 7, 2000, in Book 1175 at Page 849; May 30, 2000, in Book 1189 at Pages 788 and 798; January 8, 2001, in Book 1225 at Pages 816, 858 and 869; April 26, 2001, in Book 1248 at Page 324 and June 25, 2001, In Book 1263 at Page 299. 50. Rights -of -Way and Easements between Union Oil Company of California, a California corporation, and Barrett Resources Corporation, a corporation, recorded July 24, 2000, in Book 1 198 at Page 746. 51. Access License Agreements between Petroleum Development Corporation, a Nevada corporation and Union Oil Company of California, dba UNOCAL, a California corporation, recorded February 8, 2001, in Book 1230 at Pages 91 1 and 921, and May 21, 2001, In Book 1254 at Page 471. 52. Right -of -Way and Easement between Union Oil Company of California, a California corporation and Puckett Land Company, a Colorado corporation, recorded March 26, 2001, in Book 1239 at Page 675. 53. Lack of a right of access from Parcel B to any open public road, street or highway. NOTE: The foregoing Exception No, 53 is necessary because it does not appear from either (a) the instruments of record in the office of the Clerk and Recorder for Garfield County, Colorado, or (b) the boundary survey of "Unocal Property Within Section 1, Township 7 South, Range 96 West of the Sixth Principal Meridian" prepared by Construction Surveys, Inc. of Silt, Colorado on October 16, FIRST AMERICAN TITLE INSURANCE COMPANY 911111111111 111111 1111 Illill 111111 IIII,..,'llllll III IIII IB of 18 R 90.00 D 153.60 GARFIELD COUNTY CO • • 2000, and submitted to the Company, that any right of access exists for roadway. Parcel B to an open public •neg- +.f nvr..,ni rrrr is r,UCTJR4NC,'FCOMPANY • • • Moms. EXPLORATION at PRODUCTION 1058 CR#215 BO.Box 370 Parachute, CO 81635-0370 970128593377 9701285-9573 Fax November 4, 2005 Mr. Mark Bean Director Garfield County Building and Planning Department 108 8th Street, Suite 201 Glenwood Springs, CO 81601 Dear Mr. Bean, By this letter Williams Production RMT Co. authorizes PVCMI- Land Planning Division to represent us in any and all matters related to the special use permit application known as Williams Production RMT Co.- Parachute Creek Gas Plant Expansion Phase 3. This includes the preparation and submission of documents associated with the land use application and representation of this application before the applicable appointed and elected boards. Sincerely, Mr. Steve Soychak Williams Production RMT Co. PVCMI Land Planning Division 1038 County Road 323 Rifle, CO 81650 Ph. 970-625-5350 Fax 970-625-4522 Email: pvcm@direcway.com Project: Williams Production RMT Co.- Parachute Creek Gas Plant Expansion Phase 3 Submittal Item Number: 11- Impact Statement Please find attached the following items. (The items prepared within section 11 are arranged as called for in the Garfield County Supplemental Regulations Section 5.0107 and are additionally compliant with Garfield County Supplemental Regulations Section 5.03.08 items #1-#4 Industrial Performance Standards) 1.A. Existing lawful use of water. 1. Construction Stormwater Management Plan prepared by Cordilleran Compliance Services, Inc. dated 12/1/05. Please see attachment 1 1.1.A.1 Stormwater. 2. Spill Prevention Control and Countermeasure Plan prepared by Cordilleran Compliance Services, Inc. Please see attachment 11.1.A.2 SPCC Plan. 3. Domestic Water System- Please see attachment "3a Water System". The above information illustrates that Williams Production RMT Co. has stormwater management and spill prevention controls and countermeasures that meets the requirements set forth by the Town of Parachute, Garfield County, the State of Colorado and the USEPA. 1.B. Impacts on adjacent land 1. Vapor- Please see attached copy of Air Pollution Control Division Construction Permit Application at 1 1.1.B. 1 APCD app. 2. Dust- See attached statement 11.1.B.2 Dust Control regarding dust control policy at the Parachute Creek Gas Plant. Page 1 of 3 3. Smoke- Please see copy of Air Pollution Control Division Construction Permit Application attached in 11.1.B.1 APCD app. 4. Noise- Please see attached statement 11.1.B.4 on Noise Abatement. 5. Glare- Please see attached statement 11.1.8.5 on Glare Abatement. 6. Vibration- Please see attached statement 11.1.8.6 on Vibration Abatement. The above information illustrates that Williams Production RMT Co. has proven that vapor, dust smoke, noise, glare and vibration controls meets the requirements set forth by Garfield County, the State of Colorado and the USEPA. LC. Impacts on Wildlife See Section 11.1.0 Wildlife for details regarding this item. The above information illustrates that Williams Production RMT Co. has followed the recommendations set forth by the Colorado Division of Wildlife. I.D. Impacts of Truck and Automobile Traffic. 1. Traffic Analysis Prepared by Felsberg, Holt and Ullevig. Please see attachment 11.1.D Traffic. 2. Please see submittal 45 "Garfield County Road & Bridge Department Access Issues". The above information illustrates that Williams Production RMT Co. has proven that the existing and proposed level of service at the Mancamp Road/Garfield County Road #215 intersection is a Level of Service A. 1.E. Distances from Abutting Property. Letter attached at 11.1.E regarding abutting property. 1.F. Mitigation Measures Proposed. Please see mitigation measures noted in each of the individual submittal items. Page 2 of 3 2.A. Site Rehabilitation Ilan. Please see attachment 11.2.A Site Rehabilitation Plan. Please note that the above and attached information presented discusses a carefully implemented plan for mitigation of impacts caused by the Parachute Creek Gas Plant Phase 3. The majority of these mitigation strategies are currently in place in the existing Parachute Creek Gas Plant and will be extended to the expansion. Please contact me with any questions. Sincerely, Philip B. Vaughan President PVCM1 Page 3 of 3 CONSTRUCTION STORM WATER MANAGEMENT PLAN (STORM WATER DISCHARGE PERMIT # COR -034248) PARACHUTE CREEK GAS PLANT GARFIELD COUNTY, COLORADO PREPARED FOR: WILLIAMS PRODUCTION RMT COMPANY P.U. Box 370 Parachute, Colorado 81635 PREPARED BY: CORDILLERAN COMPLIANCE SERVICES, INC. 826 21% Road Grand Junction, Colorado 81505 970.263.7800 CORDILLERAN ORIGINAL PLAN DATE: May 21, 2002 REVISION DATE: December 1, 2005 TABLE OF CONTENTS Section Pae INTRODUCTION 1 Purpose/Object ive 1 Facility Name/Location 2 Owner/Operator Contact information 2 Type of Facility 2 1.0 SITE DESCRIPTION 3 1.1 Site Location . 3 1.2 Location Size 3 1.3 Site & Area Characteristics 3 2.0 CONSTRUCTION SITE CHARACTERISTICS 5 2.1 Location of Storm Water Outfalls 5 2.2 Drainage Basins for Each Outfall 5 2.3 Construction Activities 5 2.4 Materials Handling, Loading, and Storage Areas 6 2.5 Adjacent Property Descriptions 6 3.0 DESCRIPTION OF POTENTIAL POLLUTION SOURCES AND MATERIAL INVENTORY 7 3.1 Description of Significant Material Storage 7 3.2 Description of Significant Spills, Leaks, Releases 7 3.3 Storm Water Discharge Permit Number 7 3.4 Potential Pollution Sources 7 3.5 Summary of Storm water Sampling Data 8 4.0 STORM WATER MANAGEMENT CONTROLS 9 4.1 SWMP Administrator 9 4.2 Preventive Maintenance 9 4.3 Good Housekeeping 10 4.3.1 Operations and Maintenance Techniques 10 4.3.2 Material Storage and Material Handling 10 4.4 Spill Prevention and Response Procedures 11 4.5 Best Management Practices 11 4.5.1 Storm Water 1)iversion 11 4.5.2 Sediment and rrosion Prevention 11 4.5.3 Other Pollution Prevention Measures 14 4.6 Employee Training 14 4.6.1 Introduction to Storm water Permits 15 4.6.2 Pertinent Components .of the Perini( SWMP 15 4.6.3 Reporting and Record keeping 15 Parachute Creek ;as Plant ( 'on/ill/Tau 'orriplionc-e Services. Inc. Sion!' \\'arci Illanagemeni Plan Gra/O./unction, Ortorackr 4.6.4 Enforcement 15 5.0 INSPECTION AND MAINTNENANCE PROCEDURES 16 5.1 Inspection Log 17 5.2 Inspections and Record Keeping for Non -Storm Water Discharges 17 5.3 SWMP Revision Log 17 6.0 CONSISTENCY WITII OTHER PLANS 18 7.0 ALLOWABLE NON -STORM WATER DISCHARGES 18 8.0 ADDITIONAL REQUIREMENTS FOR FACILITIES SUBJECT TO SARA TITLE 111, SECTION 313 18 LIST OF FIGURES Fieure 1 Site Location Map 2 Site Map — Original Proposed Plant Construction 3 Site Map — Phase 2 Addition Construction Grading Plan 4 Site Map — Phase 3 Addition Construction Grading Plan 5 Site Map — Overall Facility Layout LIST OF TABLES Table 1 Notification of Outside Parties — Public Safety Officials and Government Agencies 2 Spill Cleanup Contractors ATTACHMENTS ,Xttachntent A — Storm Water Management Inspection Log and Inspection Form Attachment 8 — Typical Storm Water Bill P Details ParaelittIe Creek Gas Mani CorchlIcran Compliance Services. lin% t'onstrtleiion Storm Water hlanal2emeiii PIai (fraud ('f)lorcicio INTRODUCTION PurposelObjective Cordilleran Compliance Services, Inc. (Cordilleran) has prepared this Storm Water Management Plan (SWMP) for Williams Production RMT Company (Williams) for construction activities associated with the Parachute Creek Gas Plant in Garfield County, Colorado. This SWMP has been written to comply with the Colorado Department of Public Health and Environment (CDPHE) Genera! Permit number COIL -03000 issued on June 30, 2002 (expiration date: June 30, 2007), and related U.S. Environmental Protection Agency (USEPA) National Pollutant Discharge Elimination System (NPDES) storm water regulations. The goal of this plan is to improve water quality by reducing pollutants in storm water discharges. Construction activities potentially produce many different kinds of pollutants that may adversely impact storm water. The Federal Clean Water Act [Section 402(p)] requires that discharges of pollutants to waters of the United Station from any point source be regulated by NPDES permits. In November 1990 the USEPA published final regulations that established application requirements for storm water associated with construction activity for soil disturbances of 5 acres or more be regulated as an industrial activity and covered by an NPDES permit. In December 1999 the USEPA published final Phase II NPDES regulations that established application requirements for storm water associated with construction activity for soil disturbances to be regulated as an industrial activity and covered by an NPDES permit. These regulations became effective July 1, 2002. The main pollutant of concern at construction sites is sediment, which can become entrained in storm water runoff following grading activities that remove protective vegetative cover. When the storm water runoff carrying these sediments reaches a lake or stream and slows down, the suspended sediments are deposited, and can choke the river channel or cover areas where fish spawn and aquatic plants grow. The particles also cloud waters causing aquatic respiration problems resulting in the death of fish and plants in these systems. Construction may also involve the use of toxic or hazardous materials such as petroleum products, fertilizers, pesticides and herbicides, and building materials such as sealants and concrete, and other chemicals that can be harmful to humans and aquatic life. This plan covers the plant site and the associated right-of-way. Cordilleran has prepared this plan for Williams in order to satisfy the storm water management requirements for a new construction site. This SWMP for the Parachute Creek Gas Plant will be maintained at the Parachute Creek Gas Plant, at the Williams Parachute Office, and at the Williams regional office in Denver, Colorado until the storm water discharge permit expires or is inactivated by Williams. This SWMP is intended to be a dynamic document that is updated as needed throughout the duration of the construction project. A record of revision dates is included in Section 5.3 of this document. Document updates will be perliirnicrl to include the following: 1. Inclusion of newly proposed activities resulting in ground disturbance: Revision of existing best management practices (13MPs) as needed to address sediment control, and; Parachute Creek Cli3s Plant Construction Storni Waler Management { 'orelille'rar: (.'nruj)Iiune e .5t vz ice•., lrlr . (;rcrrrs.h uc tirrrl, ('rrlorceclr+ • • 3. Removal of BMPs and reduction in monitoring frequency for stabilized or revegetated areas. Facility NarnelLocation The Parachute Creek Gas Plant site is located approximately 4 miles northwest of the town of Parachute, Colorado on County Road 215 in Garfield County, Colorado. The site lies within the northeast quarter of the northeast quarter of Section 33, Township 6 South, Range 96 West. Specifically, the site is located at 39°29'13" north latitude, and 108`6'31" west longitude. Refer to the site location map in Figure 1. Owner/Operator Contact Information Williams Production RMT Company Ptd Box 370 Parachute, Colorado 81635 Facility ContactJSWMP Administrator: Mr. Eric Miller Work Phone: (970) 285-9377 Cell Phone: (970) 270-2813 Fax Number: (970) 285-0121 Emergency Contact: Mr. Dave Cesark Work Phone: (970) 285-9377 Cell Phone: (970) 216-9181 Fax Number: (970) 285-9573 Type of Facility The Parachute Creek Gas Plant is a natural gas fractionation processing and dehydration facility undergoing expansion and new construction. Natural gas enters the station via a gathering system pipeline supplied by local production fields. The quality of the natural gas is improved by removing the water, natural gas liquids, and carbon dioxide from the gas stream to make it suitable for pipeline transport. This facility operates 24 hours per day, 365 days per year and employs 18 full time employees. As a construction site disrupting more than 5 acres of land, the primary concern is that of sediments becoming entrained in storm water and flowing offsite following grading and clearing operations. Additionally, any chemicals stored or used onsite during construction have the potential to adversely impact storm water and migrate offsite without proper management in the event of a spill or release. Parulntle Creek ( Planl ('rnnlpliurreInc. C'canstrnclion Storni \V'aler tvtanagctneni I'I: i (ircuuI.Itmc7rnu, ('obit -wit) 1.0 SITE DESCRIPTION 1.1 Site Location The Parachute Creek Gas Plant is located approximately 4 miles northwest of the town of Parachute, Colorado on County Road 215 in Garfield County, Colorado. The facility lies within the northeast quarter of the northeast quarter of Section 33, Township 6 South, Range 96 West. Specifically, the site is located at 39'29'13" north latitude, and 108°6'31" west longitude. Refer to the site location map in Figure 1. 1.2 Location Size The Parachute Creek. Gas Plant facility consists of three areas for operational and construction consideration: - Phase 1: Original plant area — approximately 10.1 acres. Construction and soil stabilization is complete in Phase 1. - Phase 2: Expansion northeast of Phase 1 — approximately 10.3 acres. complete in Phase 2. - Phase 3: Expansion northwest of Phase 2 — approximately 11.18 construction and soil disturbance planned to begin mid-December, 2005. 1.3 Site & Area Characteristics Construction is acres of new The Parachute Creek Gas Plant site is located in an arid region on the western slope of Colorado. According to information from the National Oceanic and Atmospheric Administration (NOAA) Western Regional Climate Center, the area receives an average of between 10 and 15 inches of precipitation annually. The maximum estimated precipitation in a 24 hour period, for a 25 year storrn event is 21 tenths of an inch (2.1 inches). According to information from the USDA Natural Resources Conservation Service, soils in the vicinity of the Parachute Creek Gas Plant belong to the Arvada-Torrifluvents-lieldt complex. These soils are deep, well drained to somewhat poorly drained, nearly level to gently sloping soils, on benches, terraces, alluvial fans, and flood plains. Runoff is very rapid and the hazard of water erosion is very high in sloping areas. Parachute Creek, a perennial stream, is located approximately 750 feet southwest and down gradient of the center of the Parachute Creek Gas Plant site. Parachute Creek flows southeast to its confluence with the Colorado River, approximately 3.8 miles southeast of the plant location. There is also an irrigation drainage ditch, which flows intermittently, approximately 150 feet north and up gradient of the site. The Parachute Creek Gas Plant is operational at the date of this revision. The overall facility process involves receiving gas from area gathering systems and sending it into two separate processes where water, natural gas liquids, and carbon dioxide (CO2) are removed. The current design capacity of the facility is 120.000,00(1 standard cubic feet of natural gas per day. (MMSCFD). however, the planned expansion will increase this capacity. The water and natural I' arae "hula: ( rt ck ( ias Plant [ cni:+l114 limn Stem n1 Water ManagenicnI Plan ( -r R:°tlille'renr ( irnrl+llcnrr'e .5'e rx it t'S. bit (iron(!Jnrrc•riun, ('nluruclu gas liquids are transported offsite by truck, while a portion of produced carbon dioxide is vented to atmosphere with the rest utilized by Solvay Chemicals. Parachute Creek Gas Plant 4 i.ilrurUe'ra►r Se'/ 17U L.A. Irfr'. 4-unstruclrun Storm \\ ;filer 141anaeerncnl !'fan (i,-cn dJo+tenorr, Colorado • • • 2.0 CONSTRUCTION SITE CHARACTERISTICS The Parachute Creek Gas Plant site currently occupies approximately 20.4 acres and has a slight slope to the south-southwest. The Phase 3 plant expansion area will occupy approximately 11.18 acres and the change in elevation across this portion is approximately 25 feet. Storm water runoff from the site tends to flow toward Parachute Creek, a perertnial tributary to the Colorado River. Storm water outfalls, surface water, structural control measures, industrial activities, materials handling, loading, and storage areas, and adjacent properties are described in the following sections. 2.I Location of Storm Water Outfalls in considering the location and planned extent of the new construction area at the Parachute Creek Gas Plant, storm water outfalls are anticipated to be constructed along the southwest border of the property. Storm water leaves the Parachute Creek Gas Plant site via surface flow to the southeast. Currently no storm water outfalls exist onsite: instead storm water exits the site via sheet wash_ 2.2 Drainage Basins for Each Outfall Storm water runoff is expected to generally move to the south and southwest across the Phase 3 construction site. During construction, the site should have a silt fence constructed around the southern and western boundaries to prevent soils from washing offsite. Once construction is complete, the drainage basin areas for each storm water outfall should be calculated. In the event that the Parachute Creek Gas Plant has a release or spill of a reportable quantity that impacts storm water and migrates offsite this SWMP should be reviewed and revised as needed. Submittal of the revised SWMP to the Colorado Oil and Gas Conservation Commission (COGCC) and CDPHE may be required at the request of said agencies. 2.3 Construction Activities The Phase 3 plant area will be cleared and constructed using conventional cut and fill earthmoving techniques. The plant surface will be graded so that stone water flow onto the site is diverted away from potential pollution sources and so that storm water runoff and spilled liquids remain on the site. Soil and aggregate materials will be managed so that erosion and sediment transport are minimized. Nearby drainages and water courses will he protected by appropriate measures. ,4ndicipated Construction Schedule - Overall site preparation and grading December 2005 - January 2006 - Steel Piling Installation January - JuIy 2006 - Equipment Foundation Construction January - September 2006 - Piping. lquipment Installation. February - September 2006 - Building foundations and Erection Summer 2006 - Phase 3 Startup September 2006 Paraclime Creek (;aa Plant 1 C eirdilie^rc(o;npIia : e Services, hie'. Con lrtiction Storm \Paler ll'1a11agen1cii{ Plan ll!'[Fr111./l111c'1Pr77r. i illrll'ildri 2.4 Materials Handling, Loading, and Storage Areas Fuels, pesticides or herbicides, paints or solvents, and other industrial materials associated with construction activities must be handled, loaded, and stored so as to prevent storm water impacts from occurring. All liquids shall be stored in appropriate containers and properly protected from adverse weather or storm events. By following good housekeeping and best management practices (BMPs), discharges of impacted storm water can be averted. Industrial wastewater shall be properly disposed and not allowed to be discharged to storm water conveyances. 2.5 Adjacent Property Descriptions The site is surrounded on all sides by private agricultural land. Surrounding land usage is primarily for oil and gas exploration and production and to a lesser extent for seasonal livestock grazing and farming. Parachute Creek bats Plant (i f'nrdi!hrr•rm {'.rnolphooli5c rlic r,+. Inc t'unstruction Sturm W<rkcr IS.lanagcmcn1 Plan ror(Hui J0;1(rir)rr. C•r,lorati1 • 3.0 DESCRIPTION OF POTENTIAL POLLUTION SOURCES AND MATERIAL INVENTORY The following is a description of potential sources of pollutants to storm water discharges. 3.1 Description of Significant Material Storage During construction chemical storage will be minimal. Stockpiles of excavated soils should be bermed and covered with sheet plastic or tarps to prevent storm water from transporting sediments into nearby dry washes_ Any fuel storage tanks for trucks and heavy construction equipment refueling should be contained in an earthen berm capable of containing the entire volume of the largest tank. 3.2 Description of Significant Spills, Leaks, Releases The Phase 3 expansion area of the Parachute Creek Gas Plant has no record of prior development. No significant spills, leaks, or releases have occurred at the site prior to initiation of construction activities. 3.3 Storm Water Discharge Permit Number An active CDPHE storm water discharge permit for construction activities with permit nurnber COR — 034248 exists for the Parachute Creek. Gas Plant at the time of this revision. 3.4 Potential. Pollution Sources Potential pollution sources associated with construction sites include: • Sediment resulting from erosion of soil or aggregate stockpiles and other areas cleared of vegetation; • Leakage of fuels and lubricants from equipment or storage tanks and spills from fueling; • Use or leakage of pesticides, herbicide, sealants, emulsions, or concrete; • Trash and debris from clearing activities, construction materials, and workers_ The niost common source of pollution from construction sites is sediment, which can be carried away from the work site with storm water runoff and impact the water quality of a receiving stream. Clearing, grading, and otherwise altering previously undisturbed land can increase the rate of soil erosion over pre -disturbance rates. Petroleum products can also he potential storm water pollutants. These products are used in construction and drilling activities to power or lubricate equipment and include: fuel, gear oil, hydraulic oil, brake fluid, and grease. Chemicals should be properly stored in areas where they will not come in contact with storm water. Debris from laydown areas, residue From equipment cleaning and maintenance, and solid waste generated from land clearing operations and human activity (trees, brush, paper. trash, etc.) I'arachuiL• ("r eek (ias Mani 7 f 'ur rli!!e r,►►r C irnrplk++rc r Services. lfr ('nrsslrucnnn Storni \Vater ManlLLrrrrnr I'I,us (.;rami/./ w ic!iurt, Cub/rutin • present other potential pollution sources within the construction site. Other materials on-site will include compressed gasses used in welding and chemicals used and stored on-site for use in construction activity. 3.5 Summary of Storm Water Sampling Data Storm water sampling is not required by the discharge permit issued for the facility and sampling has not been requested by the CDPHE. As such, there are no storm water sampling data for the facility. Panel'll.0 Creek ( las I'farll C ousiruclion Sloan Water Management l'Ian ti II (hill + Lary (rrtr,rrr+rr ( ., r i 1( e‘, /Oh farmer Jung rr(,u. (`„lr,r(rr!„ • • 4.0 STORM WATER MANAGEMENT CONTROLS Storm water management controls have been developed for the construction of the Parachute Creek Gas Plant. These are described below. 4.1 SWMP Administrator The SWMP Administrator is responsible for: Authority for dedicating the necessary financial and human resources to implement the SWMP; - Implementing spill clean ups; - Notifying local authorities and local residents in the event that a significant release of storm water occurs that leaves the plant; and - Signatory authority. - Coordinating various stages of plan development and implementation; Conducting inspections; Coordinating employee training programs; Maintaining all records; Making certain that all appropriate reports are submitted as necessary; - Coordinating the implementation of the preventive maintenance program; and - Supervising spill response and housekeeping measures. 4.2 Preventive Maintenance The following preventive maintenance measures will be implemented to reduce potential storm water contamination sources at the Parachute Creek Gas Plant: - Storage containers, fuel tanks, and equipment in use during construction activities will be visually inspected daily for obvious leaks by site and contractor personnel as they perform their routine duties; Storage containers will be properly labeled so material accidentally released can be quickly identified, properly cleaned up, and disposed. OSHA -approved labeling and signage systems will be completed in a timely fashion; - Erosion damage to the earthen berms and outfalls onsite will be repaired in a timely fashion; Areas of stained soil will be inspected to identify the sources, and if necessary. releases associated with routine operations and maintenance will be minimized to the extent practical; Energy -dissipating material, such as riprap, will be placed at the storm water outfalls to prevent erosional damage. Although the site does not currently have distinct outfalls, energy -dissipating material such as cobbles or gravel could minimize erosion of onsite soils at the outfalls and in areas where chemicals are likely to come into contact with storm water. Barrow ditches should be free from vegetation and debris which may cause impounding of storm water; 1 ir.tchute Creek (ias Plant t) C?,rdillrrcnt C ompii(#ru e Seri-hrs. Iur. unstruclion Storrs Water Management Plan CiraPu/)11IfI'!ionr, Colorado Storni water management structures will be cleared of debris and repaired when necessary; and Surface runoff controls such as curbing, culverting, and ditches will be used to control runoff at the facility, and will be used to prevent runoff from the adjacent properties to the north from flowing onto the facility. 4.3 Good Housekeeping The following items will be addressed to maintain a clean and orderly facility. 4.3.1 Operations and Maintenance Techniques Develop and maintain inspection schedules (See Attachment A); Correct deficiencies noted during these inspections; Clean and maintain storm water management system components; Routine trash collection and disposal, and grounds maintenance; Familiarize employees and contractors with the storage locations for spill clean-up equipment; Familiarize employees and contractors with good housekeeping procedures, tips, reminders, and pollution prevention concepts; and Control erosion around vehicle access areas (gravel drive-through areas). 4.3.2 Material Storage and Material Handling Where possible, materials will be stored and handled in covered areas to prevent contact with storm water. Employees and contractors will receive training in identifying spills, and in containment and cleanup measures. Training will be provided for specific material handling procedures and practices, as well as proper use of equipment employed to mitigate spills. The following practices will be followed at the material storage areas: Storage containers will be stored away from direct traffic to prevent accidents; Dumpsters, empty containers, receptacles, and sumps will be covered to prevent the collection of precipitation; Storage areas will be kept free of trash; Chemical substances used at the site will be identified, properly labeled, inventoried, and the Material Safety Data Sheets (MSDS) will be kept on file; Chemical substance containers will be clearly labeled and have MSDS on file. The following information should be displayed: o Type of substance. o Stock number. o Expiration date. o Reactivity. o Corrosivity. o Ignitability. o Toxicity. o health hazards. I'araclitati [ leek (ias Plan' 10 ('tw ll/tenni Co t Services. hn• (•011%h-ticlion Storm \V icr Arlarirrgetnenl Plan Grand .1ir/id ion, Colored() o Suggested hauling methods. o First aid. - Containers will be stored off the ground to prevent corrosion_ 4.4 Spill Prevention and Response Procedures Williams is committed to operating the Parachute Creek Gas Plant in accordance with Section 112.7 of the Oil Pollution Prevention Regulations issued under the Federal Water Pollution Control Act (40 CFR Part 112). These regulations require the owners/operators of certain facilities to prepare and implement a Spill Prevention Control and Countermeasure (SPCC) plan_ Copies of the SPCC and SWMP plans will be maintained at the Parachute Creek Gas Plant, at the Parachute Field Office, and at the regional office in Denver, Colorado. The SPCC plan contains information on the potential for oil, as defined in 40 CFR Part 1 12.2, to impact storm water discharges, and the quantities of oil that potentially could be discharged. The SPCC plan contains information on employee training pertaining to spill prevention and response. Governmental agencies to be contacted in the event ofa release and spill cleanup contractors are listed in Tables 2 and Table 3, respectively. 4.5 Best Management Practices Williams will continue to implement appropriate storm water management practices including diversion; materials handling and spill prevention; sediment and erosion prevention; inspections; and other non-structural measures at the Parachute Creek Gas Plant. These are discussed below. All excavation work shall be conducted in an manner that preserves soil and allows for segregation of soil types in order to facilitate land reclamation in the future. Measures shall be taken to preserve excessive soil erosion by wind or water including silt fencing, straw bales and other storm water management efforts. All excavated surfaces shall be maintained with adequate moisture to prevent wind erosion. 4.5.1 Storm Water Diversion Culverts may be used to control runoff or divert it away from construction activities and equipment. Prevent storm water flow from leaving the plant using grading or extending terraces across to the southwestern portion of the site and planting open areas with native grasses as soon as feasible. 4.5.2 Sediment and Erosion Prevention The objective of erosion and sediment controls is to minimize the release of sediments to storm water runoff' This can be accomplished through the use of structural and/or nonstructural controls. This section describes erosion and sediment controls to be used to minimize possible sediment impacts to stone water runoff. The proposed erosion control features include: t`:.irac uuti ('reek Gas Plant l ( tons(' ucIiun Siort°ti 1Vaier A1ana4geniern Plan Cur/Alen,, C'rrnrplrrunk'c Services. Inc. (;rurulf 'ulurado - Placement of the topsoil stockpile at the upgradient edge of the construction site to divert run-on; - Installation of silt fence at or below the toe of fill slopes where located within 100 feet of surface water drainages or where steep slopes will likely result in rapid drainage from the location to nearby drainages; - Grading of construction site surfaces to control and direct drainage flows; Installation of check dams in areas of concentrated flow; and - Permanent seeding or stabilization of areas where construction is complete and ground surfaces have been graded to the final configuration. Uphill topsoil stockpile/diversion berm In order to divert surface runoff from upgradient areas away from construction or facility areas, salvaged topsoil will typically be placed on the uphill side of a cut slope. The topsoil stockpile will be placed and graded to form a diversion berm that will direct surface water away from the construction site. Downhill silt fence Silt fence will be installed at the toe of fill slopes located within 100 feet of a surface drainage. Silt fence may also be required in areas where steep slopes below the site will likely result in fast flow of water from the location to nearby drainages. Typical silt fence installation details are given in Attachment B. Straw bale check dams Straw bale check dams, at a minimum will be installed in areas of concentrated flow. Straw bale check dams should also be installed at suitable locations along new access roads. Typical straw bale check dam installation details are given in Attachment B. Check dams Rock check dams will be installed in areas of concentrated flow. Rock check dams may be used instead of straw bale check dams in areas where steep slopes, high flows, or long-term exposure are expected to result in failure or frequent maintenance ofa straw bale structure. Typical check dam installation details are given in Attachment R. Road drainage relief Culverts, rolling dips or water bars may be used to provide drainage of water from road surfaces as needed to drain low areas or to reduce the amount of water flowing on the road surface. Road drainage relief spacing ‘vill ti Erse depending on erodsbtlity of local soils and road slope. Depending on the location and type of drairiage relief installed, additional sediment control Parachute Creek Gas Plant Construction Slurnn \Valet Mmagenlen1 Plan 12 c orclilienrsr .ti', rt it cc. hu- (rr,urri hen( liru . ("nloi-Lieln features may be needed such as sediment removal at the inlet and erosion protection at the outlet. Culvert spacing guidance from the Gold Book is given in the following table. Maximum Recommended Culvert Spacing (feet) Soil Type Road Grade 2 to 4% Road Grade 5 to 8% Road Grade 9 to 12% Highly erosive granitic or sandy 240 180 140 Intermediate erosive clay or loam 310 260 200 Low erosive shale or gravel 400 325 250 Information Source: Gold Book (BLM & US FS, 2005) Culvert inlet and outlet protection Installation of culverts may be needed where access roads cross drainages or where surface drainage relief is needed. Culvert inlet and/or outlet protection will be provided as needed and will typically include rock protection. Rock protection will typically be 2- to 4 -inch diameter rock, 4 to 6 inches deep, have dimensions of about 4 feet wide by 10 feet long. The area of rock lining should be prepared by removing 6- to 8 -inches of soil. The shallow excavation should be filled with rock and the rock secured in-place by bucket tamping or wheel - rolling. Rock -lined outlets, where used, should be installed to promote lateral spreading of water as it flows across the rock. Soil Berms Soil berms may be used to divert drainage away from areas of concern or to direct flow toward sediment control structures. Where used, soil berms shall be constructed of soil with sufficient fines to minimize flow through the berm. Berms shall be at least 18 -inches tall and will be compacted in place by wheel rolling with suitable rubber tired, heavy equipment. Gravel surfacing Gravel surfacing may be used to cover soil in areas of high traffic such as roads, facility areas, and the area near well heads. Gravel surfacing forms a layer that protects soil from wind and water erosion and prevents vehicle tracking. Storni Water Management Controls As development of the plant progresses additional facilities and areas may be planned and constructed. This SWMP will be revised as needed to address new disturbances. Depending on the type and location of new ficilities there may be a need for inclusion of new and different BMPs. In general, new development should be planned with consideration for storm water quality (e.g. minimiz_e disturbed area and maximize distance from surface water drainages, as practicable). Parar1iuie ('reel [ las F1,rul l3 (iurrpJwon .tie•rrire's. hx•. Cunstrue:lion Strr11 1 11`.iler Managerneui (.olortrcio Other developments on the overall plant site, primarily existing disturbed or high -use areas, not currently or specifically addressed in the SWMP will be periodically checked for erosion and drainage problems. This is especially important for areas located within 100 feet of surface drainages or creeks. If problems are noted, they should be reported to the SWMP administrator. Problem areas may be addressed through maintenance activities, but will likely need to be addressed through BMPs which will be added to the plan as needed. The storm water outfalls at the plant should inspected often during construction and be maintained with landscape fabric, rip rap, concrete, straw bales or other energy dissipating devices to prevent erosion. Storm water conveyances need to be maintained and clear of debris and vegetation in order to adequately handle storm water from the site. 4.5.3 Other Pollution Prevention Measures Good Housekeeping o Materials and containerized fluids will be stored orderly and neatly. Waste materials will be temporarily stored in sealed containers and regularly collected and disposed of at approved disposal facilities. If spills occur, prompt cleanup is required to minimize and commingling of waste materials with storm water runoff. o Cleanup of trash and discarded materials will be conducted at the end of each work day. Cleanup will consist of patrolling construction and work areas to pickup trash, scrap metal, other discarded materials, and any contaminated soil. These materials will be disposed of appropriately. o Routine maintenance will be limited to fueling and lubrication of equipment. Drip pans will be used during routine fueling and maintenance to contain spills or leaks. Any waste product from maintenance will be containerized and transported off site for proper disposal or recycling. There will be no major equipment overhauls conducted on site during plant construction. Equipment will be transported off site for major overhauls. o Temporary and permanent roads and pathways will be installed and stabilized to minimize the transport of sediment from road surfaces by mobile equipment. o Durnpsters or other trash receptacles will be kept covered. - Record Keeping and Reporting o Records will be maintained of site inspections, spills, and storm .water control structure maintenance activities. o If a reportable impacted storm water release occurs, a report will be submitted to CDPHE, Water Quality Division. and the COGCC. o Records and reports will be retained at the Parachute Creek Gas Plant for at least three years. 4.6 Employee Training Williams will continue to implement a training program to address the areas of concern outlined in the SWMP for the construction of the Parachute Creek Gas Plant. Personal work I ;ir lsutc ('reek Gas Man, 1 _I ['rrrdillrrun (f,nrpliu?n a Sell' It , hrr t oriqniclinn Storm Wales tvtanagenient t'laas (irarul.hrru•iiun, (-ulurudu responsibilities are used to identify the appropriate attendees. The training program will be conducted along with standard safety and environmental training. The following topics are included in the SWMP training program. 4.6.1 Introduction to Storni Water Permits Storm water regulations; Purpose of storrn water permit; and Requirements of storm water permit. 4.6.2 Pertinent Components of the Permit - SWMP Spill response and clean-up procedures: - Clearly identify potential spill areas and drainage routes. - Make employees aware of the materials handled, where those materials are how materials are to be handled. - Identify labels and location of Material Safety Data Sheets. - Discuss the environmental impact of potential spills. Make emergency contacts and telephone numbers readily available. - Make certain employees know the locations of spill response equipment. Drill employees on spill cleanup procedures. Good housekeeping procedures Review and demonstrate basic cleanup procedures. - Identify proper disposal methods and locations. used, and Best Management Practices - Review use of berms, grading, gravel, etc. for erosion control to avoid sedimentation. Process evaluation to evaluate procedural and equipment improvements that can cost effectively reduce the potential for chemicals to come in contact with storm water or reduce a potential for an impacted storm release. Inspections - Discuss routine inspection methods and responsibilities. 4.6.3 Reporting and Record keeping Review and demonstrate inspection reporting and record keeping procedures including appropriate liirms (Attachment A). 4.6.4 Enforcement Discuss Williams commitment to enforcement of the various components of the SWMP. Parachute Creek ( las PI.rnl t 5 (.ordj//erun (.urrrpliunre .5en,irrs. Inr- ('onNiruct r n Stcrx111 \Valet 111ana .elneni Plan (ircrrrdJleuc'rirm. ("o foredo 5.0 INSPECTION AND MAINTENANCE PROCEDURES To meet requirements of the General Permit, inspection and maintenance of erosion and sediment controls must occur during the project. Continued inspection and maintenance is required for specific structures after construction is completed. The inspection program will include the following: A qualified person familiar with the SWMP and control measures will conduct the inspections. Inspections will cover these area of the construction site: o Disturbed areas without stabilization, o Material storage areas, o Check dams, o Silt fence, o Surface water diversions, o Downgradient areas, o Locations where vehicles enter or exit the site. Inspections will occur at least once every 14 calendar days and within 24 hours of a precipitation or snow melt event that causes erosion. Permanently stabilized areas will be inspected at least once per month. A log of inspections will be kept. - Water quality will be assessed for all receiving streams and discharge areas during each inspection. Disturbed areas and material storage areas that are exposed to precipitation will be inspected for evidence of pollutants entering nearby drainages. Check darns, silt fences, and other BMPs will he inspected for evidence of deterioration, under -cutting, and build up of sediment. Sediment will be removed when it has built up one-third to one-half the height of the straw bales or silt fence. Roads used for vehicle access will be inspected for evidence of off-site sediment transport. - Following each inspection, the SWMP will be modified as necessary to include additional controls designed to correct identified problems. Revisions to the SWMP will be made within 7 days of the inspection. An inspection report summarizing the scope of the inspection, the name of the person conducting the inspection, date of inspection, and observations relating to the implementation will be prepared. Inspection reports will be retained for at least 3 years Brom the date that the site is finally stabilized. Actions taken to modify any storm water control measure will be recorded and maintairyed with the SWMP. If no deficiencies are found during the inspection, the report will contain certification that the site is in compliance with the SWMP. Signatures will be in accordance with the General Permit Conditions. Maintenance will include prompt repairs and/or adjustments to any erosion and sediment control structures that are deteriorating or found to be performing inadequately. Repairs should be made as soon as possible and prior to the next anticipated storm event. Williams or designated Parachute Creek ( las Plant 16 ('rrtcfill'ruk Co►npliaertc•r.SerVir a•1.. Inc C•unstruc1inn SIut711 Water r4ana ,etnent Plan Gfranc/Jrttu do i, ('nlurudo contractor(s) will maintain, on-site all materials necessary to make any reasonably expected repairs such as silt fence, straw bales, and stakes. 5.1 Inspection Log The following procedures for record keeping and internal reporting will be followed to keep accurate and complete documentation of events associated with the storm water management program. A SWMP Logbook will be developed for the Parachute Creek Gas Plant. Examples of the inspection checklists to be included in the logbook are presented in Attachment A. The SWMP Logbook will include an Inspection Log. This will be used, when appropriate, for recording pertinent information regarding storm water management activities. The kinds of information that will be recorded include: Observations of spills, leaks, or overflows; the location, time, date, and weather conditions when the event occurred; and the corrective actions required and taken will be recorded; Storm water management and pollution prevention training activities;. Contacts with regulatory agencies and personnel; and Maintenance and repair of structural storm water management controls. 5.2 Inspections and Record Keeping for Non -Storm Water Discharges Storm water is anticipated to leave the Parachute Creek Gas Plant Phase 3 construction site along the ground surface via drainage swales and culverts, not through sewers or other buried piping; therefore, non -storm water discharges are very unlikely to occur. However, dry weather inspection of storm water discharge outfalls will be conducted as part of the regular storm water management system inspections to make certain that non -permitted discharges are not included in permitted discharge. Results of the non -storm water discharge inspections will be recorded on the worksheet provided in the SWMP Logbook (see Attachment A), which will be kept on file at the Parachute Creek Gas Plant. 5.3 SWMP Revision Log Date Comments/Reason for Revision 5/21/02 Original SWMP Issued 7/7/04 Revised SWMP issued fair Phase 2 expansion construction 12/1/05 Revised SWMP issued for Phase 3 expansion/construction planning Parachute ("reek ( Mani ("OnstrticliUn Slum 1Vater lbianagernen1 1'l:irr 17 ( 'r,rtlr!lrrrrrr [ •nirrfrlirrrrra' kn.:F(es, /me [,, urrr! Jrutc iiu�r, i •r+krrur!<.i 6.0 CONSISTENCY WITH OTHER PLANS This SWMP has been written and revised without the preparation of a separate SPCC plan specific to construction activities. A SPCC plan for the Parachute Creek Gas Plant that complies with §112.7 of the Oil Pollution Prevention Regulation (40 CFR §112) issued under section 311 of the Federal Water Pollution Control Act has been prepared for the current operational conditions of the facility. The SPCC plan should be revised as necessary by qualified Williams personnel or by an outside party with knowledge of the facility once construction activities are complete. 7.0 ALLOWABLE NON -STORM WATER DISCHARGES No non -storm water discharge permits have been issued for construction of the Parachute Creek Gas Plant from CDPHE at this time. No discharges other than discharges entirely of storm water, except if necessary, water for fire fighting or dust -control activities are anticipated. There are no foundations or footing drains, natural springs, or landscape irrigation return flows associated with construction of the Parachute Creek Gas Plant. 8.0 ADDITIONAL REQUIREMENTS FOR FACILITIES SUBJECT TO SARA TITLE III, SECTION 313 REQUIREMENTS The Parachute Creek Gas Plant site is not subject to SARA Title III, Section 313 requirements because there have been no releases of reportable quantities of hazardous materials to land or water from this facility. Parachute Creek (las Plant Construction Sturm Water 11,1mi:igentcnl Ilan (-Onliller•urr C iynrlrlkruI r• SI 71 it a t. frtr (irrrrrrl.lrrrrr hour. (Wm (On PARACHUTE CREEK GAS PLANT FIGURES AND TABLES • F" PARACHUTE CREEK OM Ptl1MT *.r m m 2 1- 1r vs • r _K4, $.s�,' i1w • Ca ilahar ' • J SITE LEGAL LOCATION: NE NE, SECTION 33, TOWNSHIP 6 SOUTH, RANGE 96 WEST MAP SOURCE: 7.5 MINUTE U.S.G.S. TOPOGRAPHIC MAP (PARACHUTE QUADRANGLE) FIGURE 1 SITE LOCATION MAP WILLIAMS PRODUCTION RMT COMPANY PARACHUTE CREEK GAS PLANT GARFIELD COUNTY, COLORADO RCN? OAT[' 7/7/O+ HUNe(R 002 DRAAN Err NEP nrPna m er. PROJECT 0 EG02067 SCALE: 1:24,000 CORDILLERAN rtOURE 2 r,[r+n SITE NAP - J 1 OPI NAL PROPOSED PLANT CONSTRUCTION WILLIAMS PRODUCTION RMT COMPANY PARACHUTE CREEK GAS PLANT �'. GARFtELD COUNTY, COLORADO oat N e� PatnCT EGO2D67 CORDI LLERAN SCALE: AS NOTED r• INIFOFNMAT70H ONLY F rGVRE 3 $ITE LOCATION MAP — PHASE I ADDITION CONSTRUCTIO11 GRADING PLAN WILLbWS PROCUCTION. RAD COMPAN PARACMUrt CREEK GAS PLANI GARP LD COUNTY. COLORADO *IV," dee I/7?0, o [. F].. 14E. OOT Pr UhO.{D PROJECT 1 EG'0706.7 S CALE: 1.24 DCO CO RDI LLE RAN 29 • r 0 Y BM- - it • SITE LEGAL LOCATION: NE NE, SECTION 33, TOWNSHIP 6 SOUTH, RANCE 96 WEST MAP SOURCE: 7.5 MINUTE U.S-G,S. TOPOGRAPHIC MAP (PARACHUTE QUADRANGLE) ry 5464 4 411 FIGURE 5 OVERALL FACILITY LAYOUT WILLIAMS PR0DUCTION RMT C0MPANY PARACHUTE CREEK GAS PLANT GARFIELD COUNTY, COLORADO EM(yl@N 0(.TE 11/10/03 P(Vi9ON NUMB( 801 DRAWN BY: OMP OPPROKD d!- Q� PROJECT # ECO2067 SCALE: 1:24,000 CORDILLERAN TABLE 1 NOTIFICATION OF OUTSIDE PARTIES PUBLIC SAFETY OFFICIALS AND GOVERNMENT AGENCIES Williams Production RMT Company Parachute Creek Gas Plant PUBLIC SAFETY NOTIFICATION Fire 911 Police .911 GOVERNMENT AGENCY NOTIFICATIONS - VERBAL National Response Center 1-800-424-8802 (24 hr/day-7 days/week) Colorado Department of Natural Resources Oil and Gas Conservation Commission (303) 894-2100 (24 hr/day) Colorado Department of Health (303) 692-3596 (8:00-4:30) Discharge report and response center hours Garfield County Health Department (970) 625-5200 902 Taughenbaugh Boulevard Suite 104 Rifle, CO 81650 Water Quality Control .(970) 248-7150 222 South 6`11 Street #232, Grand Junction, Colorado GOVERNMENT AGENCY NOTIFICATIONS - Report spills that have the potential to reach or have Colorado Department of Health Water Quality Control Division 4300 Cherry Creek Drive South Denver, ( 'oIiIrado 80222-1 5:4) 81501 WRITTEN reached state waters to: (303) 692-3500 (8 am - 5 pm) (303) 692-3596 (notify within 24 hrs) Colorado Dcpartment of Natural Resources Oil and Gas Conservation Commission (303) 8941-2100 1120 Lincoln Street, Suite 801 (8 am - 5 pill) Denver, Colorado 80203 (notify within 24 hrs) • 1 N,BLE 1 NOTIFICATION OF OUTSIDE PARTIES PUBLIC SAFETY OFFICIALS AND GOVERNMENT AGENCIES (Continued) Williams Production RMT Company Parachute Creek Gas Plant GOVERNMENT AGENCY NOTIFICATIONS - WRITTEN Colorado Public Utilities 1580 Logan Street, 2nd Floor Denver, Colorado 80203 U.S. Department of Transportation (303) 894-2000 (7:30 to 5:30) (notify within 24 hrs) Office of Pipeline Safety Information Resource Manager Washington, DC 20590 (Gas Distribution - Form RSPAF 7100.1-1) (Gas Transmission and Gathering - Form RSPAF 7100,2-1) (202) 366-4580 U.S. Department of Transportation (303) 231-5701 Office of Pipeline Safety 12600 West Colfax Avenue, Suite A250 Lakewood, CO 80228 (To Obtain Forms RSPAF 71001-1 and 7100.2-1) • • • CONTRACTOR TABLE 2 SPILL CLEANUP CONTRACTORS Williams Production RMT Company Parachute Creek Gas Plant PHONE SERVICE D & G Roustabout Service (970) 858-1581 Roustabout 8643 20 Road #A Fruita, Colorado Roustabout Specialties Inc. (970) 241-9696 Roustabout 789 Valley Court Grand Junction, Colorado Craigs Roustabout Service (435) 828-4242 Roustabout Vernal, Utah J West. Roustabout Service (435) 828-5046 Roustabout Vernal, Utah Cordilleran Compliance Services (970) 263-7800 Environmental 826 21,/z Road Consulting and Grand Junction, Colorado Remediation Toby's Vacuum Truck Service (970) 285-7271 Vacuum Trucks 16 Murray Court Parachute, Colorado Key Energy Services (303) 659-2062 Vacuum Trucks 1313 Denver Avenue Ft. Lupton, Colorado ATTACHMENT A PARACHUTE CREEK GAS PLANT STORM WATER MANAGEMENT INSPECTION LOG AND INSPECTION FORM Storm Water Management Field Inspection Log Williams Production RMT Company Parachute Creek Gas Plant Garfield County, Colorado This log is a record of the held inspections conducted in order to determine if storm water has been impacted by industrial activities has left the Parachute Creek Gas Plant and entered navigable waters of the United States of America. Williams Production RMT Company personnel conducted these inspections during routine activities in order to identify potential storm water impacts on the following dates. Personnel conducting inspection: Date: Releases reported: Yes LNo0 Yes l''i No 0 Yes f l No C Yes 11 No n Yes n No Q Yes C No f Yes E No C� Yes f No 0 Yes r No 0 Yes f_ No 1_ l am familiar with the personnel and operations at the Parachute Creek Gas Plant, and to the best of my knowledge, the information contained is true and accurate.. Narne/Title Date: • SWMP INSPECTION REPORTING FORM Parachute Creek Gas Plant Permit No. COR -034248 By: Date: Overall Condition Need Repair G — GOOD, F = FAIR, P = POOR, Y = YES, N = NO Comments STRUCTURAL MEASURES - Sediment Containment Systems (; 1. 1'' Barriers for Sheet Flows Bale (; 1' Y Silt Fence (; F I Y N (i F P Y N Drainitnlet Protection Bale Barriers (1 F P Y N Rock Barriers G (. F F P P ()' Y N N Inserts (x F 1' ' N Channel Check Structures Bale Barriers (1 F t' Y N Rock Barriers , GF P Y N G F P Y N Other BMPs Vehicle Tracking Pad (i r 1: I' 1' Y 1 N s .\ ON—STRUCTURAL MEASURES — - Diversion Dikes andlor %vales G F 1' Y N Slope Drains (i F P Y N Temporary Vegetation (i F 1' ' )' Perennial Vegetation 6 F P V N Mulch and/or BIN! Protection J G - F 1' Y N Soil Binder Protection G 1' 1' Y N Hillside RECPs G F 1' Y N Drainage Channel TRv1s i [; 1= P Y N Riprap and/or (i ihio11s (i F I' Y N (; ( F P Y N N F 1' ' Y SWMP INSPECTION REPORTING FORM Will existing BMPs need to be modified or removed or additional BMPs installed? YES NO If yes, list the action items to be completed on the following table. Actions to he completed Date Goznpleted 1. Amoun (Inchcs)t� '. Evens . Duration (Hours) 4. 6. Reason for inspection: Routine 14 -day interval Significant storm event. Weather information since the last inspection was held. Even: Date Began Duration (lours) Amoun (Inchcs)t� '. Evens Date Began Duration (Hours) Amount; (Inches) 3 4 5 , 6 Are uncontrolled releases of mud or muddy water from the site and/or deposits of sediment. evident? YES NO If yes, where and what corrective actions are to occur? Arc non-compliance incidents evident? YES NO If no, sign the following certification: I certify thy facility is in compliance with the SWMP and this perrnit.. If yes, should the SWMP document or drawings be modified? YES NO If yes, the following drawing modifications are to be completed within seven days. Comments: Inspection completed on: by: (Signature) "Fitic!Qualification of Inspector: - • ATTACHMENT B PARACHUTE CREEK GAS PLANT TYPICAL STORM WATER BMP DETAILS -- Silt Fence - Straw Bale Barrier - Check Dams - Fiber Rolls -Gravel Bag Berms - Storm Drain Inlet Protection - Stabilized. Construction Entrance/Exit - Stabilized Construction Roadway - Entrance/Outlet Tire Wash Silt Fence Description and Purpose A silt fence is made of a filter fabric that has been entrenched, attached to supporting poles, and sometimes backed by a plastic or wire mesh for support. The silt fence detains sediment -laden water, promoting sedimentation behind the fence Targeted Constituents - Sediment Nutrients - Trash - Metals - Bacteria Oil and Grease Organics Potential Alternatives Fiber Rolls - Gravel Bag Berm Sandbag Barrier Straw Bale Barrier Suitable Applications Silt fences are suitable for perimeter control, placed below areas where sheet Mows discharge from the site. They should also be used as interior controls below disturbed areas where runoff may occur in the form of sheet and rill erosion. Silt fences are generally ineffective in locations where the flow is concentrated and are only applicable for sheet or overland flows_ Silt fences are most effective when used in combination with erosion controls. Suitable applications include: Along the perimeter ofa project. Below the toe or down slope of exposed and erodible slopes. Along streams and channels. Around temporary spoil areas and stockpiles. Below other small cleared areas. Silt Fence: 13M1' Document (onsrruction Storm Water Management Plain 1 uC' ! •m-.1111r+.r+r c ••mpliance e.s. Inc II r+,aa+l.lrr++01101+, (.nlrrruiln Silt Fence Iirnitations Do not use in streams, channels, drain inlets, or anywhere flow is concentrated. Do not use in locations where ponded water may cause flooding. Do not place fence on a slope, or across any contour line. If not installed at the same elevation throughout, silt fences will create erosion. Filter fences will create a temporary sedimentation pond on the upstream side of the fence and may cause temporary flooding. Fences not constructed on a level contour will be overtopped by concentrated flow resulting in failure of the filter fence_ Improperly installed fences are subject to failure from undercutting, overlapping, or collapsing. Not effective unless trenched and keyed in. Not intended for use as mid -slope protection on slopes greater than 4:1 (H:V). Do not allow water depth to exceed 1.5 ft at any point. Iniplementation General A silt fence is a temporary sediment barrier consisting of filter fabric stretched across and attached to supporting posts, entrenched, and, depending upon the strength of fabric used, supported with plastic or wire mesh fence. Silt fences trap sediment by intercepting and detaining small amounts of sediment -laden runoff from disturbed areas in order to promote sedimentation behind the fence. Silt fences are preferable to straw bale barriers in many cases. Laboratory work at the Virginia Highway and Transportation Research Council has shown that silt Fences can trap a much higher percentage of suspended sediments than can straw bales. While the failure rate of silt fences is lower than that of straw bale barriers, there are many instances where silt fences have been improperly installed. The following layout and installation guidance can improve performance and should be followed: Use principally in areas where sheet flow occurs. Don't use in streams, channels, or anywhere flow is concentrated. Don't use silt fences to divert flow. Don't use below slopes subject to creep, slumping, or landslides. Select filter fabric that retains 85% of soil by weight, based on sieve analysis, but that is not finer than an equivalent opening size of 70. Install along a level contour, so water does not pond more than 1.5 0 at any point along the silt fence. The maximum length of slope draining to any point along the silt fence should be 200 ft or Tess. The maximum slope perpendicular to the fence line should be I:1. Provide sufficient room for runoff to pond behind the fence and to allow sediment removal equipment to pass between the silt fence and toes of slopes or other obstructions. About 1200 ft= of ponding area should be provided for every acre draining to the fence. `burro the ends of the filter fence uphill to prevent storm water from flowing around the fence. Leave an undisturbed or stabilized area immediately down slope from the fence where feasible. Sih fiances should remain. in place until Ile • disturbed area is pe1mirnently stabilized. sill' 1 rnrr 1 t!111' 1 ]ni urne1H tit 1VYIli 5lt 1111 Nan ' 1011 C rhr(Gllr'Pieu (r+Je7IOban( e ,Tel ft es. hi? GhThlit,llhli/Ui. h,Irl/ • Silt Fence Design and Layout Selection of a filter fabric is based on soil conditions at the construction site (which affect the equivalent opening size (EOS) fabric specification) and characteristics of the support fence (which affect the choice of tensile strength). The designer should specify a filter fabric that retains the soil found on the construction site yet that it has openings large enough to permit drainage and prevent clogging. The following criteria is recommended for selection of the equivalent opening size: 1. If 50 percent or less of the soil, by weight, will pass the U.S. Standard Sieve No. 200, select the EOS to retain 85 % of the soil. The EOS should not be finer than EOS 70. 2. For all other soil types, the EOS should be no larger than the openings in the U.S. Standard Sieve No. 70 except where direct discharge to a stream, lake, or wetland will occur, then the EOS should be no larger than Standard Sieve No. 100. To reduce the chance of clogging, it is preferable to specify a fabric with openings as large as allowed by the criteria. No fabric should be specified with an EOS smaller than. U.S. Standard Sieve No. 100. If 85% or more of a soil, by weight, passes through the openings in a No. 200 sieve, filter fabric should not be used. Most of the particles in such a soil would not be retained if the EOS was too large and they would clog the fabric quickly if the EOS were small enough to capture the soil. The fence should be supported by a plastic or wire mesh if the fabric selected does not have sufficient strength and bursting strength characteristics for the planned application (as recommended by the fabric manufacturer). Filter fabric material should contain ultraviolet inhibitors and stabilizers to provide a minimum of six months of expected usable construction life at a temperature range of 0 °F to 120 '°F. Layout in accordance with attached figures. For slopes steeper than 2:1 (I I:V) and that contain a high number of rocks or large dirt clods that tend to dislodge, it may be necessary to install additional protection immediately adjacent to the bottom of the slope, prior to installing silt fence. Additional protection may be a chain link fence or a cable fence. For slopes adjacent to sensitive receiving waters or Environmentally Sensitive Areas (ESAs), silt fence should be used in conjunction with erosion control MMPs. Materials Silt fence fabric should be woven polypropylene with a minimum width of 36 in_ and a minimum tensile strength of 100 Ib lbrce. The fabric should conform to the requirements in ASTM designation 1)4632 and should have an integral reinforcement layer. The reinforcement layer should be a polypropylene, or equivalent, net provided by the manufacturer. The permittivity of the fabric should be between 0.1 sec- I and 0.15 sec -1 in conformance with the requirements in ASTM designation 134491. Wood stakes should be commercial quality lumber of the size and shape shown on the plans. Each stake should be free from decay, splits or cracks longer than the thickness of the stake or other defects that ‘v-ould weaken the stakes and cause the stakes to be stntcturally unsuitable. Staples used to fasten the fence fabric to the stakes should be not less than 1.75 in_ long and should be tirbricatcd from 15 gauge or heavier wire. 1 he wire used to fasten the tops of the stakes together \Oben joining trio sections of fence ,h'niId Inc 9 puee or heavier wire. Galvanizing of the fastening, wire 'trill not be required. Sitr Fence HMV Document ; 4,1 - (r 0 . /dirt -e71: I . i!Ttf rhINk n' 5E11 IE e.%. hit ['unstruction Storm \Ville' ILl;rrrns:_c111L•rlt I'Itrrr [io,mii.hon rlurr. (:+lEnthl Silt Fence There are new products that may use prefabricated plastic holders for the silt fence and use bar reinforcement instead of wood stakes. if bar reinforcement is used in lieu of wood stakes, use number four or greater bar. Provide end protection for any exposed bar reinforcement. Installation Guidelines Silt fences are to be constructed on a level contour. Sufficient area should exist behind the fence for ponding to occur without flooding or overtopping the fence. ('fasts A trench should be excavated approximately 6 in. wide and 6 in. deep along the line the proposed silt fence. Bottom of the silt fence should be keyed -in a minimum of 12 in. Posts should be spaced a maximum of 6 ft apart and driven securely into the ground a minimum of 18 in. or 12 in. below the bottom of the trench. When standard strength filter fabric is used, a plastic or wire mesh support fence should be fastened securely to the upslope side of posts using heavy—duty wire staples at least 1 in. long. The mesh should extend into the trench. When extra -strength filter fabric and closer post spacing are used, the mesh support fence may be eliminated. Filter fabric should be purchased in a long roll, then cut to the length of the barrier. When joints are necessary, filter cloth should be spliced together only at a support post, with a minimum 6 in. overlap and both ends securely fastened to the post. The trench should be backfilled with compacted native material. Construct silt fences with a setback of at least 3 ft from the toe of a slope. Where a silt fence is determined to be not practicable due to specific site conditions, the silt fence may be constructed at the toe of the slope, but should be constructed as far from the toe of the slope as practicable. Silt fences close to the toe of the slope will be less effective and difficult to maintain. Construct the length of each reach so that the change in base elevation along the reach does not exceed 1/3 the height of the barrier; in no case should the reach exceed 500 ft. Average annual cost for installation and maintenance (assumes 6 month useful life): $7 per lineal foot ($850 per drainage acre). Range of cost is $3.501- $9.10 per lineal foot. inspection and Maintenance Inspect I3MPs prior to forecast rain, daily during extended rain events, after rain events, weekly during the rainy season, and at two-week intervals during the non -rainy season. Repair undercut silt fences. Repair or replace split, torn, slumping, or weathered fabric. The lifespan of silt fence fabric is generally 5 to 8 months. Silt fences that are damaged and become unsuitable for the intended purpose should be removed from the site of work, disposed of, and replaced with new silt fence barriers. Sediment that accumulates in the BMP must be periodically removed in order to maintain BMP effectiveness. Sediment should be removed when the sediment accumulation reaches one-third of the ban-ier height. Sediment removed during maintenance Inay be incorporated into earthwork on the site or disposed at an appropriate location. Silt fences should be lett in place until the upstream area is permanently stabilized. Until then, the silt fence must be inspected and maintained. tittt Fence UN1t' 1)ocuiueni ( unstitinlrin Water IN1aui:rgement Plan 1 ,r - ( r,,,l,ll, rer„ r 0Mr. i4101t e .ti,,,,, rk. 1,i, tuu,, r',rjr,rurlr, Silt Fence Holes, depressions, or other ground disturbance caused by the removal of the silt fences should. be backfilled and repaired. References Manual of Standards of Erosion and Sediment Control Measures, Association of Bay Area Governments, May 1995. National Management Measures to Control Nonpoint Source Pollution from Urban Areas, United States Environmental Protection Agency, 2002_ Proposed Guidance Specifying Management Measures for Sources of Nonpoint Pollution in Coastal Waters, Work Group -Working Paper, USEPA, April 1992. Sedimentation and Erosion Control Practices, and Inventory of Current Practices (Draft), UESPA, 1990. Southeastern Wisconsin Regional Planning Commission (SWRPC). Costs of Urban Nonpoint Source Water Pollution Control Measures. Technical Report No_ 31. Southeastern Wisconsin Regional Planning Commission, Waukesha, WI. 1991 Storm water Quality Handbooks - Construction Site Best Management Practices (BMPs) Manual, State of California Department of Transportation (Caltrans), November 2000. Storm water Management Manual for The Puget Sound Basin, Washington State Department of Ecology, Public Review Draft, 1991. U.S. Environmental Protection Agency (USEPA). Stormwater Management for Industrial Activities: Developing Pollution Prevention Plans and Best Management Practices. U.S. Environmental Protection Agency, Office of Water, Washington, DC, 1992. Water Quality Management Plan for the Lake Tahoe Region, Volume I1, Handbook of Management Practices, Tahoe Regional Planning Agency, November 1988. California Storm Water Quality Association, California Storm Water BMP Handbook — Construction, January 2003. `+ill Fence I3h'l1' t)ru(nnen of 7 (e,r,Gle, i, r (. irrrrphirfic c Sill l< r+. Jin ('ontilru Ikon Slurin Water ht;ur,iLc•rPlan (r'r-riul.Irrrr, non, (.'rrlurwclu Silt Fence \ .Sep rote 1 0 [ cr 4§ \j d / £ %hlwmeBMP 1) m Qm%mdanSinwaelyam7mentmm: thfl \�0 bt t,rneo up s•ope CROSS BARRIER DETAIL cd ir c +1,o"nc• to ensure { t. SECTION C—C \Tu \ } ta rtir7 ('rzwmQ,ihnh i /01 QmQ amw DQw Silt Fence —J to, 0,a t 76 „DINING SECICN DETAIL ( TOP VIEW) -7 '71 S 111 l• clic': 11(1P I )ticumen1 Consirticlisin illef I1aiiuenieii Plan •13E 1.1 a 4— KE DETAIL (TOP v Lco 7 LJ 1.1 • • • • • • ; • . . . • . . ; r END DETAIL 714 7 ( .1111t.r.ifl (.(111.1p11.111) t' k, (;ililiti.J/M(fUIP.. ( Straw Bale Barrier Description and Purpose A straw bale barrier is a series of straw bales placed on a level contour to intercept sheet Bows. Straw hale barriers pond sheet- flow runoff, allowing sediment to settle out. Targeted Constituents Sediment - Nutrients - Trash Metals - Bacteria - Oil and Grease Organics Potential Alternatives - Silt Fence - Fiber Rolls - Gravel Bag Berm - Sandbag Barrier Suitable Applications Straw bale barriers may be suitable: As a linear sediment control measure: - Below the toe of slopes and erodible slopes - As sediment traps at culvertipipe outlets Below other small cleared areas - Along the perimeter of a site - Down slope of exposed soil areas. - Around temporary stockpiles and spoil areas - Parallel to a roadway to keep sediment off paved areas - Along streams and channels As linear erosion control measure: - Along the face and at grade breaks of exposed and erodible slopes and spread runoff as sheet flow At the top of slopes to divert runoff away from disturbed slopes As check dams across mildly sloped construction roads Straw Bale Barrier I3i.1 P i koeurnenn Construction Storni wale] NrianaLeincni Plan to shor .NT scope length 1 of + r -rrr llrlle•rrrrr f 'tom/theme * Bert le e' %. lrrt f rr enral.lt�.nt bion, C r.ofrrrrnlrr Straw Bale Barrier Limitations Straw bale barriers: Are not to be used for extended periods of time because they tend to rot and fall apart Are suitable only for sheet flow on slopes of 10 % or flatter Are not appropriate for large drainage areas, limit to one acre or less May require constant maintenance due to rotting Are not recommended for concentrated flow, inlet protection, channel flow, and live streams Cannot be made of bale bindings of jute or cotton Require labor-intensive installation and maintenance Cannot be used on paved surfaces Should not to be used for drain inlet protection Should not be used on lined Glitches May introduce undesirable non-native plants to the area Implementation General A straw bale barrier consists of a row of straw bales placed on a level contour. When appropriately placed, a straw bale barrier intercepts and slows sheet flow runoff, causing temporary ponding. The temporary ponding provides quiescent conditions allowing sediment to settle. Straw bale barriers also interrupt the slope length and thereby reduce erosion by reducing the tendency of sheet flows to concentrate into rivulets, which erode rills, and ultimately gullies, into disturbed, sloped soils. Straw bale barriers have not been as effective as expected due to improper use. These barriers have been placed in streams and drainage ways where runoff volumes and velocities have caused the barriers to wash out. In addition, failure to stake and entrench the straw bale has allowed undercutting and end flow. Use of straw bale barriers in accordance with this 13MP should produce acceptable results. Design and Layout Locate straw bale barriers on a level contour. - Slopes up to 10:1 (H:V): Straw bales should be placed at a maximum interval of 50 f1 (a closer spacing is more effective), with the first row near the toe of slope. - Slopes greater than 10:1 (H:V): Not recommended. Tuni the ends of the straw bale barrier up slope to prevent runoff from going around the barrier. Allow sufficient space up slope from the barrier to allow ponding, and to provide room for sediment storage. Lor installation near the toe of the slope, consider moving the barrier away from the slope toe to facilitate cleaning. To prevent flow behind the barrier, sand bags can be placed perpendicular to the barrier to serve as cross barriers. Drainage area should not exceed 1 acre, or 0.25 acre per 100 ft of barrier. Maxin7.uni flow path to the barrier should be limited to 100 ft. Straw hale harriers should consist of two parallel rows. - Butt ends of hales tightly. Stagger butt joints between front and back row Each row of bales must be trenched in and firmly staked Straw bale barriers arc limited in height to one hale laid on its side. Straw bale Barrier tihitl' 1)ocuniertl ? tit ("en Hiller' t C'omplrum-r.tit r-r,rr.s. Int Uonsiruclittrr titurrn I aler 11anatzenunt flan Gram/ Jun, non, i'r,lnruclr, Straw Bale Barrier Anchor bales with either two wood stakes or four bars driven through the bale and into the soil. Drive the first stake towards the butt joint with the adjacent bale to force the bales together. See attached figure for installation details. Materials Straw Bale Size: Each straw bale should be a minimum of 14 in. wide, 18 in. in height, 36 in. in length and should have a minimum mass of 50 lbs. The straw bale should be composed entirely of vegetative matter, except for the binding material. Bale Bindings: Bales should be bound by steel wire, nylon or polypropylene string placed horizontally. Jute and cotton binding should not be used. Baling wire should be a minimum diameter of 14 gauge. Nylon or polypropylene string should be approximately 12 gauge in diameter with a breaking strength of 80 lbs force. Stakes: Wood stakes should be commercial quality lumber of the size and shape shown on the plans. Each stake should be free from decay, splits or cracks longer than the thickness of the stake, or other defects that would weaken the stakes and cause the stakes to be structurally unsuitable. Steel bar reinforcement should be equal to a #4 designation or greater. End protection should be provided for any exposed bar reinforcement. Costs Straw bales cost $5 - $7 each. Adequate labor should be budgeted for installation rind maintenance. Inspection and Maintenance Maintenance Inspect BMPs prior to forecast rain, daily during extended rain events, after rain events, weekly during the rainy season, and at two-week intervals during the non -rainy season. Straw bales degrade, especially when exposed to moisture. Rotting bales will need to be replaced on a regular basis. Replace or repair damaged bales as needed. Repair washouts or other damages as needed. Sediment that accumulates in the I3MP must be periodically removed in order to maintain BMP effectiveness. Sediment should be removed when the sediment accumulation reaches one-third of the barrier height. Sediment removed during maintenance may be incorporated into earthwork on the site or disposed at an appropriate location. Remove straw bales when no longer needed. Remove sediment accumulation, and clean, re - grade, and stabilize the area. Removed sediment should be incorporated in the project or disposed of. References Sturmwater Quality Handbooks - Construction Site Best Management Practices (BM )s) Manual, State of California Department of Transportation (Caltrans), November 2000. California Storm Water Quality Association, California Storm Water BMP 1landhook January 2001 Sit ay. kale 1Jan ter 13)'.11' 1hxuntcnt onstruction, 3 tit- : {'rii ridler-rrrr (rrrrrr'lr.rrvr e Set-lit-c.v. Int. f'i,it irueli0m Sterna) 4'w' iter >' itilugenueiri Plait (,rurrddrrrrcrrr+u, Craw -ado • • Straw Bale Barrier C.1 -p d c CI •' u, 11 u,� Str;ru Rale Barrier RMP Document t. Lnr,lruciitln Salmi Water Management Plan as d5 l��nea uP &We.. caa cnnaIt 4^ 7 } •1 ▪ = L • F •,i�nw :tsa IC ?fight y tagether sales n! Inslc':ed rime ono a max "+auld oe of • r 4 or 5 C'rardilll rws PmpIi nh e .Sart rr J't lrrx irl'[aTrel.{1rA7!'lrllrr, t Nlrrr Iklrr • • Straw Bale Barrier LijW . E • SECTION 9-8 Li 0 CI - • Si raw Bale liarrser liMli Poctiotreni 5 oic ('S ( .17narluttice Serra -et'. ine• Consirtichon Si in Water Manaventeni Mari Grand,Thowilf111, Cflkoracia) • Check Dams Description and Purpose A check dam is a small barrier constructed of rock, gravel bags, sandbags, fiber rolls, or reusable products, placed across a constructed swale or drainage ditch. Check dams reduce the effective slope of the channel, thereby reducing the velocity of flowing water, allowing sediment to settle and reducing erosion. Targeted Constituents - Sediment - Nutrients - Trash Metals - Bacteria - Oil and Grease Organics Suitable Applications Check dams may be appropriate in the following situations: Potential Alternatives - Fiber Rolls Gravel Bag Berm Sandbag Barrier To promote sedimentation behind the dam. To prevent erosion by reducing the velocity of channel flow in small intermittent channels and temporary swales. In small open channels that drain 10 acres or less. In steep channels where stormwater runoff velocities exceed 5 ft/s. During the establishment of grass Linings in drainage ditches or channels. In temporary ditches where the short length of service does not warrant establishment of erosion -resistant linings. ( heck 1)ams I3htl' 1)oc•umenl (t sfrULIIOrr Slllrin \ alcr NI:iilarCilkl•ilt 1 of 3 ("+++r7,(+hiuu • Sco ++ c ., hid 1P7'llih/.+r SA [kto Check Dams Limitations Not to be used in live streams or in channels with extended base flows. Not appropriate in channels that drain areas greater than I0 acres_ Not appropriate in channels that are already grass -lined unless erosion is expected, as installation may damage vegetation. Require extensive maintenance following high velocity flows. Promotes sediment trapping which can be re -suspended during subsequent storms or removal of the check dam. Implementation General Check dams reduce the effective slope and create small pools in swales and ditches that drain 10 acres or less.. Reduced slopes reduce the velocity of storm water flows, thus reducing erosion of the swale or ditch and promoting sedimentation. Use of check dams for sedimentation will likely result in little net removal of sediment because of the small detention time and probable scour during longer storms. Using a series of check dams will generally increase their effectiveness. A sediment trap may be placed immediately upstream of the check dam to increase sediment removal efficiency. Design and Layout Check dams work by decreasing the effective slope in ditches and swales. An important consequence of the reduced slope is a reduction in capacity of the ditch or swale. This reduction in capacity must be considered when using this BMP, as reduced capacity can result in overtopping of the ditch or swale and resultant consequences. In some cases, such as a "permanent" ditch or swale being constructed early and used as a "temporary" conveyance for construction flows, the ditch or swale may have sufficient capacity such that the temporary reduction in capacity due to check dams is acceptable. When check dams reduce capacities beyond acceptable limits, there are several options: Don't use check dams. Consider alternative BMPs. Increase the size of the ditch or swale to restore capacity_ Maximum slope and velocity reduction is achieved when the toe of the upstream damis at the same elevation as the top of the downstream dam. The center section of the dam should be lower than the edge sections so that the check dam will direct flows to the center of the ditch or swale. Check dams are usually constructed of rock, gravel bags, sandbags, and fiber rolls. A number of products manufactured specifically fax use as check dams are also being used, and some of these products can be removed and reused. Check dams can also be constructed of Togs or lumber, and have the advantage of a longer lifespan when compared to gravel bags, sandbags, and fiber rolls. Straw bales can also be used for check dams and can work if correctly installed; but in practice, straw hale check dams have a high failure rate. Check dams should not be constructed Brom straw bales or silt fences, since concentrated flows quickly wash out these materials. Rock check dams are usually constructed of 8 to 12 in. rock. The rock is placed either by hand or mechanically, but never just dumped into the channel. The dans) must completely span the ditch or swale to prevent washout. The rock used must be large enough to stay in place given the expected design flow through the channel. Cheek Dain IiV1n" 1 )i crsmrnt C'unstrucnon Swim V%, mei '11,irid1Jcnrrn1 Man 2 of ( i,rJlillerem ('rrnrplioneeServices, Inc. (iron dJune tsnn. Crrlrrr nki Check Dams Log check dams are usually constructed of 4 to 6 in. diameter logs. The logs should be embedded into the soil at least 18 in. Logs can be bolted or wired to vertical support logs that have been driven or buried into the soil. Gravel bag and sandbag check dams are constructed by stacking bags across the ditch or swale, shaped as shown in the drawings at the end of this fact sheet. Manufactured products should be installed in accordance with the manufacturer's instructions. If grass is planted to stabilize the ditch or swale, the check dam should be removed when the grass has matured (unless the slope of the swales is greater than 4%). The following guidance should be followed for the design and layout of check dams: Install the first check dam approximately 16 ft from the outfall device and at regular intervals based on shape gradient and soil type. Check dams should be placed at a distance and height to allow small pools to form between each check dam. Backwater from a downstream check dam should reach the toes of the upstream check dam. A sediment trap provided immediately upstream of the check dam will help capture sediment. Due to the potential for this sediment to be resuspended in subsequent storms, the sediment trap must be cleaned following each storm event. High flows (typically a 2 -year storm or larger) should safely flow over the check dam without an increase in upstream flooding or damage to the check dam. Where grass is used to line ditches, check dams should be removed when grass has matured sufficiently to protect the ditch or swale. Gravel bags may be used as check dams with the following specifications: Materials Caravel bags used for check dams should conform to the requirements of gravel bag berms. Sandbags used for check dams should conform to sandbag barrier guidelines. Fiber rolls used for check dams should conform to fiber roll requirements. Straw bales used for check dams should conform to straw bale barrier requirements. Installation Rock should be placed individually by hand or by mechanical methods (no dumping of rock) to achieve complete ditch or swale coverage. Tightly abut bags and stack according to detail shown in the figure at the end of this section. Gravel bags and sandbags should not be stacked any higher than 3 ft. Fiber rolls and straw bales must he trenched in and firmly staked in place. Costs Cost consists of only installation costs if materials are readily available.. lfrnaterial must he imported, costs may increase. ('heck Darns UMP Document Construction Storm Water Manaecincnt flan C vl S 4 10rrlrlll n:Pi e .Seri ir'c+. lrre 1 iruur! Ju,rr r on. C,,lorarlu • Check Dams Inspection and Maintenance Inspect BM Ps prior to forecast rain, daily during extended rain events, after rain events, weekly during the rainy season, and at two-week intervals during the non -rainy season. Replace missing rock, bags, bales, etc. Replace bags or bales that have degraded or have become damaged. If the check dam is used as a sediment capture device, sediment that accumulates in the BMP must be periodically removed in order to maintain BMP effectiveness. Sediment should be removed when the sediment accumulation reaches one-third of the barrier height. Sediment removed during maintenance may be incorporated into earthwork on the site or disposed at an appropriate location. If the check dam is used as a grade control structure, sediment removal is not required as long as the system continues to control the grade. Remove accumulated sediment prior to permanent seeding or soil stabilization. Remove check dam and accumulated sediment when check dams are no Ionger needed. References Draft — Sedimentation and Erosion Control, and Inventory of Current Practices, USEPA, April 1990. Manual of Standards of Erosion and Sediment Control Measures, Association of Bay Area Governments, May 1995. Storm water Quality Handbooks - Construction Site Best Management Practices (BMPs) Manual, State of California Department of Transportation (Caltrans), November 2000. • Storm water Management of the Puget Sound Basin, Technical. Manual, Publication #91-75, Washington State Department of Ecology, February 1992. California Storm Water Quality Association, California Storm Water BMP Handbook — Construction, January 2003. Check tlatns t d I1' tloeurnenl Construction Storni water Man.igerrsen1 Plan a of s ( (nnuihri rre .SeTvor-e.r. /sic (irrrrrrl.hrurltun. (nlnrurlrr Check Dams 8 to 12" diameter rock F1 ow ELE VA TION a�� o cP53,0 1 IMP 4jaC) 0 x TYPICAL ROCK CHECK DAM SEC -110N CC< CHECK DAN NO1 TO SCALL Check, Danis 1.3N11' 1)ocurnenl ('onstrttCtiun Sturm Nater M1;nnageIi !nl I'I;tii r, T ul f e0V4ialrrura (rnriphahfir if e".1, l�rs r,r r+rrl filth rrufr, Colorado Fiber Rolls Description and Purpose A fiber roll consists of straw, flax, or other similar materials bound into a tight tubular roll. When fiber rolls are placed at the toe and on the face of slopes, they intercept runoff, reduce its flow velocity, release the runoff as sheet flow, and provide removal of sediment from the runoff By interrupting the length of a slope, fiber rolls can also reduce erosion. Targeted Constituents - Sediment - Nutrients Trash - Metals - Bacteria Oil and Grease Organics Suitable Applications Fiber rolls may be suitable: Potential Alternatives - Silt Fence Gravel Bag Berm - Sandbag Barrier - Straw Bale Barrier Along the toe, top, face, and at grade breaks of exposed and erodible slopes to shorten slope length and spread runoff as sheet flow. At the end of a downward slope where it transitions to a steeper slope Along the perimeter of a. project As check dams in unlined ditches Down-slope of exposed soil areas Around temporary stockpiles Hier Rolls tthgl' I)ocurmrrl ['onslruc1iifri Silllm \V uler l44rrnugeiiiei l Man 1 or 4 [ `r,rd lh^rarr (`r)r rjrjirrrre r ,4rr ti�r� ,cs, l+ar (rr4.11/d Me /rear, ('r,lurekju Fiber Rolls Limitations Fiber rolls are not effective unless trenched Fiber rolls at the toe of slopes greater than 5:1 (H:V) should be a minimum of 20 in. diameter or installations achieving the same protection (i.e. stacked smaller diameter fiber rolls, etc.). Difficult to move once saturated. If not properly staked and trenched in, fiber rolls could be transported by high flows. Fiber rolls have a very limited sediment capture zone. Fiber rolls should not be used on slopes subject to creep, slumping, or landslide. implementation Fiber Roll Materials Fiber rolls should be either prefabricated rolls or rolled tubes of erosion control blanket. Assembly of Field Rolled Fiber Roll Roll length of erosion control blanket into a tube of minimum 3 in. diameter. Bind roll at each end and every 4 ft along Iength of roll with jute -type twine. Installation Locate fiber rolls on level contours spaced as follows: Slope inclination of 4:1 (H:V) or flatter: Fiber rolls should be placed at a maximum interval of 20 ft. Slope inclination between 4:1 and 2:1 (H:V): Fiber Rolls should be placed at a maximum interval of 15 ft. (a closer spacing is more effective). Slope inclination 2:1 (H:V) or greater: Fiber Rolls should be placed at a maximum interval of 10 ft. (a closer spacing is more effective). Turn the ends of the fiber roll up slope to prevent runoff from going around the roll. Stake fiber rolls into a 2 to 4 in. deep trench with a width equal to the diameter of the fiber roll. Drive stakes at the end of each fiber roll and spaced 4 ft maximum on center. Use wood stakes with a nominal classification of 0.75 by 0.75 in. and minimum length of 24 in. If more than one fiber roll is placed in a row, the rolls should be overlapped, not abutted. Removal F if,er rolls are typically left in place. It fiber rolls are removed, collect and dispose .of sediment accumulation, and fill and compact holes, trenches, depressions or any other ground disturbance to blend with adjacent ground. Costs Material costs for fiber rolls range from 52.0- 530 per 25 ft roll. Inspection and Maintenance Inspect BM1's prior to forecast rain, daily during extended rain events, alter rain events, weekly during the rainy season, and at two-week intervals during the non -rainy season. Repair or replace split. torn. unraveling, or slumping liber rolls. I ik t r Rolls BMP Document ( ,rig dt(leiio,n Storm Water 1\1:Inilecltlent 1'I;iri 2 or 1 (`,,, h/fr•rrrrr (-rrrrl!frfr,r Fiber Roils If the fiber roll is used as a sediment capture device, or as an erosion control device to maintain sheet flows, sediment that accumulates in the BMP must be periodically removed in order to maintain BMP effectiveness. Sediment should be removed when sediment accumulation reaches one-half the designated sediment storage depth, usually one-half the distance between the top of the fiber roll and the adjacent ground surface. Sediment removed during maintenance may be incorporated into earthwork on the site of disposed at an appropriate location. If fiber rolls are used for erosion control, such as in a mini check darn, sediment removal should not be required as long as the system continues to control the grade. Sediment control BMPs will likely be required in conjunction with this type of application. References Stormwater Quality Handbooks - Construction Site Best Management Practices (BMPs) Manual, State of California Department of Transportation (Caltrans), November 2000. California Storm Water Quality Association, California Storm Water BMP Handbook — Construction, January 2003. Fiber Rolls 13M1' t)ociiri ni of 4 earth Fiera,: ('ornplinnce Serwres. J r ('unslr-uctrnn Storni \4'at t r'Ntallage11len1 Plali (i'rand,letnceiosl. Fiber Rolls L0 • z n Z 4- J 0 CfC TYPICAL. rIBE R • • 17. -7 R Gravel Bag Berm Description and Purpose A gravel bag berm is a series of gravel -filled bags placed on a level contour to intercept sheet flows. Gravel bags pond sheet flow runoff, allowing sediment to settle out, and release runoff slowly as sheet flows, preventing erosion. Targeted Constituents - Sediment Nutrients Trash Metals Bacteria - Oil and Grease - Organics Suitable Applications Gravel bag berms may be suitable: Potential Alternatives - Silt Fence Fiber Roll - Sandbag Barrier - Straw Bale Barrier As a linear sediment control measure: - Below the toe of slopes and erodible slopes - As sediment traps at culvert/pipe outlets - Below other small cleared areas Along the perimeter ()fa site Down slope of exposed soil areas Around temporary stockpiles and spoil areas Parallel to a roadway to keep sediment off paved areas Along streams and channels (ir;i\cl 14;q2 Berm LIMP Document onsiruelton Storm Water Management Plan 1 .11 -I ijIiin i SeriIsIlk (,intPori .hencto ( -colurculto Gravel Bag Berm As linear erosion control measure: Along the face and at grade breaks of exposed and erodible slopes to shorten slope length and spread runoff as sheet flow At the top of slopes to divert runoff away from disturbed slopes - As check dams across mildly sloped construction roads Limitations Gravel berms may be difficult to remove. Removal problems limit their usefulness in landscaped areas. Gravel bag berm may not be appropriate for drainage areas greater than 5 acres. Runoff will pond upstream of the filter, possibly causing flooding if sufficient space does n©t exist_ Degraded gravel bags may rupture when removed, spilling contents. installation can be labor intensive. Berms may have limited durability for long-term projects. Wien used to detain concentrated flows, maintenance requirements increase. Implementation General A gravel bag berm consists of a row of open graded gravel—filled bags placed on a level contour. When appropriately placed, a gravel bag berm intercepts and slows sheet flow runoff, causing temporary ponding. The temporary ponding provides quiescent conditions allowing sediment to settle. The open graded gravel in the bags is porous, which allows the ponded runoff to flow slowly through the bags, releasing the runoff as sheet flows. Gravel bag berms also interrupt the slope length and thereby reduce erosion by reducing the tendency of sheet flows to concentrate into rivulets, which erode rills, and ultimately gullies, into disturbed, sloped soils. Gravel bag berms are similar to sand bag barriers, but are more porous. Design and Layout Locate gravel bag berms on level contours_ - Slopes between 20:1 and 2:1 (H:V): Gravel bags should be placed at a maximum interval of 50 ft (a closer spacing is more effective), with the first row near the slope toe. - Slopes 2:1 (H:V) or steeper: Gravel bags should be placed at a maximum interval of 25 ft (a closer spacing is more effective), with the first row placed the slope toe. Turn the ends of the gravel bag barriers up slope to prevent runoff from going around the herrn. ;Allow sufficient space up slope from the gravel bag berrn to allow ponding, and to provide room for sediment storage_ For installation near the toe of the slope, consider moving the gravel bag harriers away from the slope toe to facilitate cleaning. To prevent flows behind the barrier, bags can he placed perpendicular to a berm to serve as cross harriers. Drainage area should not exceed 5 acres. In Non-Tra!Tic Areas: - l leii'ht = 18 in. tnaxitnum Top \v idth - 24 in. minimum for three or more layer construction Top width 12 in. minimum for one or Iwo layer construction (ira%el Iiag Berm t3A4t' 1)uc•umenI ('unslruilian Storni Water Mane .enrenl flan '_ iyt 4 (urchllrrun ('nraph n ci Ser•rrce . hx•. (iiand.Iun&riun. Colt walk) Gravel Bag Berm - Side slopes = 2: l or flatter In Construction Traffic Areas: Height = 12 in. maximum Top width = 24 in. minimum for three or more layer construction. Top width = 12 in. minimum for one or two layer construction. Side slopes = 2:1 or flatter. Butt ends of bags tightly On multiple row, or multiple layer construction, overlapp butt joints of adjacent row and row beneath. Use a pyramid approach when stacking bags. Materials Bag Material: Bags should be woven polypropylene, polyethylene or polyamide fabric or burlap, minimum unit weight of 4 ounces/yd2, Mullen burst strength exceeding 300 lb/in2 in conformance with the requirements in ASTM designation D3786, and ultraviolet stability exceeding 70% in conformance with the requirements in ASTM designation D4355. Bag Size: Each gravel -filled bag should have a length of 18 in., width of 12 in., thickness of 3 in., and mass of approximately 33 lbs. Bag dimensions are nominal, and may vary based on locally available materials. Fill Material: Fill material should be 0.5 to 1 in. Class 2 aggregate base, clean and free from clay, organic matter, and other deleterious material, or other suitable open graded, non- cohesive, porous gravel. Costs Gravel filter: Expensive, since off-site materials, hand construction, and demolition/removal are usually required. Material costs for gravel bags are average of $2.50 per empty gravel bag. Gravel costs range from $20-$35 per yd3. Inspection and Maintenance Inspect BMPs prior to forecast rain, daily during extended rain events, after rain events, weekly during the rainy season, and at two-week intervals during the non -rainy season. Gravel bags exposed to sunlight will need to be replaced every two to three months due to degrading of the bags. Reshape or replace gravel bags as needed. Repair washouts or other damage as needed. Sediment that accunnalates in the BMP must be periodically removed in order to maintain BMP effectiveness. Sediment should be removed when the sediment accumulation reaches one-third of the barrier height. Sediment removed during maintenance may be incorporated into earthwork on the site or disposed at an appropriate location. Remove gravel bag berms when no longer needed. Remove sediment accumulation and clean, re -grade, and stabilize the area. Removed sediment should be incorporated in the project or disposed of. (ira%el Ei.zt.+, Berm BMP t)crt;tIntcnl k,l .l (`?Jithllevtlre ['rvriplrctiuF3 .Se i t it e•1. I'll ( tttt lnulit+tt SItrnti 11'ale'r NI:iI1 t.e'itti'itl f'1:tit [, ct,rilJrul.lreut ['HIi,retch, Gravel Bag Berm References Handbook of Steel Drainage and Highway Construction, American Iron and Steel Institute, 1983. • Stormwater Quality Handbooks - Construction Site Best Management Practices (BMPs) Manual, State of California Department of Transportation (Caltrans), November 2000_ • • Stormwater Pollution Plan Handbook, First Edition, State of California, Department of l'ransportation Division of New Technology, Materials and Research, October 1992. California Storm Water Quality Association, California Storm Water BMP Handbook — Construction, January 2003. t �r.nel Bait Berm BMP Document Construction Storm Water Management Plan 4 of •1 ( .r.ntlillerarr ('unrphonrr .Sc'rvrrrs. fn[. Grund.huxuon. (',Ioraa4, • • Storm Drain Inlet Protection Description and Purpose Storm drain inlet protection consists ofa sediment filter or an impounding area around or upstream of a storm drain, drop inlet, or curb inlet. Storm drain inlet protection measures temporarily pond runoff before it enters the storm drain, allowing sediment to settle. Some filter configurations also remove sediment by filtering, but usually the ponding action results in the greatest sediment reduction. Targeted Constituents Sediment - Nutrients - Trash Metals Bacteria Oil and Grease Organics Potential Alternatives - Silt Fence - Fiber Rolls Gravel Bag Berm - Sandbag Barrier - Straw Bale Barrier Suitable Applications Every storm drain inlet receiving sediment -laden runoff should he protected. Limitations Drainage area should not exceed 1 acre. Straw bales, while potentially effective. have not produced in practice satisfactory results, primarily due to improper installation. Requires an adequate area for water to pond without encroaching into portions of the roadway subject to traffic. Inlet protection usually requires other methods of temporary protection to prevent sediment - laden storm water and non -storm water discharges from entering the storm drain system. Sediment removal may be difficult in high tlow conditions or if runoff is heavily sediment laden. If high flow conditions are expected, use other onsite sediment trapping techniques in conjunction with inlet protection. tit0110 1)rjtii Intel Pruteetntn 11MP nejeutnent 1 u1'5 t <ortslrueIiun Storm \Vater Aian:aeerucnt I'l.nI ( CPrif illerarrr i ),r,r1*11„,rr n• Si') rn ('). (rrelik /,pith !Hon. ('1,,101,1tlri Storm Drain Inlet Protection Frequent maintenance is required. For drainage areas larger than 1 acre, runoff should be routed to a sediment -trapping device designed for larger flows. Excavated drop inlet sediment traps are appropriate where relatively heavy flows are expected, and overflow capability is needed. Implementation General Large amounts of sediment may enter the storm drain system when storm drains are installed before the upslope drainage area is stabilized, or where construction is adjacent to an existing storm drain. In cases of extreme sediment loading, the storm drain itself may clog and lose a major portion of its capacity. To avoid these problems, it is necessary to prevent sediment from entering the system at the inlets. Inlet control measures presented in this handbook should not be used for inlets draining more than one acre. Runoff from larger disturbed areas should be first routed through a sediment basin or sediment trap. Different types of inlet protection are appropriate for different applications depending on site conditions and the type of inlet. Inlet protection methods not presented in this handbook should be approved by the local storrn water management agency. Design and Layout Identify existing and planned storm drain inlets that have the potential to receive sediment- laden surface runoff. Determine if storm drain inlet protection is needed and which method to use. Limit upstream drainage area to 1 acre maximum. For larger drainage areas, use a sediment basin, or a sediment trap, upstream of the inlet protection device. The key to successful and safe use of storm drain inlet protection devices is to know where runoff will pond or be diverted. Determine the acceptable location and extent of ponding in the vicinity of the drain inlet. The acceptable location and extent of ponding will influence the type and design of the storm drain inlet protection device. - Determine the extent of potential runoff diversion caused by the storm drain inlet protection device. Runoff ponded by inlet protection devices may flow around the device and towards the next downstream inlet. In some cases, this is acceptable; in other cases, serious erosion or downstream property damage can be caused by these diversions. The possibility of runoff diversions will influence whether or not storm drain inlet protection is suitable; and, if suitable, the type and design of the device. The location and extent of ponding, and the extent of diversion. can usually be controlled through appropriate placement of the inlet protection device. In some cases. moving the inlet protection device a short distance upstream of the actual inlet can provide more efficient sediment control, limit ponding to desired areas, and prevent or control diversions. Four types of inlet protection are presented below. However, it is recognized that other effective methods and proprietary devices exist and may be selected. Filter Fabric Fence: Appropriate for drainage basins with less than a 5% slope, sheet flows, and flows under 0.5 cfs. - Excavated Drop Inlet Sediment Trap: An excavated arca around the inlet to trap sediment. Storm Thain inlet Protection 13k11I' Ihrl•Ltinenr Construction Storni Water Management flan 2 of $ ( /tr,r,rr,',(!++np/iu:I 1 . erir{1.S. hit f ti MY /./11i1i Peru:. f )ifellaslra Storm Drain Inlet Protection - Gravel bag barrier: Used to create a small sediment trap upstream of inlets on sloped, paved streets. Appropriate for sheet flow or when concentrated flow may exceed 0.5 cfs, and where overtopping is required to prevent flooding. - BIock and Gravel Filter: Appropriate for flows greater than 0.5 cfs. Select the appropriate type of inlet protection and design as referred to or as described in this fact sheet. Provide area around the inlet for water to pond without flooding structures and property. Grates and spaces around all inlets should be sealed to prevent seepage of sediment -laden water. Excavate sediment sumps (where needed) 1 to 2 ft with 2:1 side slopes around the inlet. Installation DI Protection Type I - Filter Fabric Fence - The filter fabric fence (Type 1) protection is shown in the attached figure. Similar to constructing a silt fence. Do not place filter fabric underneath the inlet grate since the collected sediment may fall into the drain inlet when the fabric is removed or replaced. 1. Excavate a trench approximately 6 in. wide and 6 in. deep along the line of the silt fence inlet protection device. 2. Place 2 in. by 2 in. wooden stakes around the perimeter of the inlet a maximum of 3 ft apart and drive them at least 18 in. into the ground or 12 in. below the bottom of the trench. The stakes must be at least 48 in. 3. Lay fabric along bottom of trench, up side of trench, and then up stakes. The maximum silt fence height around the inlet is 24 in. 4. Staple the filter fabric to wooden stakes. Use heavy-duty wire staples at least 1 in. in length, 5, Backfill the trench with gravel or compacted earth all the way around. DI Protection Type 2 - Excavated Drop Inlet Sediment Trap - The excavated drop inlet sediment trap (Type 2) is shown in the attached figures. Install filter fabric fence in accordance with D1 Protection Type 1. Size excavated trap to provide a minimum storage capacity calculated at the rate 67 yd3/acre of drainage area. DI Protection Type 3 - Gravel bag - The gravel bag barrier (Type 3) is shown in the figures. Flow from a severe storm should not overtop the curb. In areas of high clay and silts, use filter fabric and gravel as additional filter media. Construct gravel bags in accordance with gravel bag berm guidelines. Gravel bags should be used due to their high permeability. 1 _ Use sand bag made of geotcxtile fabric (not burlap) and till with 0.75 in. rock or 0.25 in. pea gravel. 2. Construct on gently sloping street. 3. Leave room upstream of barrier for water to pond and sediment to settle. 4. Place several layers of sand bags - overlapping the bags and packing them tightly together. 5. Leave gap of one bag on the top row to serve as a spillway. Flow from a severe storm (e.g., 10 year stone) should not overtop the curb. 1)1 Protection Type 4 - Block and Gravel Filter - The block and gravel lliter CI yr 4) is shown in the figures. Block and gravel filters are suitable for curb inlets commonly used in residential, commercial, and industrial construction. :dorm Drain Inlet Prc►Iection ttN1P 1)t umcnt Construction Starer Water h1anneenieni Plan 3 uF P roNff HiP.N'r t' Sl'r'17l'e,. /ow [irirrrrl.lrrrre/rim. ('r+lrlr-u to Storm Drain Inlet Protection Costs 1 Place hardware cloth, or comparable wire mesh with 0.5 in. openings over the drop inlet so that the wire extends a minimum of 1 t beyond each side of the inlet structure. If more than one strip is necessary, overlap the strips. Place filter fabric over the wire mesh. 2. Place concrete blocks lengthwise on their sides in a single row around the perimeter of the inlet, so that the open ends face outward, not upward. The ends of adjacent blocks should abut. The height of the barrier can be varied, depending on design needs, by stacking combinations of blocks that are 4 in., 8 in., and 1.2 in. wide. The row of blocks should be at least 12 in. but no greater than 24 in. high. 3. Place wire mesh over the outside vertical face (open end) of the concrete blocks to prevent stone from being washed through the blocks. Use hardware cloth or comparable wire mesh with 0.5 in. opening. 4. Pile washed stone against the wire mesh to the top of the blocks. Use 0.75 to 3 in. Average annual cost for installation and maintenance (one year useful life) is $200 per inlet. Inspection and Maintenance Inspect BMPs prior to forecast rain, daily during extended rain events, after rain events, weekly during the rainy season, and at two-week intervals during the non -rainy season. Filter Fabric Fences. If the fabric becomes clogged, torn, or degrades, it should be replaced. Make sure the stakes are securely driven in the ground and are in good shape (i.e., not bent, cracked, or splintered, and are reasonably perpendicular to the ground). Replace damaged stakes. Gravel Filters. If the gravel becomes clogged with sediment, it must be carefully removed from the inlet and either cleaned or replaced. Since cleaning gravel at a construction site may be difficult, consider using the sediment -laden stone as fill material and put fresh stone around the inlet. Inspect bags for holes, gashes, and snags, and replace bags as needed. Check gravel bags for proper arrangement and displacement. Sediment that accumulates in the BMP must be periodically removed in order to maintain BMP effectiveness. Sediment should be removed when the sediment accumulation reaches one-third of the barrier height. Sediment removed during maintenance may be incorporated into earthwork on the site ore disposed at an appropriate location. Remove storm drain inlet protection once the drainage area is stabilized. Clean and regrade area around the inlet and clean the inside of the storm drain inlet as it must be free of sediment and debris at the time of final inspection. References Stormwater Quality 1 -landbooks - Construction Site Best Management Practices (BMPs) Manual, State of California Department of Transportation (Caltrans), November 2000. Storms;pater Management Manual for The Puget Sound Basin, Washington State Department of Ecology, Publii Re\ iew Draft, 1991. California Storm Water Quality Association, California Storm Water BMP Handbook - Construction, January 200.3. Storm 1)r;im Inlet PlL t cIii n 13r 1E' 1hwoment Constriction 5i;not Water Management I'l;ni .1 cif { falhNe• ani 'e++++frl++r+re c' .i=', ++ es 1+r. Fil'w711ci,Itll7t 17e�+7. 1 rrlr+tel.lir Storm Drain Inlet Protection Geotextile Blanket 24 Sheet flow Less than 1 acre [-Drain inlet SECTION A -A Drain inlet SEEM§ IMMENES ., AN , Slurp, 1 h;titi 1UICI Protection 1MI 1)ucumen1 x x Silt Fence per SE -01 1 it/ x 5" Min overlap at ends of silt fence. —Geotextile Blanket Silt I cnCe Dr- .`AL 1 r,1 ;,; ('rarchlle r.arr (r,a,lrlru„ e 5o`I' ei's. Inc Consiluction Storm Water Management Plan (;, rind _turn lrc,,,, (*olr,rsd • • • Storm Drain Inlet Protection 3 M i n —Stabilize area and grade uniformly ground perimeter Geotextile Blanket Note: Remove sediment before reaching one-third full. Concentrated flow 1:1 slope Drain inlet - Silt fence Per SE --f1 12" Min 24" Max Section A-- A Rock filter(use if flow is concentrated) Sheet flow x (I) r - x 1'11- 1 =c— == = w --r, r - I .t' 1 t •- 1 i I_ i` ++ - - •i- - - +- - - r .3•it• r tl I tilnr'rta Drain Iltltt I'ra,t<alu,n I3R1I' I)arcuntrnt ('cxnstrlicIiarn Staudt 1V'atcr INlala.agern •nt Plan 1' 'd I x Edge of sediment trap 'gain inlet Geotextile Blanket -0—Silt fence Pe, SE - 01 x :V (1 or X ['t„ell llc•r.tort L r.,mphrrrna� Sr+ -I WL %. I+rr. f;,- J, /.itta7c7Yuu, C"uhl+'tnIn • Storm Drain Inlet Protection flow Inlet Spillway, 1 -bog high -Edge of Pavemen Flow Sandbags 2- bags high TYPICAL PROTECTION FOR INLET ON SUMP d e of Pavement Inle Flow Flow Spillway, 1 -bog high Sandbags - bogs high TYDICAL PROTECTION FOR INLET ON G,ADE NJO1 1 -riencec 'or 51-rtIe 7 Jse tr. nch'i F -:•c•-•-• f^nvo A tow fur proper cfritcric-icc cri-3 9ccra r• •er- Ii e- acjoct-i : rrn si-h •-iah ji p 1 -- L.I II 1 JNI Y ' - Storm Dram Inlet Protcclimi liN111 hri Innen! it Curalilteriin Coorpliancy Servit'es. Inc Construction Storm Water Nlanalpvincill Plan GrairdJurk rum, ( 'Worm/6i Storm Drain Inlet Protection Cur! 4 d - , iii.....u...uSfl.sii e. ,i1••Mli°n:1•e1i1Meii11e 1111311 •# . t.,f foh ,^i] 1,ar.p 4l1 O. " r Concrete block laid lengthwise on sides @ perimeter of opening Runoff with sediment Overflow 1 2"- 74 Hardware cloth or wire mesh Filtered water L)+' • i4 y��.. 4 opt 4 \�`'/ /\\fes\K\ \<{', \; �•%V \ 's f Sediment ',1+ !I Drain inlet Protection HMP Document •uns1ructio11 Sill rin Water Management Plan rc cl_,fk+ of R t' 'Of 11r'i'a111 (l1!pfhli71 r' .Se'11 r+ [li, Inc (;ranrI Jiul( non, ('rrfr++•rhki Stabilized Construction Entrance/Exit Description and Purpose A stabilized construction access is defined by a point of entrance/exit to a construction site that is stabilized to reduce the tracking of mud and dirt onto public roads by construction vehicles. Targeted Constituents - Sediment Nutrients - Trash Metals Bacteria Oil and Grease Organics Potential Alternatives - None Suitable Applications Use at constriction sites: Where dirt or mud can be tracked onto public roads. Adjacent to water bodies. Where poor soils are encountered. Where dust is a problem during dry weather conditions. Limitations Entrances and exits require periodic top dressing with additional stones. This BMP should be used in conjunction with street sweeping on adjacent public right of way. Entrances and exits should be constructed on level ground only. Stabilized construction entrances are rather expensive to construct and when a wash rack is included, a sediment trap of some kind must also be provided to collect wash water runoff. Stabilized Construction 1:ntiance I-.yt tiN.11' D otiunit:in i'ons1ruetlorl Storni Wiltef N1;iil;li'eiliellt I'I.lii 1 of C'rrrrlrllr•r'rra f 'rrrrifrlrrrvrt a rho hit ttrrurelJrrrrelrou, (,'4•rlf+1f7161 Stabilized Construction Entrance/ Exit Implementation General A stabilized construction entrance is a pad of aggregate underlain with filter cloth located at any point where traffic will be entering or leaving a construction site to or from a public right of way, street, alley, sidewalk, or parking area. The purpose of a stabilized construction entrance is to reduce or eliminate the tracking of sediment onto public rights of way or streets. Reducing tracking of sediments and other pollutants onto paved roads helps prevent deposition of sediments into local storm drains and production of airborne dust. Where traffic will be entering or leaving the construction site, a stabilized construction entrance should be used. NPDES permits require that appropriate measures be implemented to prevent tracking of sediments onto paved roadways, where a significant source of sediments is derived from mud and dirt carried out from unpaved roads and construction sites. Stabilized construction entrances are moderately effective in removing sediment from equipment leaving a construction site. The entrance should be built on level ground. Advantages of the Stabilized Construction Entrance/Exit is that it does remove some sediment from equipment and serves to channel construction traffic in and out of the site at specified locations. Efficiency is greatly increased when a washing rack is included as part of a stabilized construction entrance/exit. Design and Layout Construct on level ground where possible. Select 3 to 6 in. diameter stones. Use minimum depth of stones of 12 in, or as recommended by soils engineer. Construct length of 50 ft minimum, and 30 ft minimum width. Rumble racks constructed of steel panels with ridges and installed in the stabilized entrance/exit will help remove additional sediment and to keep adjacent streets clean. Provide ample turning radii as part of the entrance. Limit the points of entrance/exit to the construction site. Limit speed of vehicles to control dust. Properly grade each construction entrance/exit to prevent runoff from leaving the construction site. Route runoff from stabilized entrances/exits through a sediment trapping device before discharge. Design stabilized entrance/exit to support heaviest vehicles and equipment that will use it. Select construction access stabilization (aggregate, asphaltic concrete, concrete) based on longevity, required performance, and site conditions. Do not use asphalt concrete (AC) grindings for stabilized construction access/roadway. If aggregate is selected. place crushed aggregate over geotextile fabric to at least 12 in. depth, or place aggregate to a depth recommended by a geotechnical engineer. A crushed aggregate greater than 3 in, but smaller than 6 in. should be used. Designate combination or single purpose entrances and exits to the construction site. Require that all employees, subcontractors, and suppliers utilize the stabilized construction access. Implement street sweeping and vacuuming, as needed. All exit locations intended to he used for more than a two-week period should have stabilized construction entrance/exit BIt1Ps. Stabilized Construction Entrance/I:xi' BM!' t 11M.umen' ' of t .»,b11.'r,rr, c t+srlflreaur Ser VICt'S. brc Construction Storm IV'ater %'lanal-'ement Plan (own! Ct rl[Nr1, o Stabilized Construction Entrance/Exit Inspection and Maintenance Inspect and verify that activity—based BMPs are in place prior to the commencement of associated activities_ While activities associated with the BMPs are under way, inspect weekly during the rainy season and of two-week intervals in the non -rainy season to verify continued BMP implementation. Inspect local roads adjacent to the site daily. Sweep or vacuum to remove visible accumulated sediment. Remove aggregate, separate and dispose of sediment if construction entrance/exit is clogged with sediment_ Keep all temporary roadway ditches clear. Check for damage and repair as needed. Replace gravel material when surface voids are visible. Remove all sediment deposited on paved roadways within 24 hours. Remove gravel and filter fabric at completion of construction Costs Average annual cost for installation and maintenance may vary from $1,200 to $4,800 each, averaging $2,400 per entrance. Costs will increase with addition of washing rack, and sediment trap. With wash rack, costs range from $1,200 - $6,000 each, averaging $3,600 per entrance. References Manual of Standards of Erosion and Sediment Control Measures, Association of Bay Area Governments, May 1995. National Management Measures to Control Nonpoint Source Pollution from Urban Areas, USEPA Agency, 2002. Proposed Guidance Specifying Management Measures for Sources of Nonpoint Pollution in Coastal Waters, Work Group Working Paper, USEPA, April 1992. Stormwater Quality Handbooks Construction Site Best Management Practices (BMPs) Manual, State of California Department of Transportation (Caltrans), November 2000. Stormwater Management of the Puget Sound Basin, Technical Manual, Publication #91-75, Washington State Department of Ecology, February 1992. Virginia Erosion and Sedimentation Control Handbook, Virginia Department of Conservation and Recreation, Division of Soil and Water Conservation, 1991, Guidance Specifying Management Measures for Nonpoint Pollution in Coastal Waters, EPA 840-B- 9-002, USEPA, Office of Water, Washington, DC, 1993. Water Quality Management Plan for the Lake Tahoe Region, Volume 11. Handbook of Nlanagement Practices, Tahoe Regional Planning Agency, November 1988. California Storm Water Quality Association, California Storni Water 13MP l-1andhook -- Construction, January 2003. Stabilized Construction ITalrun, a t•xit llN.113 Document Construction Storm Water 111; n;Tenat•rni Plan 3 ort 1'rrrritlferun f 'rnnlslirnra r Si. -t rre . f.14.01 l.lrn+4 ruin. 1 0lerraxlr) Stabilized Construction Entrance/Exit Crushed aggregate greater than 3" but smaller than 6" Filter €obrir. (3I0t-^7.)(—/t)p 41111111.1. 9 )?l L t? ,. Min, unless otherwise specified by a sons engineer SECTION B—B NTS Original grade N0f : Construct sediment barrier and channelize runoff to sediment trapping device • • I • C� • �� •� ; r:.' -+CJS'•• I• %• .• • ••A • •. •• re•C r44 • rI•• P • • ode'.�%`o �y/(�jC��J1ro • a 1 C:n"p(1r'1r Ver StahiIP/LLI (+mSPW iirm Entrance 1;7,m t l\1P i)oLEIn1u rII -t rel ('onsIrueliull 4l1.1131 ‘Vater hv1aiLigemeu! l'tarr r !I!-. lf ,_.rr +-•��� ' • :! •o 1 Width as recurred to accomodate an t'c ipat ed :mat€ic ( "nrdrlli•rurr (ornplia:nct• Ser•rices. lrra Glytrnd drr!1t 71077, {, r7la)7'altlrr Stabilized Construction Entrance/Exit Crushed aggregate greater than _ but smaller than 6 Filter fabric. fl Q11:0] r 12+' Min, ,Jnless otner wise specified by a soils engineer SECTION B -B NTS - Original grade Crushed aggregate greater than 3" but smaller than 6'. Corrugated steel Min, unless otherwise specified by a soils engineer SECTION A -A NOT TO SCALE NOTE: Construct sediment barrier and channeiize runoff to sediment trapping device w I :I -{ Original grade Filter fabric Sediment trapping device pane is —Corr,,gated steel parte s A - B .+yir.—. . .; 7(.1. -rt.) ar CI's ef.':4l14E'2 1 '1r+. is .:t:I ct1 '-t,:il'ili/ed Construction Entrance E-vit lill.1 I' Document S „r - Cordillera,' (.1 impliam e° SePTle'e'1- c,nsIrtletion Storm Water Management Plan Grand Olt 1,017. Colorado Stabilized Construction Roadway, Description and Purpose Access roads, subdivision roads, parking areas, and other onsite vehicle transportation routes should be stabilized immediately after grading, and frequently maintained to prevent erosion and control dust. Targeted Constituents - Sediment - Nutrients - Trash Metals - Bacteria - Oil and Grease - Organics Suitable Applications This BMP should be applied for the following conditions: Temporary Construction Traffic: - Phased construction projects and offsite road - Construction during wet weather Construction roadways and detour roads: - Where mud tracking is a problem during wet Where dust is a problem during dry weather - Adjacent to water bodies - Where poor soils are encountered Potential Alternatives None access weather Limitations The roadway must be removed or paved when construction is complete. Certain chemical stabilization methods may cause storm water or soil pollution and should not be used. S;tabilired Construction Roadway 10,11' Document construction Storni water Management Plan of 3 /A./ ur f .rmrplydruer Solid r , !uc• (ivernilJunction, ('oloraclr+ Stabilized Construction Roadway Management of construction traffic is subject to air quality control measures. Contact the local air quality management agency. Materials will likely need to be removed prior to final project grading and stabilization. Use of this BMP may not be applicable to very short duration projects. Implementation General Areas that are graded for construction vehicle transport and parking purposes are especially susceptible to erosion and dust. The exposed soil surface is continually disturbed, leaving no opportunity for vegetative stabilization. Such areas also tend to collect and transport runoff waters along their surfaces. During wet weather, they often become muddy quagmires that generate significant quantities of sediment that may pollute nearby streams or be transported offsite on the wheels of construction vehicles. Dirt roads can become so unstable during wet weather that they are virtually unusable. Efficient construction road stabilization not only reduces onsite erosion but also can significantly speed onsite work, avoid instances of immobilized machinery and delivery vehicles, and generally improve site efficiency and working conditions during adverse weather Installation/Application Criteria Permanent roads and parking areas should be paved as soon as possible after grading. As an alternative where construction will be phased, the early application of gravel or chemical stabilization. may solve potential erosion and stability problems. Temporary gravel roadway should be considered during the rainy season and on slopes greater than 5%. Temporary roads should follow the contour of the natural terrain to the maximum extent possible. Slope should not exceed 15%. Roadways should be carefully graded to drain transversely. Provide drainage swales on each side of the roadway in the case of a crowned section or one side in the case ofa super elevated section. Simple gravel berms without a trench can also be used. Installed inlets should be protected to prevent sediment laden water from entering the storm sewer system. In addition, the following criteria should be considered. Road should follow topographic contours to reduce erosion of the roadway. The roadway slope should not exceed 1 5%. Chemical stabilizers or water are usually required on gravel or dirt roads to prevent dust Properly grade roadway to prevent runoff from leaving the construction site. Design stabilized access to support heaviest vehicles and equipment that will use it. Stabilize roadway using aggregate, asphalt concrete, or concrete based on longevity, required performance, and site conditions. The use of cold mix asphalt or asphalt concrete (AC) grindings for stabilized construction roadway is not allowed. Coordinate materials with those used for stabilized construction entrance/exit points. If aggregate is selected. place crushed aggregate over geotextile fabric to at least 12 in. depth. A crushed aggregate greater than 3 in. but smaller than 6 in. should be used. Slabiliz d ('«nslruclion Roadway ay I M1' Ducunteni C'onslnkliun Slur n Water Maina cincn1 Plan 2 of 3 ('r i,lille+rr+r ('nml /nut, +, tiev r+„,,., f++,. t irunxl Am( +Yr+++, (filo+uil„ Stabilized Construction Roadway Inspection and Maintenance Inspect and verify that activity -based BMPs are in place prior to the commencement of associated activities. While activities associated with the BMP are under way, impact weekly during the rainy season and of two-week intervals in the non -rainy season to verify continued BMP implementation. Keep all temporary roadway ditches clear, When no longer required, remove stabilized construction roadway and re -grade and repair slopes. Periodically apply additional aggregate on gravel roads. Active dirt construction roads are commonly watered three or more times per day during the dry season. Costs Gravel construction roads are moderately expensive, but cost is often balanced by reductions in construction delay. No additional costs for dust control on construction roads should be required above that needed to meet local air quality requirements. References Blueprint for a Clean Bay: Best Management Practices to Prevent Stormwater Pollution from Construction Related Activities; Santa Clara Valley Nonpoint Source Pollution Control. Program, 1995. Coastal Nonpoint. Pollution Control Program; Program Development and. Approval Guidance, Working Group, Working Paper; USEPA, April 1992. Manual of Standards of Erosion and Sediment Control Measures, Association of Bay Area Governments, May 1995. Storrnwater Quality Handbooks Construction Site Best Management Practices (BMPs) Manual, State of California Department of Transportation (Caltrans), November 2000. Stormwater Management for Construction Activities, Developing Pollution Prevention Plans and Best Management Practices, EPA 832-R-92005; USEPA, April 1992. Stormwater Management of the Puget Sound Basin, Technical Manual, Publication #91-75, Washington State Department of Ecology, February 1992. Virginia Erosion and Sedimentation Control Handbook, Virginia Department of Conservation and Recreation, Division of Soil and Water Conservation, 1991. Water Quality Management Plan for the Lake Tahoe Region, Volume 11, Handbook of Management Practices, Tahoe Regional Planning Agency, November 1988. California Storni Water Quality Association, California Storni Water BMP 'Handbook - Construction, January 2003. Stabilizer! Construction Ruadwav Rr1lP t)ururnctrt of ; C or•dif/e,on Compliance Services, hie Construction Slorru Water Management Nan ii,YlrlJJUraa'rl[au, ('010011ein Entrance/Outlet Tire Wash Description and Purpose A tire wash is an area located at stabilized construction access points to remove sediment from tires and under carriages and to prevent sediment from being transported onto public roadways. Targeted Constituents - Sediment - Nutrients - Trash - Metals Bacteria - Oil and Grease Organics Potential Alternatives Stabilized Construction Entrance/Exit Suitable Applications Tire washes may be used on construction sites where dirt and mud tracking onto public roads by construction vehicles may occur. Limitations The tire wash requires a supply of wash water. A turnout or doublewide exit is required to avoid having entering vehicles drive through the wash area. Do not use where wet tire trucks leaving the site leave the road dangerously slick. Implementation Incorporate with a stabilized construction entrance/exit. Construct on level ground when possible, on a pad of coarse aggregate greater than 3 in. but smaller than 6 in. A geotextile fabric should be placed below the aggregate. Wash rack should be designed and constructed/manufactured for anticipated traffic loads. I miance t )rftl t Tire Wash Mit' Document Construction Storni Water Management Plan 1 of ? C cirrlrlh ron l iurajrlurrrr r Ae^r}•rres, hal firrrrrel.loof turn. Colorful() Entrance/Outlet Tire Wash Provide a drainage ditch that will convey the runoff from the wash area to a sediment trapping device. The drainage ditch should be of sufficient grade, width, and depth to carry the wash runoff. Use hoses with automatic shutoff nozzles to prevent hoses from being left on. Require that all employees, subcontractors, and others that leave the site with mud caked tires and undercarriages to use the wash facility. Costs Costs are low for installation of wash rack_ Inspection and Maintenance Inspect and verify that activity -based BMPs are in place prior to the commencement of associated activities. While activities associated with the BMP are under way, inspect weekly during the rainy season and of two-week intervals in the non -rainy season to verify continued BMP implementation. Inspect BMPs subject to non-stormwater discharge daily while non-stormwater discharges occur. Remove accumulated sediment in wash rack and/or sediment trap to maintain system performance_ Inspect routinely for damage and repair as needed. References Blueprint for a Clean Bay: Best Management Practices to Prevent Stormwater Pollution from Construction Related Activities; Santa Clara Valley Nonpoint Source Pollution Control Program, 1995. Coastal Nonpoint Pollution Control Program; Program Development and Approval Guidance, Working Group, Working Paper; USEPA, April 1992. Manual of Standards of Erosion and Sediment Control Measures, Association of Bay Area Governments, May 1995. Stormwater Quality Handbooks Construction Site Best Managernent Practices (BMPs) Manual, State of California Department of Transportation (Caltrans;, November 2000. Stonnwatcr Management for Constriction Activities, Developing Pollution Prevention Plans and Best Management Practices, EPA 832-R-92005; USEPA, April 1992. California Storm Water Quality Association, California Storm Water BMP Handbook - Construction, January 2003. Fntrance { hitict Tire Wash I;MI' Document Construction Storm Water Management flan 2 of Wenn: Compliance pliance Serr:ces. Inc. GruHcl.unction, Cnloruclr, Entrance/Outlet Tire Wash Crushed aggregate greater than 3" but smaller than 6". Corrugated steel panels 1.'" in, unless otherwise specified by a soils engineer SECTION A -A NOT TO SCALE Original grade Filter fabric Crushed aggregate greater than 3" but smaller than 6" Filter fabric Original 00�► grade 11111116 "a, 12" Min, unless otherwise specified by a soils engineer SECTION B -a' N T S DRch to curry runoff — to a sediment trapping device • I;It al 1 1,I ,i 1 1--r Entrancc( hrllei tire Wash 13h11' I)(e(tlI]1�'I11 ('onstrue:lrrrn Storrs \\ alcr hdarurt 4ni�nl f'I:sre t+l; e,Sen.:ce's, bre:. (+e'ee ii.h eeeverrar, ('r)lcwclre • C0RDI LLERAN December 1, 2005 826217,2 Road Grand Junction, CO 81505 T:970.263.7800 F: 970.263.7456 Mr. Mark Bean Garfield County Building & Planning Department 309 Eighth Street, Suite 303 Glenwood Springs, Colorado 81601 Re: Parachute Creek Gas Plant Spill Prevention Control and Countermeasure Plan Requirements Dear Mr. Bean: This letter serves as recognition that the Parachute Creek Gas Plant (Plant), owned and operated by Williams Production RMT Company (Williams). is currently subject to Spill Prevention Control and Countermeasure (SPCC) Plan requirements as outlined in the Clean Water Act of the United States Environmental Protection Agency (EPA). Additionally, future operations in the Phase 3 area of the facility will be subject to SPCC requirements. The entire Plant, when completed and in full operation, will store "oil" (as defined by the EPA) in quantities sufficient to require SPCC compliance. The SPCC regulations are in place in order to minimize the risk of "oil" contamination to navigable waters and other environmental receptors„ Williams currently complies with existing SPCC requirements as required by the EPA. l oward this end, Williams has contracted Cordilleras Compliance Services, Inc_ (Cordilleran) to regularly evaluate, and revise as needed, the SPCC Plan for the Plant. Upon completion of construction and installation of the "oil" storage and containment structures in the Phase 3 area of the Plant, Cordilleran will promptly inspect these structures, the facility, and the surrounding area for compliance. Based upon this inspection and review of Plant operating procedures, Cordilleran will, using sound engineering judgment, revise the existing SPCC Plan describing best management practices designed to minimize the risk of "oil" spills and releases from occurring at the Plant. Additionally, the SPCC Plan will certify that the containment structures at the plant meet SPCC guidelines. Should you have any questions or concerns, please contact me at (970) 263-7800. Sincerely, Cordillera: Compliance Services, Inc.. Dion Plsek, P,E. Principal Engineer Cordflleran Compliance Services, Inc. Grand junction, CO • Denver, CO • Casper, WY • Laramie, WY • Lander, WY • Sheridan, WY Environmental Consulting Engineers and Scientists • • SPILL PREVENTION CONTROL AND COUNTERMEASURE PLAN PARACHUTE CREEK GAS PLANT PHASE 1 PLANT AREA PHASE 2 PLANT AREA GARFIELD COUNTY, COLORADO PREPARED FOR: WILLIAMS PRODUCTION RMT COMPANY P.O. Box 370 Parachute, Colorado 81635 PREPARED BY: CORDILLERAN COMPLIANCE SERVICES, INC. 826 21'/ Road Grand .function, Colorado 81505 970.263.7800 CORDILLERAN REVISION DATE: November 2005 • • TABLE OF CONTENTS Section Page No. SECTION 1.0 MANAGEMENT COMMITMENT CERTIFICATION 1 SECTION 2.0 ENGINEERING CERTIFICATION 2 SECTION 3.0 INTRODUCTION .. 3 SECTION 4.0 GENERAL APPLICABILITY 4 SECTION 5.0 SPCC PLAN ADMINISTRATION: §112.3, §112.4, AND §112.5 5 5.1 Requirement to Prepare: §112.3 5 5.2 Amendment by Regional Administrator: §112.4 5 5.3 SPCC Plan Amendment by Owner/Operator: §112.5 .6 SECTION 6M SPCC PLAN GENERAL REQUIREMENTS §112.7 7 6.1 General Facility Information ............................... 7 6.2 General Facility Description 8 6.3 SPCC Plan Conformance and Deviations: §112.7( (1) and (2) 9 6.4 Facility Layout: §112.7(a)(3) 9 6.5 Oil Storage Capacity: § 112,7(a)(3)(i) 9 6.6 Discharge Prevention Measures: §1 12.7(a)(3)(ii) I 1 6.7 Discharge Drainage Controls: §112.7(a)(3)(iii) 11 6.8 Countermeasures for Discharge Discovery, Response and Cleanup: § 112-7(a)(3)(iv) 11 6.9 Recovered Materials Disposal: §112.7(a)(3)(v) 12 6.10 Contact List and Notification Phone Numbers: §1.12.7(a)(3)(vi) 12 6.11 Reporting and Notification Procedures: §112.7(a)(4) .12 6.12 Oil Spill Response Procedures: §112.7(a)(5) ....,_.12 613 Discharge Analysis: §112.7(b) 12 6.14 SpilI Containment: §112.7(c) 14 6.15 Spill Containment Practicability: § 112.7(d) ..._._--.., 14 6.16 Inspections, Tests and Records: §112.7(e) 14 6.17 Personnel Training and Discharge Prevention Measures: § 112.7(f) 15 6.18 Security: §112.7(g) 15 6.19 Facility Tank Car and Tank Truck Loading/Unloading: §I 12.7(h) 16 6.20 Brittle Fracture Analysis: §1 I2.7(1) 16 6.21 Applicable Requirements: §112.7(j) 16 SECTION 7.0 REQUIREMENTS FOR ONSHORE (NON -PRODUCTION) FACILITIES: §l 12.8 17 SECTION 8.0 REQUIREMENTS FOR ONSHORE OIL PRODUCTION FACILITIES: §112.9 I8 8.1 011 Production Facility Drainage: §112.9(h) ................ 18 8.2 Oil Production Facility Bulk Storage Containers: § 112.9(c) 18 8.3 Facility Transfer Operations, Oil Production Facility: § 112.9(d) 19 SECTION 9.0 REQUIREMENTS FOR ONSHORE OIL DRILLING AND WORKOVER FACILITIES: §112.10 20 SECTION 10.0 REQUIREMENTS FOR OFFSHORE OIL DRILLING, PRODUCTION AND WORKOVER FACILITIES: §l 12.11 20 • • TABLE OF CONTENTS (Continued) FIGURES Figure 1 — Parachute Creek Gas Plant Location Map Figure 2 — Parachute Creek Gas Plant Site Map — Phase 1 Figure 3 — Parachute Creek Gas Plant Site Map — Phase 2 APPENDICES Appendix A — Certification of the Applicability of the Substantial Harm Criteria Appendix B — SPCC Plan ReviewfAmendment Documentation Appendix C — Oil Spill Response Procedures (Including Notification Phone Numbers Appendix D — Secondary Containment Information Appendix E — Inspection Procedures and Records Appendix F — Training Procedures and Records Appendix G — SPCC Regulations (40 CFR 110 and 40 CFR 112) • SECTION 1.0 MANAGEMENT COMMITMENT CERTIFICATION Management approval has been extended at a level with authority to commit the necessary resources to implement this Spill Prevention, Control and Countermeasure (SPCC) plan. Pursuant to §112.7(d), this is the written commitment of Williams Production RMT Company (Williams) to provide the manpower, equipment and materials required to expeditiously control and remove any quantity of oil discharged that may be harmful to human health and the environment. A copy of this plan shall be maintained by the operator as described herein and will be made available to the EPA Regional Administrator for on-site review during normal working hours. Authorized Management Representative: Signature: Name: Steve Soychak Title: District Manager Date: SECTION 2.0 ENGINEERING CERTIFICATION Pursuant to §112.3(d) and by means of this certification, 1 attest that: - 1 am familiar with the requirements of the SPCC rule (40 CFR 112); The facility has been visited and examined by myself or my agent; - This plan has been prepared in accordance with good engineering practice, including consideration of applicable industry standards, and with the requirements of the SPCC rule; Procedures for required inspections and testing have been established; and, - This plan is adequate for the facility. mature of Professional Engineer State Registration No. Date State Note: The PE's certification does not relieve the owner/operator of the facility of the duty of fully implementing the SPCC plan in accordance with all applicable requirements. • • • SECTION 3.0 INTRODUCTION The Federal Water Pollution Control Act, as amended by the Clean Water Act of 1977, authorized the establishment of procedures, methods, equipment and other requirements for the prevention and/or containment of discharges of oil and hazardous substances from vessels and onshore and offshore facilities. In partial response to this authorization, the U.S. Environmental Protection Agency (USEPA) issued Oil Pollution Prevention Regulations for Non -Transportation Related Onshore and Offshore Facilities on December 11, 1973 (effective on January 10, 1974). These regulations were published under title 40 of the Code of Federal Regulations (CFR), Part 112 and specifically outlined requirements for the preparation of Spill Prevention, Control and Countermeasure (SPCC) plans. On July 17, 2002 the USEPA published modifications to the SPCC requirements in the Federal Register (68 FR, 4704247152)_ This SPCC plan has been prepared in accordance with these revised regulations. The following sections of this plan are presented in the sequence of the SPCC rule, as required by the rule. The substantive requirements 01 12.7 and § 112.9) are addressed in Sections 6 and 8, respectively. Throughout this plan, where applicable, references to the appropriate subsections of 40 CFR Part 112 are provided, followed by an explanation of how the requirements have been addressed. SECTION 4.0 GENERAL APPLICABILITY The Oil Pollution Prevention Regulations (40 CFR Part 112) require preparation of an SPCC plan for facilities that have discharged or could reasonably be expected to discharge oil into or upon navigable waters of the United States or adjoining shorelines. Specifically, §112.1(d)(2)(ii) requires an SPCC plan to be developed for facilities where the aggregate storage capacity of oil is greater than 1,320 gallons (inclusive of containers with thresholds of 55 -gallons or greater). Because the Parachute Creek Gas Plant near Parachute, Colorado has a collective potential maximum above ground storage capacity of approximately 47,590 gallons, as well as individual stored volumes up to 12,600 gallons each, Williams is required to develop, implement and maintain an SPCC plan for this facility. This SPCC plan has been developed for the Parachute Creek Gas Plant in response to the regulations listed above. The purpose of this plan is to identify sources of oil at the Parachute Creek Gas Plant and outline procedures to prevent the release of oil to navigable waters of the United States. A release of oil is considered a discharge under this plan only if the release is into or upon the navigable waters of the United States, adjoining shorelines, or waters contiguous with the navigable waters of the United States. This is apparent if a release impacts surface water quality by causing a film, sheen or discoloration of the water surface or adjoining shorelines, or causes a sludge or emulsion to be deposited beneath the surface of the adjoining shorelines. Impacts to groundwater also apply if the groundwater is contiguous with navigable waters of the United States (i.e., groundwater discharges to/contributes to the total volume of a surface water body that is itself contiguous with navigable waters of the United States). Any facility that could, because of its location, be expected to cause substantial harm to the environment by discharging oil into or on navigable waters or adjoining shorelines is required to prepare and submit a facility response plan (FRP) to the USEPA Regional Administrator (RA) in accordance with 40 CFR Part 112.20. The Parachute Creek Gas Plant is not considered such a facility because it does not meet any of the substantial harm criteria specified in §112.20. These criteria, and the associated applicability determination regarding the Parachute Creek Gas Plant, are shown in ,-Appendix A. This appendix is the Certification of the Applicability of the Substantial Harm Criteria required by §112.20 and must be maintained at the facility. Because submittal of an FRP is not required, except at the discretion of the RA, this SPCC plan provides information and procedures for responding to discharges. SECTION 5.0 SPCC PLAN ADMINISTRATION: §1123, §112.4, AND §112.5 5.1 Requirement to Prepare: §112.3 This SPCC plan was prepared to comply with the SPCC rule (40 CFR Part 112) that was amended and promulgated on July 17, 2002. In accordance with §112.3(a) and the compliance timeline extension announced by the EPA on August 5, 2004, this plan was completed prior to February 16, 2006 and will be fully implemented prior to August 18, 2006. In accordance with §112.3(e)(1) and (2), a complete updated copy of the SPCC Plan and associated files will be maintained at the plant site, and at the Williams district office in Parachute, Colorado. .During normal working hours at the facility, the plan will be available to authorized representatives of Local, State or Federal governing agencies for on-site review and a copy will be submitted to the EPA if requested. 5.2 Amendment by Regional Administrator: §112.4 In accordance with §112.4(a), whenever more than 1,000 -gallons of oil have been discharged in a single incident or more than 42 -gallons of oil have been discharged in each of two incidents over a 12 -month period, Williams will submit a report to the EPA RA within 60 days (refer to the definition of a discharge previously provided in Section 4). The report must include the following: • §112.4(a)(1): Name of the facility; • §112.4(a)(2): Name of the operator;. • §112.4(a)(3): Location of the facility; • §112.4(a)(4): Maximum storage or handling capacity of the facility and the normal daily throughput; • §112.4(a)(5): Corrective action and countermeasures that have been taken, including a description of equipment repairs and replacements; • §112.4(a)(6): An adequate description of the facility, including maps, flow diagrams, and topographical maps, as necessary; • §112.4(a)(7): 'The cause of such discharge as described in 40 CFR 1 12. t (b), including a failure analysis of the system or subsystem in which the firilure occurred: • • • • • § 112.4(a)(8): Additional preventive measures taken or planned to minimize the possibility of recurrence; and • §112.4(a)(9): Such other information as the Regional Administrator may reasonably require pertinent to the SPCC Plan or discharge. In accordance with 40 CFR 112.4(c), copies of the incident report will also be forwarded to the representative/case manager designated by the appropriate local or tribal agency. Should the RA subsequently propose by certified mail or personal delivery that this SPCC plan be amended, in accordance with §112.4(e) Williams will: • Submit arguments and supporting information in response to the proposed amendments within 30 days; or • Amend this SPCC plan within 30 days and implement the amended plan within six months, unless otherwise authorized by the RA. As required by §112.4(c), technical amendments to the plan will be certified by a Professional Engineer. 5.3 SPCC Plan Amendment by Owner/Operator: §112.5 In accordance with § 112.5(a), when there is a change in facility design, construction, operation, or maintenance that materially affects the facility's potential for a discharge, Williams will amend this SPCC plan within six months of the change and implement the amended plan within six months of its completion. In accordance with § 112.5(b), Williams will also review this plan at least once every five years from the date of the last review. As a result of the review, the plan will be amended within six months of the review if more effective prevention and control technology has been field -proven at the time of the review and will significantly reduce the likelihood of a discharge. The amended plan will be implemented within six months of its completion. The designated person accountable for oil spill prevention at the facility (the Principal Environmental Specialist, see Section 6.1) will document completion of each five year review, sign a statement as to whether the plan will be amended, and record the results in Appendix K. As required by §1 12_5(c), technical amendments to the plan will be certified by a Professional Engineer. Any such amendments to this SPCC plan shall be noted on the Amendment Log included in Appendix 13 of this SPCC plan. Entries into the log will indicate a general description of the changes that were made to the facility, the corresponding changes that were made to the SPCC plan, including plan section and page numbers, and the name and signature of i Iae person making the changes. A new certification page will be signed, scaled and inserted into chis plan to complete the amendment process. SECTION 6.0 SPCC PLAN GENERAL REQUIREMENTS: §11.2.7 This section presents facility -specific details associated with the general requirements for SPCC plans outlined in §112.7. As previously indicated in Sections 1,2 and 3, this SPCC plan has been prepared in accordance with good engineering practice, with management approval at a level with authority to commit the necessary resources for full implementation, and in the sequence of the rule. 6.1 General Facility Information Name and type of facility: The Parachute Creek Gas Plant is a natural gas processing and compression facility, owned and operated by Williams Production RMT Company. The Parachute Creek Gas Plant is considered a production facility, as it is upstream of associated custody transfer points to transportation -related systems. Location of facility: The Parachute Creek Gas Plant is located in the northeast quarter of the northeast quarter of Section 33 in Township 6 South, Range 96 West in Garfield County, Colorado. See Figure 1 for additional site location information. The town of Parachute, Colorado, which lies approximately 4 miles west southeast of the facility, is the nearest population center. Owner name and address: Williams Production RMT Company 1515 Arapahoe, Tower 3, Suite 1000 Denver, Colorado 80202 (303) 573-3901) Designated personnel accountable for spill prevention: Regional/District Contact Mr. Steve Soychak District Manager Williams Production RMT Co. P.O. Box 370 Parachute, Colorado 81635 (970) 285-9377 office (970) 216-0922 mobile 7 Facility Contact Mr_ Eric Miller Plant Manager Williams Production RMT Co. 4289 County Road 215 Parachute, Colorado 81635 (970) 285-9377 office (970) 270-2813 mobile • • Has the facility experienced a reportable oil spill (discharge) event during the past I2 months? No, the facility has not experienced a reportable oil spill event during the 12 months preceding the certification date of this SPCC plan. 6.2 General Facility Description The Parachute Creek Gas Plant is a natural gas processing and compression facility, owned and operated by Williams Production RMT Company. The facility is located in western Colorado, in Garfield County, on private property. The area surrounding the facility is considered multiple - use land and area activities include oil and gas exploration and production. The location of the plant is depicted on Figure 1. Details of the facility and oil storage areas at the facility are shown on Figures 2 and 3. According to U.S. Geological Survey topographic mapping sources (Parachute, Colorado quadrangle), the site lies at an approximate elevations of 5,410 feet above mean sea level, with shallow relief in the immediate vicinity of the site. Information from the United States Department of Agriculture Natural Resources Conservation Service (USDA NRCS) indicates the soils in the area of the Parachute Creek Gas Plant are of the Arvada-Torrifluents-Heldt complex, which is described as follows. These soils are deep, well drained to somewhat poorly drained, nearly level to gently sloping soils on benches, terraces, alluvial fans, and flood plains. Arvada soils are on benches, terraces and fans. They are deep, well drained, and alkali affected. The surface layer is loam, the subsurface is strongly alkaline silty clay loam, and the substratum is silty clay loam. Torruvents are on flood plains and low terraces. They are deep and well drained to somewhat well poorly drained. They are sandy loam or loam stratified with sand, gravel, or cobbles. Heidi soils are on alluvial fans. They are deep and well drained. The surface and subsoil are clary loam, and the substratum is clay. Parachute Creek, a perennial stream, is located approximately 750 feet southwest and down gradient of the Parachute Creek Gas Plant. Parachute Creek flows southeast to its confluence with the Colorado River, approximately 18 miles southeast of the site. There is also an irrigation drainage ditch, which flows intermittently, approximately 150 feet north and up gradient of the site. All existing drainages in the vicinity of the facility discharge to Parachute. Creek. Drainage within the site boundary is governed by surface topography. Downhill slope direction arrows on Figures 2 and 3 indicate the predicted general direction of storm water flow to the south and West. • • • The facility consists of metering equipment, dehydration, separation, and processing equipment, above ground storage tanks, and piping systems. Products related to the maintenance and operation of the facility are stored in above ground storage tanks. Natural gas liquids are occasionally taken from the facility via tank truck. The facility operates 24 hours per day and is continuously manned by operations personnel. An inventory of all storage tanks at the facility is provided in Section 6.5. Williams has determined that specific liquids stored at the facility are considered oils for the purpose of this SPCC plan. The plant is considered a production facility and is hence subject to the specific SPCC requirements of 40 CFR §112.9 for onshore production facilities. 63 SPCC Plan Conformance and Deviations: §112.7(a)(1) and (2) This SPCC plan conforms with and does not deviate from the applicable requirements of CFR 40 §H 2.7, as detailed in the subsequent sections of this SPCC plan. The Parachute Creek Gas Plant is an onshore production facility and is therefore subject to §112.9. 6.4 Facility Layout: §112.7(a)(3) Oil storage areas at the facility are identified on Figures 2 and 3. There are no completely buried or bunkered tanks at the facility, or buried pipelines related to the handling of oil as defined by §112.2 of the SPCC regulations, other than lines leading from the separation equipment to storage tanks. Aboveground storage containers and oil -filled equipment applicable to this plan are listed below in Section 6.5 6.5 Oil Storage Capacity: §112.7(a)(3)(i) A summary of the substance, containers and container capacities applicable to this plan is provided in the following table. Although oil -filled equipment are not considered containers as defined by §112.2, the preamble of the SPCC rule (67 FR, 47054-47055) indicates that applicability criteria such as oil storage capacity and potential for a discharge still pertain and the prevention of discharges from such equipment still falls within the scope of the SPCC rule. Consequently, the type of oil and capacity of the oil -filled equipment at the Parachute Creek Gas Plant are included in the summary. SPCC -Regulated Storage Containers and Oil -Containing Equipment PHASE I Stored Material Type of Container/Equipment Reference ID (See Figure 2) Storage Capacity (Gallons) Lubricating Oil Above ground storage tank 1 500 Used Oil Above ground storage tank 3 3,360 Condensate Above ground storage tank 6 12,600 Condensate Above ground storage tank 7 12,600 Combustor Skid Drain Above ground storage tank 14 4,200 Combustor Skid Drain Partially buried storage lank 15 3,360 Lubricating Oil Above ground storage tank 16 500 Lubricating Oil Above ground storage tank I7 30 Hot Oil Tank Above ground storage tank 20 2940 Lubricating Oil Above ground storage tank 23 1,000 Lubricating Oil Above ground storage tank 24 1,000 Lubricating Oil Above ground storage tank _ 26 500 Lubricating Oil Above ground storage lank 28 500 Lubricating Oil Above ground storage lank 29 500 Unleaded Gasoline Above ground storage tank 31 500 Off -Road Diesel Above ground storage tank 32 500 Dyed Diesel Above ground storage tank 33 500 Sump Tank Buried storage tank _ 34 500 , Phase 1 Storage Capacity 45,590 PHASE 2 Stored Material Type of Container/Equipment Reference ID (See Figure 3) Storage C'ap;uity (Gallons) Lubricating Oil Above ground storage tank 4 500 Lubricating Oil Above ground storage tank 5 500 Lubricating Oil Above ground storage tank 6 500 Lubricating Oil Above ground storage tank 7 500 Phase 2 Storage Capacity _ 2,000 Plant Overall Storage Capacity 47,590 • • 6.6 Discharge Prevention Measures: §112.7(a)(3)(ii) The Parachute Creek Gas Plant relies on a number of measures to aide in the prevention of a discharge. Descriptions of these measures are provided below. • Routine maintenance of any oil -containing equipment is performed by trained personnel at the location of the equipment utilizing soaker pads and the available secondary containment structures and/or drip pans as warranted. • Each storage tank or vessel has a system in place that has been designed and installed in accordance with good engineering practice to prevent discharges. These features may include: adequate containment volume to avoid overfill during normal operations, and; high level sensors and controls to stop liquid flow. All discharge features are inspected at regular intervals. 6.7 Discharge or Drainage Controls: §112.7(a)(3)(iii) The products stored at the Parachute Creek Gas Plant (natural gas liquids, produced water, and lubricating oil) are noncorrosive materials and are compatible with the materials with which the storage containers and containment structures at the facility are constructed. The containment structures at the facility are designed to provide adequate protection against the discharge of oil.. Secondary containment is provided for the atmospheric aboveground storage tanks. Secondary containment details are provided in Sections 6.14 and 6.19. Containment capacity calculations and/or specifications are provided in Appendix D. Each secondary containment system, including the walls and floor of the respective system, is capable of containing oil and has been constructed so that any discharge from a primary containment system (such as a tank or pipe) wiIl not permeate, drain, infiltrate, or otherwise escape before cleanup occurs. 6.8 Countermeasures for Discharge Discovery, Response and Cleanup: §112.7(a)(3)(iv) As part of routine facility procedures, visual exterior inspections of the oil storage containers and equipment are made several tinges per week, at a minimum, for signs of deterioration or Teaks. Deficiencies noted from these examinations are entered on a check sheet and corrected in a timely manner. Inspection check sheets are kept in a logbook in the plant office. In addition to the regular checks, the oil storage equipment is inspected every month according to the written procedures outlined in Section 6.16 of this plan In the event of a release, the facility has trained personnel and equipment available to contain and clean up minor volumes of oil. On-site equipment and materials include spill kits, shovels, and sorbent materials (booms, pads, etc.) that may be used to dike, contain and remove minor releases. II • In the event of a larger release, specific response procedures have been developed (See Appendix C). As part of these procedures, external resources (contractors) have been identified to assist facility personnel. To ensure the commitment of these external resources, Williams Production RMT Company maintains a service agreement with each selected contractor. A list of approved contractors is kept at the plant site and at the Williams district office in Parachute, Colorado. At a minimum, contractors identified to assist in a spill response will have the capabilities to provide emergency response, industrial power vacuuming, tank and pipeline cleaning, equipment decontamination, excavation/earthmoving and waste transportation and disposal services. 6.9 Recovered Materials Disposal: §112.7(a)(3)(v) Materials recovered during a spill event will be appropriately containerized or will be remediated on site in accordance with Colorado Oil and Gas Conservation Commission (COGCC) stipulations. Soils and other solids will be placed in 55 -gallon drums or roll -off containers, or in other approved containers as warranted. Liquids will be placed in 55 -gallon drums or will be collected in a tank truck using industrial power vacuuming. Recovered materials will be labeled, characterized and disposed/recycled in accordance with applicable federal, state and local regulations. 6.10 Contact List and Notification Phone Numbers: §112.7(a)(3)(vi) The contact list for oil spill response activities is provided in Appendix C, as part of the Oil Spill Response Procedures developed for the Parachute Creek Gas Plant. 6.11 Reporting and Notification Procedures: §1.12.7(a)(4) Reporting and notification requirements are outlined in the Oil Spill Response Procedures provided in Appendix C. 6.12 Oil Spill Response Procedures: §1 12.7(a)(5) Oil Spill Response Procedures for the Parachute Creek Gas Plant are provided in Appendix C. 6.13 Discharge Analysis: §112.7(h) Pursuant to §I 12.7(b), predictions of the direction, rate of flow, and total quantity of material that could be discharged at the facility. in the event of a breach or failure of the secondary containment structures, are summarized in the table below for oil storage containers or oil -filled equipnnent. • Notes: • Potential Spill Prediction and Control Source Primary Failure Mechanism Storage Capacity (Gallons) Discharge Flow Direction Required Containment Capacity" (Gallons) Current Containment Capacity' (Gallons) PHASE 1 Storage tank #1 Leakage, overfilling 500 South, east 566 756 Storage tank #3 ! Leakage, o,, erf illing 3.360 South, east 3,804 3,915 Storage tank #6 Leakage, overfilling 12.600 South, east 16,056 34,586 Storage tank #7 Leakage, overfilling, 12,600 South, east 16,056 34,586 Storage tank -14 Leakage, overfilling 4,200 South, east 4,760 756 Storage tank » 15 Leakage, overftll't g 3,360 South, east 3,804 - 9,682 Storage tank 416 Leakage. overfilling 500 South, east 566 9,682 Storage tank » 17 Leakage. overfilling 30 South, east 34 0 Storage tank #20 Leakage, overfilling 2,940 South, east 3,328 0 Storage tank #23 Leakage, overfilling 1,000 South, east 1,132 0 Storage tank a24 Leakage, overfilling 1,000 South, east 1,132 0 Storage tank g26 _ Leakage. overfilling 500 South, east 566 756 Storage tank =28 Leakage, overfilling 500 South. east 566 _ 2,095 Storage tank »29 ° Leakage, oveft-tiling 500 South, east 566 2,095 Storage tank #31 Leakage, overfilling 500 South, east 566 756 Storage tank #32 Leakage, overfilling 500 South, east 566 756 Storage tank =33 Leakage, overfilling 500 South, east 566 - 756 Storage tank #34 Leakage, overfilling UNK. South, east NA 10,436 PHASE 2 Storage tank Leakage, overfilling 500 South, east 566 756 Storage tank Leakage, overfilling 500 South, east 566 5,760 Storage tank Leakage, overfilling 500 South, east 566 5,760 Storage tank Leakage. overfilling 500 South, east 566 5,760 • 1. The indicated capacities are sufficient volumes required to contain the storage capacity of the largest vessel in the specific containment plus at least 2.1 inches of freeboard to accommodate precipitation associated with a 24-hour 25 -year storm event. (Source: NOAA Atlas 2) 2. Secondary containment deficiencies exist where the current containment capacity is listed as "0". • 6.14 Spill Containment: §112.7(c) Oil storage containers at the Parachute Creek Gas Plant are equipped with secondary containment as noted in this document. Although oil -filled equipment are not considered containers as defined by §112.2, the preamble of the SPCC rule indicates that the requirements of § 112.7(c) still apply. Spill containment at the facility is described below: • Secondary containment is typically provided for the lubricating oil, and condensate above ground storage tanks in the form of earthen dikes or steel -wall containers. Containment for the other oil -filled equipment and vessels and the loading area is provided as described below or in Section 6.19. • Containment structures are configured to contain the storage capacity of the largest tank within the containment area, plus at least 2.1 inches of freeboard to accommodate precipitation associated with a 24-hour 25 -year storm event (Source: U.S. Department of Commerce National Oceanic and. Atmospheric Administration Atlas 2, Volume 11).. The containment volume calculations associated with the secondary containment structures are presented in Appendix D. 6.15 Spill Containment Practicability: §112.7(d) No discussions related to practicability are warranted because this SPCC plan either does not deviate from the requirements of §§112.7(c), 112.7(h)(1), 112.8(c)(2), 1 l 2.8(c)(11), 112.9(c)(2), 112.10(c), 112.12(c)(2), and 112.14(c), or, where it does deviate, the deviations are not practicability -caused issues. 6.16 Inspections, Tests and Records: §112.7(e) Oil storage containers, oil -filled equipment and related containment structures at the Parachute Creek Gas Plant are visually examined several times per week, at a minimum, for signs of deterioration or leaks. These inspections are conducted as part of normal facility operations. Deficiencies noted from these examinations are entered on a check sheet and corrected in a timely manner. The equipment is also inspected every month according to the written procedure in Appendix E. Signed and dated records of all inspections and other pertinent information, such as spills, removal and disposal of spill contaminated materials, replacement or repair of equipment, and training are maintained for a minimum of 3 years. 14 • • • 6.17 Personnel Training and Discharge Prevention Measures: §112.7(f) Oil -handling personnel operating the facility are required to have training in the operation and maintenance of equipment to prevent the discharge of oil; discharge procedure protocols; applicable pollution control laws, rules, and regulations; general facility operations; and the contents of the facility SPCC plan. They are under the direct supervision of the Principal Environmental Specialist, who is responsible for e-stablishing performance and duty guidelines and is the designated person accountable for spill prevention at the facility. Regular safety meetings are held to discuss a variety of safety procedures and other pertinent job responsibility criteria. A written record of all training is maintained for 3 years. At a minimum, training is conducted annually and whenever new spill regulations are promulgated, existing operating systems are modified, personnel responsibilities change, or the SPCC plan is amended. In addition, regular safety meetings will be used as a forum to reinforce understanding of SPCC procedures as necessary. An outline of the topics to be covered during SPCC training is presented in Appendix F. Attendance rosters and other training records will be maintained in the main office at the facility for a period of no less than three years. 6.18 Security: §112.7(g) The Parachute Creek Gas Plant is a secure facility and is typically not subject to trespass or vandalism. The facility is fully fenced with lockable access gates. The facility is in operation and attended 24 hours per day. General security is controlled by operations personnel during regular duties. Flow valves are generally kept locked or sealed to preclude tampering. The lighting at the facility is adequate for nighttime operations and appropriate for this type of facility. When a pipe that has potential for re -use is not in service, or it is in a standby service for an extended period of time, any associated valves are kept closed and locked and lines are sealed appropriately and marked as to their tie-in connection. • • • 6.19 Facility Tank Car and Tank Truck Loading/Unloading: §112.7(h) The loading and unloading areas at the Parachute Creek Gas Plant are not currently equipped with containment systems designed and constructed to hold at least the maximum capacity of the largest anticipated delivery tank truck. This situation will be addressed prior to the compliance deadlines outlined in Section 5.0 Proper loading procedures will be followed and wheel chocks used by tank truck drivers to prevent vehicles from departing or moving before completed disconnection of flexible or fixed oil transfer lines. All tank truck drivers are required to comply with DOT regulations in 49 CFR. Part 177 and facility standard operating procedures. All drivers must be authorized and/or certified by Williams Production RMT Company. If available, Williams operations personnel will remain with any delivery truck during filling operations to monitor the transfer; inspect outlets, connections and valves on the delivery tank truck before and after oil -filling operations; and make adjustments as necessary. The driver or an operations personnel member visually inspects all tank trucks before leaving the loading/unloading areas. The lowermost drain and all outlets of transport vehicles shall be inspected and, if necessary, make certain that they are tightened, adjusted, or replaced to prevent liquid discharge while in transit. 6.20 Brittle Fracture Analysis: §112.7(1) The Parachute Creek Gas Plant has no field -constructed aboveground oil -storage containers that apply to this plan and therefore this section of the regulation is not applicable. 6.21 Applicable Requirements: §112.7(j) Sections 6 and 8 of this plan provide detailed discussions of conformance with the applicable requirements and other effective discharge prevention used at the facility. SECTION 7.0 REQUIREMENTS FOR ONSHORE (NON -PRODUCTION) FACILITIES: §112.8 The Parachute Creek Gas Plant is not an onshore non -production facility. Consequently, the provisions in §112.8 do not apply. 17 • • SECTION 8.0 REQUIREMENTS FOR ONSHORE OIL PRODUCTION FACILITIES: §112.9 8.1 Oil Production Facility Drainage: §112.9(b) Precipitation that may accumulate in any contained area is normally allowed to evaporate. No automatic pumps or ejector devices are present in any of the containment areas. If removal of any water accumulated in the containment areas is necessary, it will be conducted under the direct supervision of responsible personnel as described in this section. Accumulated precipitation is removed, when necessary, from secondary containment areas using a vacuum truck, pump, or other appropriate method. Removed water is disposed of in accordance with applicable local, state, and federal regulations. Prior to removal of the water from any containment area, the responsible personnel visually inspect the water in the containment structure and note the appearance of the water in the facility logs. The name of the person draining the containment, as well as the date, time, and approximate quantity of water removed will also be recorded in the facility logs and kept on file with the SPCC documents for a period of at least three years. A secondary containment drainage log is included in Appendix E. The drain systems at the Parachute Creek Gas Plant are of the `enclosed' type. All process effluents are routed through drain lines to storage tanks. No process effluents, untreated or treated, are released off-site. All field drainage systems (such as drainage ditches or road ditches) in the vicinity of the facility are inspected at regular intervals for the presence of accumulated oil that may have resulted from a small discharge. Any accumulated oil will be removed from these areas promptly upon discovery. 8.2 Oil Production Facility Sulk Storage Containers: §112.9(c) The products stored at the Parachute Creek Gas Plant are compatible with the materials with which the storage containers and containment structures at the facility are constructed. Secondary containment is provided for several of the atmospheric above ground storage tanks. Specific secondary containment details are presented in Sections 6.14 and 6.19. Oil storage containers at the Parachute Creek Gas Plant are equipped with secondary containment as noted in this document. Although oil -filled equiprnent are not considered containers as defined by §112.2. the preamble of the SPCC rule indicates that the requirements of §112.7(c) still apply. Spill containment at the facility is described in Section 6.14 and Appendix D. IK • • • Certain secondary containment structures at the facility are constructed with native soils or road construction -grade fill material. The composition of the native soil is considered sufficiently impervious to contain spilled oil until cleanup operations can commence. Oil storage containers, oil -filled equipment and related containment structures at the Parachute Creek Gas Plant are visually examined several times per week, at a minimum, for signs of deterioration or leaks. These inspections are conducted as part of normal facility operations. Deficiencies noted from these examinations are entered on a check sheet and corrected in a timely manner. The equipment is also inspected every month according to the written procedure in Appendix E. Each storage tank or vessel at the Parachute Creek Gas Plant has a system in place that has been designed and installed in accordance with good engineering practice to prevent discharges. These features may include adequate container volume to avoid overfill and high-level sensors and controls to stop liquid flow. All discharge prevention features are inspected at regular intervals. 8.3 Facility Transfer Operations, Oil Production Facility: §112.9(d) All above ground valves and pipelines are routinely inspected for the general condition of flange joints, valve glands and bodies, drip pans, pipe supports, and other appurtenances. Integrity or leak testing is also performed at the time of any installation, modification, construction, relocation, or replacement of buried piping. The following procedures and protocols are in place to maintain all flow lines in order to prevent discharges from flow lines: ■ All buried piping at the facility is protected by coating or wrapping. Any buried equipment will be visually inspected for corrosion whenever exposed through excavation. Further inspection and repair will be conducted on the affected metal equipment if problems are identified to minimize the chance for a discharge from facility transfer equipment. • When a pipe that has potential for re -use is not in service, or it is in a standby service for an extended period of time, any associated valves are kept closed and locked and lines are sealed appropriately and marked as to their tie-in connection. • All pipe supports at the facility are designed to minimize abrasion and corrosion and to allow for expansion and contraction. Pipe supports are routinely inspected as part of the general facility inspections described in this SPCC plan. SECTION 9.0 REQUIREMENTS FOR ONSHORE OIL DRILLING AND WORK OVER FACILITIES: §112.10 The Parachute Creek Gas Plant is not an onshore oil drilling or work over facility. Consequently, the provisions in §112.10 do not apply. SECTION 10.0 REQUIREMENTS FOR OFFSHORE OIL DRILLING, PRODUCTION AND WORK OVER FACILITIES: §112.11 The Parachute Creek Gas Plant is not an offshore oil drilling, production or work over facility. Consequently, the provisions in §112.11 do not apply. ✓1' r��7 C r Yi ~.f q. l• n d L- t- __ f / q � �'7'7 - V r Ff0E ky V } 1, ! 4 r`_- '' �: - ` f`�` .. :4 v"f /y1 I } li .rif:f Cnllahnm pr": f J 0 r y i-1 • ,11E IF GA1. 1 OCAIION: NE NE, SECTION 33, 1OWNSHIP 6 SOUIEI, RANGE 96 WEST 9A1� SOURCE: 7.5 MINU1E U.S_C.S- 1OPDGRAPll C MAI' (17ARACI IU11 QUADRANGLE) N EEGURL 1 SHE E COCA] ION MAP Wit LJAMS PRODUCTION RMT COMPANY PARACHUTE CREEK GAS PLANT GARP Jf E D COUN1Y, COLORADO jr 0.0C RAI 7/7/0 REVESI;JN NUMt1CR 007 ❑R7VVIN FiY DPP PROJI.C1 # E.GO206 CORDILLERAN S t 1 a PRODUCT LOADOQT AREA , AIR COMPRESSOR/ STORAGE CONTROL ROOM/ OFFICES O APPROXIMATE PWLSE 2 DOUNDARr -J -.1 PRODUCT STORAGE AREA -J V LEGEND - ESTIMATED DIRECTION OF DRAINAGE FLOW 0 - STORAGE TANK REFERENCE NUMER - SECONDARY CONTAINMENT REFERENCE NUMBER FIGURE 3 SITE MAP - PHASE 2 WILLIAMS PRODUCTION RMT COMPANY PARACHUTE CREEK GAS PLANT GARFIELD COUNTY, COLORADO REV$h]M DATE: ] I1/21M REVISION IMAM +IIS 000 OMI Hr' APvaowgD Mb1°: OUP -3►�" - r_, PROJECT j EG02071 C0RDI LLERAN SCALE: 114,000 Appendix A Certification of the Applicability of the Substantial Harm Criteria • Certification of the Applicability of the Substantial Harm Criteria Facility Name: Facility Location: Parachute Creek Gas Plant The Parachute Creek Gas Plant is located in the northeast quarter of the northeast quarter of Section 33 Township 6 South, Range 96 West in Garfield County, Colorado. See Figure 1 for detailed location information. 1. Does the facility transfer oil over water to or from vessels and does the facility have a total oil storage capacity greater than or equal to 42,000 gallons? YES NO X 2. Does the facility have a total oil storage capacity greater than or equal to 1 million gallons and does the facility lack secondary containment that is sufficiently large to contain the capacity of the largest aboveground oil storage tank plus sufficient freeboard to allow for precipitation within any aboveground storage tank area? YES NO X 3. Does the facility have a total oil storage capacity greater than or equal to 1 million gallons and is the facility located at a distance (as calculated using the appropriate formula in Attachment C-111 to this appendix {Appendix C to 40 CFR 112} or a comparable formula') such that a discharge from the facility could cause injury to fish and wildlife and sensitive environments? For further description of fish and wildlife and sensitive environments, see Appendices 1. It, and III to DOC/NOAA"s "Guidance for Facility and Vessel Response Plans: Fish and Wildlife and Sensitive Environments" and the applicable Area Contingency Plan. YES NO X 4. Does the facility have a total oil storage capacity greater than or equal to 1 million gallons and is the facility located at a distance (as calculated using the appropriate formula in Attachment C-111 to this appendix (Appendix C to 40 CFR 112) or a comparable formula') such that a discharge from the facility would shut down a public drinking water intake2? YES NO X 5. Does the facility have a total oil storage capacity greater than or equal to 1 million gallons and has the facility experienced a reportable oil spill in an amount greater than or equal to 10,000 gallons within the last 5 years? YES NO X CERTIFICATION I certify under penalty of law that I have personally examined and am familiar with the information submitted in this document, and that based on my inquiry of those individuals responsible for obtaining this information, 1 believe that the submitted information is true.. accurate, and complete. Signature Title Name (please type or print) Date If a comparable fomiula is used, di:)c nnentation of the reliability and analytical soundness of the comparable formula must be attached to this bumf. a For the purposes of 40 CFR part 112, public drinking water intakes are analogous to public water systems as described at 40 CFR 143.2(c). Appendix B Five -Year Review Documentation • • • Five -Year Review Documentation In accordance with §112.5(b), this SPCC plan been reviewed to determine if more effective prevention and control technology is available to significantly reduce the likelihood of a discharge. Pursuant to §112.5(b) and by means of this certification, I attest that I have completed a review and evaluation of this SPCC plan for Williams, and as a result Will Will Not amend the plan. A Professional Engineer has reviewed technical amendments to the plan and certified the revised document. Signature, Authorized Facility Representative Name (Printed) Title Date • Five -Year Review Documentation Original Date of Plan: August 2003 In an effort to document the five-year review process, the facility manager or his representative shall complete the information below: Review Dates Representative Or designee Name and Title Signature Man Amended (Yes or No) 2/04 Dion Pisek, P.E. Yes 3/05 Dion Plsek, P.E. Yes 11/05 Dion Plsek, P.E. Yes • • SPCC Plan Amendment Loi; • Date of Amendment General Description of Change Made Page Numbers of Changes Made Name of Certifying PE Name of Management Reviewer 2:'04 Plan revised to match plant as -built conditions Various Dion Plsek, P.E. Dave Cesark 3:05 Plan revised to meet new SPCC rule requirements and changes in storage equipment at plant. Various Dion Plsek, P.E. Jerry Alberts i 1 05 revised to include Phase 2 plant area. Various Various Dion Plsek, P.E. Dave Cesark • • Appendix C Oil Spill Response Procedures Oil Spill Response Procedures FACILITY NAME: PARACHUTE CREEK GAS PLANT FACILITY ADDRESS: NE NE, SECTION 33 IN TOWNSHIP 6 SOUTH, RANGE 96 WEST IN GARFIELD COUNTY, COLORADO. NEAR PARACHUTE, COLORADO REFERENCE: SECTION 6.12 OF SPCC PLAN WRITTEN PROCEDURES APPROVED BY: Signature Title Name (please type or print) Date • • • Oil Spill Response Procedures 1. Response Management Structure The Spill Coordinator and Alternate Spill Coordinator(s) are responsible for implementing response procedures in the event of an oil spill or discharge emergency. These personnel have the authority to commit the resources necessary to carry out a response. However, all operating personnel at the Parachute Creek Gas Plant receive training to familiarize themselves with all aspects of the SPCC Plan, facility operations, the location and characteristics of materials handled at the facility, and the location of all records within the facility; and are responsible for proper implementation of response procedures should the Spill Coordinator or Alternate Spill Coordinator(s) be unavailable. 2. Initial Response Releases at the Parachute Creek Gas Plant will be discovered through observations made during the course of normal work activities, inspections of work areas and equipment, monitoring devices, or by chance. Discovering a release is the first step in initiating a response. Upon discovery, the individual discovering a release should immediately upon discovery: 1. Assess the basic situation. 2. Stop the source of the release if safely possible using available resources (including spill kits). 3. Restrict ignition sources if the material is flammable. 4. Secure the area as off limits. 5. In the event that the incident poses an immediate threat of fire, explosion, or other impact to safety, health, or the environment, contact the local fire department at 911. DO NOT HANG UP after completing the report, let the dispatcher hang up first. 6. Report the release to the Spill Coordinator or an Alternate Spill Coordinator (see attached Oil Spill Incident Notification Phone Numbers). 7. The Spill Coordinator (or alternate) will determine whether the spill incident warrants evacuation of the facility. if so, the procedures outlined in the facility Emergency Action Plan will be followed. 8. The Spill Coordinator (or alternate) will determine whether the spill incident constitutes a discharge as defined in §112.1(b) of the SPCC regulations (see Section 3, below) and will notify appropriate federal, state, and local agencies of the spill/release incident if warranted.. 9. If the spill involves a minor volume of oil, it can be cleaned ups by facility personnel provided that 1) they are OSHA (rained and have received their current refresher training; 2) appropriate material safety data sheets (MSDS sheets) are available pier the material spilled: and 3) appropriate personal protective equipment (PPE) is available. • 10. If the spill involves a significant volume of oil, or any of the three criteria listed in (9) above are not met, it should be cleaned up by a properly certified outside contractor (see attached Oil Spill Incident Notification Phone Numbers). 3. Oil Spill Emergency Reporting If the release constitutes a discharge as defined in §l12.1(b) of the SPCC regulations, it will be considered an Oil Spill Emergency. A release of oil is considered a discharge under this Plan only if: the release is into or upon the navigable waters of the United States, adjoining shorelines, or waters contiguous with navigable waters of the United States. This is apparent if a release impacts surface water quality by causing a film, sheen, or discoloration of the water surface, or upon water or adjoining shorelines, or causes a sludge or emulsion to be deposited beneath the surface of the adjoining shorelines. Impacts to groundwater also apply if the groundwater is contiguous with navigable waters of the United States (i.e., groundwater discharges to/contributes to the total volume of a surface water body that is itself contiguous with navigable waters of the United States). In summary, if a release directly affects surface water or groundwater at the facility, it must be considered an Oil Spill Emergency. Federal and local authorities to be notified in the event of an Oil Spill Emergency are outlined below. State of Colorado In Colorado, condensate and E&P wastes are to be reported within 24 hours if the spill has entered waters of the state (any surface or groundwater) or entered navigable waters (any surface water) in sufficient quantities to cause a sheen on the water or stain on the shore. Spills less than 5 barrels which can be immediately contained and cleaned up do not need to be reported. Spills greater than 20 barrels must be reported with 24 hours. All spills and releases of exploration and production waste or produced fluid exceeding five barrels, including those contained within unlined berms, shall be reported in writing on the Colorado Oil and Gas Conservation Commission (COGCC) Spill/Release Report Form 19 within 10 days of discovery of the spill. in addition, spills or releases that exceed twenty barrels of exploration and production waste or produced fluid shall be verbally reported to the COGCC within 24 hours of discovery. Spills or releases of any size that impact or threaten to impact any waters of the state, residence or occupied structure, livestock or public byway, shall be verbally reported to the COGCC as soon as practicable after discovery. See COGCC Rule 906 for more information. If the spill may reach waters of the State (which include surface water, ground water and dry gullies or storm sewers leading to surface water), it niust also be reported immediately to the Colorado Department of Public Health and Environment. Refined petroleum releases must be reported if they have entered navigable waters or if the quantity release exceeds 25 gallons. Spills of hazardous materials must be reported if they impact navigable waters or their volume exceeds the reportable quantities in Table E1. • • • In general, verbal or telephone reports are to be made within 24 hours. The District Manager or Environmental Manager will notify regulatory agencies as appropriate. As a practical matter, an evaluation of the specifics of each spill and a determination of reporting requirements will be made. If there is any question about reporting requirements, Williams will over -report rather than under -report. Written, follow up reports are to be sent within 10 days to: Colorado Oil and Gas Conservation Commission 1 120 Lincoln # 801 Denver, Colorado 80203 (Use COGCC Spill/Release Form) Bureau of Land Management - File an "Undesirable Event Form" with: Glenwood Springs Resource Area Office 50629 Highways 6 and 24 P.O. Box 1009 Glenwood Springs, CO 81602 If the Local Emergency Planning Commission (LEPC) was notified of the spill (in the event of a hazardous substance release) a report should also be sent to: Dale Hancock Garfield County LEPC 109 8`h Street, Suite 300 Glenwood Springs, Colorado 81601 United States Environmental Protection Agency (EPA) An oil spill is reportable to the EPA if any of the following criteria are met: A) Is the spill to navigable waters or adjoining shorelines? B) Could Water Quality Standards be violated? C) Could the spill cause a film, "sheen", or discoloration? D) Could the spill cause a sludge or emulsion? E) Do any of the reporting exemptions apply? Exemptions include 1) Properly functioning vessel engines not deemed harmful, 2) Research and Development Releases (approved on a case by case basis), 3) NPDES Permitted Releases, and 4) Discharges Permitted Under the International Convention for the Prevention of Pollution from Ships (MARPOL) If the answer to any question A through D above is "yes" and none of the exemptions apply then the release is reportable to the EPA. To report an oil spill or hazardous substance release, call R the National Response Center: (800) 424-8802 Lor information on EPA's Oil Spill Program, call the Oil Spill Program Information Line at (800) 424- 9346. Region 8 EPA (CO, MT, ND, SD, UT, WY) 999 18th Street, Suite 500 Denver, Colorado 80202-2466 http://www.epa.goviregion08/ Telephone: (303) 312-6312 email: r8eisc@epa.gov Fax: (303) 312-6339 Toll Free: (800) 227-8917 • 411/ 4. Follow-up Activities After the initial response, reporting, and notification associated with a spill incident, the Spill Coordinator (or alternate) will prepare a written report which includes following: 1. Time and date of the incident; 2. Source and exact location of the spill; 3. Material involved; 4. Cause of the incident; 5. Estimated spill volume; 6. Names of any waterways involved; 7. Description of all media impacted by the spill; 8. Description of damages or injuries caused by the spill; 9. Actions taken to stop, remove, and mitigate the effects of the material spilled 10. Names of individuals and organizations contacted (time, day, who received call, who called from Williams, and pertinent notes). 11. Who reported to the scene from Federal, State, and Local agencies (time, day, etc). In addition, whenever more than 1,000 -gallons of oil are discharged in a single incident or more than 42 -gallons of oil have been discharged in each of two incidents over a 12 -month period, Willliams will submit a report to the United States Environmental Protection Agency (USEPA) Regional Administrator (RA) as outlined in Section 5.2 of the SPCC Plan. 5. Sustained Actions Where prolonged mitigation and recovery actions are required in response to a spill or release, the Spill Coordinator (or alternate) will manage the activities with any or all of the following, as warranted: 1. An outside contractor. 2. An environmental/engineering consultant. 3. Any outside vendor responsible for the incident. 4. The appropriate local, state, and federal agencies. Most release incidents at the Parachute Creek (ias Plant are expected to be handled without implementing sustained actions.. Oil Spill Response Procedures Notification Phone Numbers EPA 24 -Hour Spill Notification Number 303.293.1788 Department of Transportation National Response Center 800.424.8802. Colorado Department of Public Health & Environment (CDPHE) 303.6923033 CDPHE 24 -Hour Spill Hotline 877.518.5608 Colorado Oil & Gas Conservation Commission (COGCC) 303.894.2100 COGCC 24 -Hour Hotline 303.860.1435 Colorado Division of Labor, Oil Inspection. Section 303.620.4300 Colorado PUC Safety and Enforcement Section 800.888.0170 Colorado State Patrol Hazmat Service 970.242.7283 Hospitals (St. Mary's Hospital — Grand Junction) 970.244.2273 (Clagett Memorial — Rifle) 970.625.1510 *Garfield County Sheriff 970.6251899 *Ride Fire Protection District 970.625.1220 Parachute Fire Department 970.285.7630 U.S. Dept. of Interior, Bureau of Land Management, White River District Office 970.244.3000 Williams Production RMT Company Corporate Office 303.573.3900 Williams Production RMT Company Parachute Field Office 970.285.9377 Steven Soychak, District Manager Office: 970.285.9377 Mobile: 970.216.0922 Brad Moss, Production & Pipeline Superintendent Office: 970.285.9377 Mobile: 970.250.3683 Dave Cesark, Principal Environmental Specialist Office: 970.285.9377 Mobile: 970.216.9181 Rob Bleil, Senior Regulatory Specialist Office: 970.263.2704 Mobile: 970.210.2050 Eric Miller, Plant Manager Office: 970.285.9377 Mobile: 970.270.2813 * = this is a non -emergency number. Emergency calls should dial 911. Spill/Release Information Form Parachute Creek Gas Plant Exact name, address, and location of the facility: Date and time of the discharge: Name, title and phone number of the person reporting the spill, the responsible party and the contact person: Source of the discharge: Type or description of material discharged: Estimated total quantity of the discharge: Estimated total quantity discharged as described in §112.1(h): Names of individuals and/or organizations that have been contacted: Bodies of water involved, the extent of actual and potential pollution or threat to surface water: A chronology of all occurred events including: a complete description of circumstances causing the release or spill, actions taken and explanations: A description of all impacted media: An description of all damages or injuries caused by the discharge: Actions being used to stop, remove, or mitigate the effects of the discharge, including disposal and treatment: Other appropriate information for the particular spill ,,r • • • Appendix D Secondary Containment Information SECONDARY CONTAINMENT INFORMATION PARACHUTE CREEK GAS PLANT WILLIAMS PRODUTION RMT COMPANY PHASE 1 Tank 517 N LIInbor Tank Carncnt,,;lh.,cri mitt Tool, \olunIC ( HIlL1 C0.0131t1.rrrrn Nurnbcr CONTAINMENT DIMENSIONS Sec I FT' Overall trodary Containment IGA1l (."apacovvf7l I BBL 1 I'.1 Top Width (W3) i -. Bottom WidthIWO) FT) Top Length 0.1) 1F- Bottum Length 1L2i - Minimum Height 4311 (FTI 234 Lube oil 12 1 -- --- --- _ -'101 2,155 16,127 75). 18 1541 2 Glycal 12 2 -' - -- --- -• 101 756 18 550 3 Used ail 80 3 18.0 14.0 15.0 11.0 23 523 3,945 93 117 4 R4wwater 210 4. 80.0 74,0 33.0 27.0 2.0 4,623 34,586 823 392 5 Raw water _ 210 4 00.0 74.0 33.0 27.0 2.0 1,623 34,586 823 392 6 Condensate 300 4 80.0 74.0 33.0 27.0 2.0 4,623 34,586 823 274 7 Condensate 300 4 80.0 74.0 33.0 27,0 2.0 4,623 34,586 823 274 8 NGL 1,071 5 104 0 94 0 _ 600 50.0 3.0 1b,356 122,356 2,913 272 9 NGL 1,071 5 104.0 940 600 50.0 3.0 16,336 122,356 2,913 272 10 Amine 40 -•• 0.47 0.0 0.0 0.0 0.0 0 0 0 0 11Amine 1.071 100 - 0.0 0.0 0.0 0.0 0.0 0 0 0 0 12 Amine 100 --- 0.0 0.0 0.0 0.0 0.0 0 0 0 0 13 Glycol 70 6 05 0 60.0 25,0 20.0 _ 1.0 1,407 10,527 251 358 14 Combustor Skid Dr. Tank 10Q 6 65 0 60.0 - 23.0 20.0 I.0 1,407 19527 231 251. 15 CambusloT Skid Dr. Tank 80 6 65.11 60.0 25A 70.0 1.0 1,407 10,527 251 313 16 Lube oil 12 7 IQ 756 18 150 17 Lube oil 0.7 -- 0.11 0.0 0.0 0.0 0.0 0 0 Q 0 18 Soap 12 8 0.0 0.0 0.0 0.0 0.0 0 0 0 0 19 Degreaser 12 8 0.0 0,0 00 0.0 0.0 0 0 0 0 20 Hoe oil rank 70 •-• 0.0 0.0 0.0 0.0 0.0 f] 0 0 0 21 Hn oil heater 100 •-• 0.0 OA 0.0 0.0 0.0 0 0 0 22 Hot 011 healer _ _ 100 - 0.0 09 0.0 0.0 0.0 0 (i 0 0 23 Lulu oil 24 0.0 0.0 9.0_ 0.0 0,0 1) 0 1) 0 24 _ Lobe ail 24 •-. 0.0 0.0 0.0 0.0 0.0 0 _ 0 Q Q 25 Glycol__ _ 12 9 ---' .-- - - -3 01 756 _ 18 150 2b Lubcoil 12 10 --t -- ---' -' .-- 101 756 18 150 27 Octal 12 _ _ 11 - -- - --' ---r 101 756 18 150 28 _ Lubc 011 _ 12 _ 12 --' ---' ---' ---r i _ 280 _ _ 2,095 _ 50 416 29 Lube oil 12 13 I s i _ -i _ 200 _ 2,095 50 416 _ 30 Ethylene Glycol. 12 14 - -' -. - -' 101 756 18 150 31 Unleaded Gasoline 12 15 - -' -3 -' 105 756 IS 150 32 0fIReed Diesel 12 16 --' _--- --- -' -- -'+ 101 756 18 150 33 Dyed Diesel 12 17 -- .--a -' -- --' 101 756 18 150 34 Sump Tank I INK. 58 25.0 19.0 24.0 18.0 3.0 1.395 502436 248 NA 35 Water 100 --- 0.0 0_0 0.0 0.0 0.0 0 0 0 0 Calcnlalion to corno to for multi lc tanks on containment: Largest tank dimensions Adjusted /or, ('onleiltS, kurr.tion Volume Footprint area. Containment Capacity Secondary IFT'1 I13131,3 IPI"') (GAL) IBBL1 1`4' 300 1-19 29,514 703 234 110 I f 3 9,682 231 231 .. For conutnmcni 44 c< For Cnntaimneen 06 PHASE 2 Tank 112 Number /or, ('onleiltS, kurr.tion Tank Volume IRI341 Cartunnoerr Number CONTAINMENT DIMENSIONS Secondary IFT'1 4Acrall Coro a nmem IGALY ('apactry ITT 1116L1 _ S'(i' Fop 5, kill') (WIt IFT1 lot ban V. Mth t\6"11 11 Ti Top 1 engrh 1111 1FT1 Holtum I.onglh 11.21 {FT) blimmuns Height III) IFTI 1.14 Driomired Wrier 100 1. 46.0 4110 28.0 22.0 2A 2,155 16,127 384 384 _ A m,ne 100 1 46.0 40:0 20.0 22 0 2.0 2,155 16,112 384 38.4 3 Amax 90 -- 0.0 0.0 11.0 00 0.0 0 0 lI 13 4 1.ahe 041 12 2 101 756 18 150 5 Lobe. 011 12 3 -- i --' .- -+ 770 5.760 137 I, idL 6 Labe rod 12 4 - r ..- .-•. ... .-. 770 5,760 137 I,143 7 Luhewl 12 5 --a i • 770 5,760 i?' 1,141 14 Thrt'nnnril S5 - 1W 6 23.0 71 0 22.0 11411 1 5 692 5,17, 121 123 9 Hy/env Glycol 100 h 25.0 21.17 2221 I40 1.5 692 5,17' I_.1 123 10 6561 1.071 7 90.0 9211 58,11 32 0 3.0 15.683 117.122 .' 793 261 11 NIA _ 1.071 7 90.0 _ 920 5011 }2.11 311 IS.683 II',322 «.'93 7,61 12 Ni.[ 1.071 7 98.0 '1211 ik 1142.11 317 15,683 I I 7.4T7 2.'u'; 21,1 3. ahulanon t=, t,anpensate la multiple tank. ,n cunrainnwmr I.mprst tank dime, ,lint. Ad os,te l Volume 1 ootpnin Area Containment Caption 11110 42115 iGAL1417 !RBI +'•4 IIIQ 113 Id.43-' 1.14 ,444 103 114 8909 93 94 Vn1ta: T.,r11 (uniammrnr Capacnry iTl-11I:3hallWIaLO1•i.4b,Uj'5t311T(4'I.L1.kt.2z1.1)1 "mammon - 6n1il, al top '47 ( nn1a1111rICnt w,dih at 1,411111111, 1 1 I ..nu,nmrnt Iengil1 al tap 1 2 l onlamnrcnl Fungi at !Heiurn. 11 ('.mum nrrn•on 1IcipIli Fon ci,neammcm 111 1,4 t t1lIIAmnKnt 111. 114. \Imrmrrn (01 burn, rank w r.lu,roer IN grneral(. .utr.4rtatr 10 allrn..nlfn noon I,rel.u,rl dapo 111 10, ,nia,n 111.0.15.14111011 2 = 4 111),1:11 .nook rank t 2' tall . 8' dim 'trim uveal foo .reund:u. uo/aumrrirrn hoops in enn9ur..411 61111101r (I,.1) X0' . 14' . 2 i deep) mint 1 r w.cnrnl:rn- cu0l.nnmrm 4 \on,p, rn twnpinx+i 600110t1.. Mira 111' . 14' . ti tlrrpl used lou .rd,rldl4r+ c, N,W lnmrnl • • Appendix E Inspection Procedures and Records • Inspection Procedures and Records FACILITY NAME: PARACHUTE CREEK GAS PLANT FACILITY ADDRESS: NE NE, SECTION 33 IN TOWNSHIP 6 SOUTH, RANGE 96 WEST IN GARFIELD COUNTY, COLORADO. NEAR PARACHUTE, COLORADO REFERENCE: SECTION 6.16 OF SPCC PLAN WRITTEN PROCEDURES APPROVED BY: Signature Title Name (please type or print) Date Inspection Procedures and Records • 1. Responsibilities These procedures establish the requirements for periodic inspections and tests for the oil storage vessels and oil -filled equipment listed at the Parachute Creek Gas Plant, to minimize the risk of a spill incident. The Principal Environmental Specialist is responsible for the implementation of these procedures. Specifically, the Principal Environmental Specialist is responsible for: ▪ Conducting the inspections; Producing documentation for deficiencies found during the inspections; and • Making certain that remediation or repair work is properly prioritized and completed in a timely manner. The Principal. Environmental Specialist may designate another personnel member to complete the inspections. Designated personnel will have the authority to commit the resources necessary to carry out a response, if warranted. Operating personnel at the Parachute Creek Gas Plant receive training to familiarize themselves with all aspects of the SPCC Plan, facility operations, the location and characteristics of materials handled at the facility, and the location of pertinent records within the facility. • 2. Procedures The Principal Environmental Specialist (or designee) will conduct a monthly visual deficiency inspection of the oil storage vessels and oil -filled equipment identified in Section 6.5 of the SPCC Plan. The inspections will be documented using the attached inspection forms. The monthly inspection includes a visual examination of exterior surfaces for leaks and other deficiencies of the vessel, supports, connected piping and valves and secondary containment. It also includes visual inspection and monitoring of any leak detection system or other monitoring or warning systems (e.g., level indication/alarm or interstitial space monitoring). if any inspection reveals a leak or equipment deficiency outside of normal operating conditions, corrective action must be taken promptly to eliminate the leak or deficiency. Deficiencies noted during the inspection are recorded as a work order. The inspector will complete the following: L _ Visually inspect exterior surfaces of storage vessels and oil -filled equipment, along with associated pipes, valves and other appurtenances and identify any leaks, cracks, area of wear, external wall thinning, swelling, excessive corrosion or mechanical deficiency. 2. Visually inspect vessel/equipment supports and containment structures for excessive settlement, apparent structural weakness, cracks or other deficiency that would allow the secondary containment to leak. • • • • 3. Inspect and monitor existing leak detection systems (for example, observation ports on double - bottom tanks), cathodic protection equipment and other warning systems such as alarms and level gauges. If, during the monthly inspection, the inspector observes a spill of oil from any of the equipment the inspector shall immediately initiate the oil spill response procedures outlined in Appendix C of this SPCC Plan. • Inspection Procedures and Records Secondary Containment Drainage Log Date and Time of Drainage Containment Area Drained (ID# or description) Appearance (visual, odor, etc.) Note: Do not discharge water containing any contaminant and/or free oil or an oil sheen. Approximate Quantity Removed (Gals) Method of Removal and Disposal ; • • Appendix F Training Procedures and Records Training Procedures and Records • Spill Prevention Training Outline FACILITY NAME: PARACHUTE CREEK GAS PLANT FACILITY ADDRESS: NE NE, SECTION 33 IN TOWNSHIP 6 SOUTH, RANGE 96 WEST IN GAB FIELD COUNTY, COLORADO. NEAR PARACHUTE, COLORADO REFERS NCE: SECTION 6. I7 OF SPCC PLAN WRITTEN PROCEDURES APPROVED BY: Signature Title Name (please type or print) Date Training Procedures and Records Topics to be Covered in SPCC Training I. Introduction/Training Roster 2. Facility Layout 3. General Facility Operations 4. Location of Oil Storage Areas a. Above Ground Storage Tanks b. Compressors/Separators/Scrubbers c. Lubricating Oil Containers 5. Facility SPCC Plan a. Physical Location of Plan b. Introduce/Review Contents of SPCC Plan i. General SPCC Requirements (§112.7) ii. Specific Requirements for Onshore Production Facilities (§112.9) 6. Operation of Oil -Filled Equipment and Containment Equipment a. Above Ground Storage Tanks i. Fill Procedures b. Compressors/Separators/Scrubbers i. Maintenance Procedures c. Lubricating 011 Containers 1. Handling Procedures 7. til Spill/Discharge Response Procedures a. Appendix C of SPCC Plan S. Known Oil Spill/Discharge Incidents at Facility in Past 12 Months 9. Applicable Rules and Regulations a. Federal Regulations 1. 40 CFR 110: Discharge of Oil ii. 40 CFR 112: Oil Pollution Prevention b. State Regulations (CDPHE) c. Local (Garfield County LFPC) • • • Training Procedures and Records Oil Discharge Prevention Briefings (Training) Roster INSTRUCTOR: DATE: EMPLOYEE TITLE SIGNATURE Appendix G SPCC Regulations (40 CFR 110 and 40 CFR 112) • Environmental Protection Agency (1) The identification and inventory of applicable equipment, materials and supplies whish aro available locally and regionally, (2) An estimate of the equipment, materials and supplies which would be required to remove the maximum oil diachargo to be anticipated. (3) ,Duvolopmont of agreements and arrangements in advance of an oil dis- charge for the acquisition of equip- ment, materials and supplies to he used in responding to such a discharge. (d) Provisions for well defined and epooifie actions to be taken after dis- covery and notification of an oil die - charge including: (1) Spooifioation of an 011 disoharge response operating team consisting of trained, prepared and available oper- ating personnel. (2) Predesignation of a properly qualified oil discharge response coordi- nator who is charged with tho responsi- bility and delegated commensurate au- thority for directing and coordinating response operations and who knows how to requeat assistance from Federal authorities operating under existing- national xistingnational and roglonal contingency plans. (3) A proplannod looation for an oil discharge response operations center and a reliable oonimunioatlona system for directing the coordinated overall response operations. (4) Provisions for varying degrees of reaponee effort depending on the sever- ity of the oil discharp;e. (5) Spooifloation of the order of pri- ority In which the various water uses are to ho protected whore more than ono water use may be adversely af- fected as a result of an oil dleoharge and whore response operations may not be adequate to protect all uses. (e) Speciflo and well defined proce- dures to faollitato ronovery of damages and enforoomont ineaauree as provided for by State and local statutes and or- dinances. § 100.0 Cnerdinetlon. For the purponos of coordination, the contingency plans of State and heal governments should be developed and Implemented in consultation with pri- vate interests. A copy of any oil re- moval contingency plan developed by 17 § 110.1 State and local governments should he forwarded to the Council on Environ- mental Quality upon request to facili- tate the oocrdinatlon of theeo contin- gency plans with the National 011 and Hazardous Materials Pollution Contin- gency Plan. PART 110—DISCHARGE OF OIL son. 110.1 Definitions. 110.2 Applicability. 110.3 Diaoharas of oil in auOb quantities Re "may be harmful" pursuant to notion 311(b)(4) of the Act. 110,4 Dispersants. 110.6 Dleobargea of all not determined "as may be harmful" pursuant to section 311(b)(3) of the Act. 110.1 Notico. Atiracrltrry: 33 U.6.0. 1321(i»(3) and (h)(4) and 1281(&): 11.0. 11736, 38 FR 2I243, 3 OFR Parts 1071-1676 Comp., p. 703. $outtail: 62 FR 10710, Apr. 2, 1007, unless otherwise noted. 9110.1 Definitions, Terms not defined In this section have the same meaning given by the Sootion 311 of the Act. As used in title part, the following terms shall have the meaning indicated below: Act moans the Federal Water Pollu- tion Control Act, as amended, 33 U.S.O. 1251 et seq., also known as tho Olean Water Act; Administrator means the Adminis- tratur of the Environmental Protection Agency (EPA); Applicable water quality standards means State water quality standards adopted by the State pursuant to sec- tion 303 of the Antor promulgated by L1'A pursuant to that section; MARPOL 73/78 means the Inter- national Convention for the Prevention of Pollution from Ships, 1973, ae modi- fied by the Protocol of 1979 relating thereto, Annex I, which regulates pol- lution from o1I and which entered into force on October 2, 1983; Nauigabte waters means tho waters of tho United States, including tho terri- torial Roan. The term Moieties: (a) All waters that are currently used. were tined in the past, or may be susceptible to use in interstate or for- eign commerce, including all waters r • § i10.2 that are subject to the ebb and flow of the tido; (b) Interstate waters, including Inter- atato wetlands; (e) All ether wators suoh a9 intra- state lakes, rivers, streams (including- intermittent includingintermittent 8troama), mudflats, sandflats, and wetlands, tho use, deg- radation, or destruction of which would affoot or could affect intorstato or for- eign commerce including any suoh wa- ters: (1) That aro or could be used by inter- state or foreign travelers for roo- reational or other purposes; (2) From which flail or shollfiuh aro or could bo taken and sold Sn intorstato or foreign oommeroe; (3) That are ueed or could bo used for Industrial purposes by induetrios In interstate commoroo; (d) Ali impoundmonts of waters oth- orwieo dofinod as navigable waters tinder this aeotion; (e) Tributaries of waters idontiftod in paragraphs (a) through (d) of this Boo - tion, including adjaoent wetlands; and (f) Wetlands adjaoont to wators Iden- tified 1n paragraphs (a) through (0) of this section: Provided, That waeto treatment systems (othor than cooling ponds meeting tho orlteria of this para. - graph) aro not waters of trio {niton States; Navigablo waters do not include prior oonverted cropland. Notw i thstandint; the determination of an arna'a statue as prior oonvortod cropland by any other federal agency, for the purposoe of the Olean Wator Act, the final au- thority regarding Clean Wator Aot Ju- riediotion romains with LPA. NPJES means National Pollutant Discharge Elimination System; Sheers means an iridescent appoar- ance on tho surfaco of water; Studlie insane an aggregate of oil or oil and other matter of any kind in any form other than drudged spoil having a combined apooific gravity equivalent to or greater than water; United St(trs mOILna the Matas, tho District of Columbia, tho Common- wealth of Puerto ltioo, Guam. Arnor- lean Samoa. the Virgin Islands, and tho Trust Torrltory of the Pacific Iolanda; Wetkzmts moans thoao arena that are luundatcd or saturated by surface or ground water at a frequenoy or dura - 18 40 CFR Ch. 1 (7-1-02 Edition) tion sufficient to support, and that under normal circurnstancea do sup- port, a prevalence of vegetation typi- cally adaptod for life in eaturatod soil conditions. Wetlands genorally inoiudo playa lakes, swamps, marshes, bogs and similar arcus such as sloughs, prai- rie potholes, wet meadows, prairie rivor overflown, rnudflate, and natural ponds. (52 FR 10719, Aar. 2, 1987. as amended at 69 FR 45020, Aug. 2G. 1993; 61 FR 7421, Feb. 28, 1899] 4110.2 Applicability. The regulations of this part apply to the dlaohargo of oil prohibited by non - tion 311(5)(3) of the Act. (61 FR 7421, Feb. 26, 1996] 1110.3 Discharge of oil in such quan- tities as "may bo harmful" pursuant to section 31 L(b)(4) of tiro Act. For purposes of motion 311(b)(4) of the Aot, discharges of oil in such quan- tities that the Administrator has dc- termttled may be harmful to the publio boalth or welfaro or tho onvlronmont of the United States Ineludo diaohargns of oil that; (a) Violate applicable water quality standards; or (b) Canoe a film or sheen upon or dis- coloration of the surface of tho water or adjoining shorelines or cause a sludge or omulalon to 110 deposited be- neath the eurfaco of tho wator or upon adjoining shorelines. [61 FR 7421, Fob, 28, 10961 4110.4 Dispersants. Addition of dlspoireante or omu)a)fiore to oil to ba discharged that would clr- rumvent tho provisions of thin part 1e prohibited. [52 Fit 10719, Anr. 2, 1907. Rndnoignated at 61 FR 7421, Feb, 20, 10901 110.5 Discharges of oil not deter - minuet "as may he harmful" pursu- ant to Section 311(b)(8) of the Act. Notwithstanding any other provi- sions of this part. the Administrator has not determined the following dis- charges of oil "aa may ho harmful" for purposoe of eeotion 311(b) of the Aot: (a) Dlsohargos of oil from a proporly funotloning vessel onglno (including an • • • Environmental Protection Agency angina on a public vessol) and any tile - charges of suoh all aoounlulatod in the bilges of a vessel disohargod in compli- ance with MARPCIL 73178, Annex I, ae provided in 33 OFR part 151, suhpart A; (b) Othor disobarges of o11 pormittod under MARPC)L 73178, Annex I, as pro- vided in 33 OFR part 151, subpart A; and (o) Any dieohargo of oil oxplinitly permitted by the Administrator in con- nection with rosoaroh, demonstration projects, or studios rolating to the pre- vention, control, or abatoznent of oil pollution. Lel FR 7931. Feb. 2B, 19061 1110.0 Notice. Any parson in charge of a vessel or of an onehnro or offehoro facility shall, ns soon as ho or oho has knowiedgo of any discharge of oil from snots vassal or fa- cility in violation of section 311(b)(3) of the Aot, immodls,toly notify the Na- tional Roaponeo Center (NICO) 000--424- 8302; In tho Washington, DO metropoli- tan aroa, 202-420-2675). If diroot report - Ing to the N110 Is not practicable, re- ports may be made to tho Cont Guard or EPA predesignatod do -Boone Coordi- nator (080) for the geographio area whore the clisoharge ocnure. All such reports shall be promptly relayed to the NRO. If 1t is not possihlo to notify the NRC or tho predesignatod 008 irn- modlately, reports may ho Clado imme- diately to the nearest Coast. Guard unit, provided that the portion In charge of the vosnel or onshore or off- shore facility notifies the NRC) no soon as possible. The reports shall bo maclo in ncoordanoe with such procedures ns the 8eoretary of Transportation !nay prescribe. The procedures for each no- tice are sot forth In U.S. Const Guard regulations, 33 OFR part 153, subpart 13 and in tho National 011 and Ilazarcious Substanoes Pollution Contingency Plan, 40 CFR part 300, subpart. E. (APprovod by the Wilco of Management and Budget raider the con ,vol umnbor 2033-0045) 162 FR 1571!1, Apr. 2, 1087. Rodeelgruntoi and amended at 6] FR 7421, Fob. 28. 1085; 51 b`IR. 19032. Mar, 29, 1095] 19 • Wednesday, July 17, 2002 Part II Environmental Protection Agency 40 CFR Part 112 011 Pollution Prevention and Response;. Non -Transportation -Related Onshore and Offshore Facilities; Final Rule • • • 47140 Federal Register/ Val, 67, No. 137/ Wednesday, July 17, 2002/ Rules and Regulations 112 of the Code of Federal Regulations, is amended as follows: PART 112—OIL POLLUTION PREVENTION 1. The authority for part 112 continues to reed as follows: Authority; 33 U.S.C. 1251 et seq.: 33 U.S.0 2720; E.U. 12777 (October 18. 1891 1, 3 CFR. 1001 Comp., p. 351. 2. Part 112 is amended by designating 112.1 through 112.7 as subpart A, adding a subpart heading and rovising newly dnsignatod subpart A to road as follows: Subpart A—ApplIcability, Definitions, and General Requirements For All Facilities and All Types of oils Sec. 112.1 General applicability. 112.2 Definitions. 112.3 Requirement to prepare and implement a Spill Prevention, Control, and Countermeasure Plan. 112.4 Amendment of Spill Prevention, Control, and Countermeasure Plan by Regional Administrator. 112.5 Amendment of Spill Prevention, Control, and Countermeasure Plan by owners or operators. 112.6 (unserved]. 112.7 General requirements for Spill Prevention. Control, and Countermeasure Plans. Subpart A --Applicability, Definitions, and General Rortulremonts for All Facilities and All Types of Oils § 112.1 General applicability. (a)(1) 'd'his part establishes procedures, nlolhuds, equipment, and athnr requirements to provont the discharge of oil from non - transportation -related onshore and offshore facilities Into or upon rho navigable waters of the United States or adjoining shorelines, Dr into or upon rho waters of the contiguous zone, or In connection with activities tinder the Outer Continental Shelf Lands Act or the Deopwator Pori Act of 1974, or that may affect natural resources belonging tn, appertaining ta, or under the exclusive mnrragernent authority of the United Stoles (including resources under the Magnuson Fishery Conservation end Maungornent Act). (2) As used in this part. words in the singular also include tato plural end words In the ritascullno gander also includo tho feminine and vino versa, ns the case may require. (b) Except as provided in paragraph (d) of this section, ibis part applies to any owner or operator of a non- lrensporintion-related onshore or offshore facility mimed in drilling, producing, gathering, storing, processing, refining, transferring, distributing, using, or consuming oil and ail products, which duo to its location, could roasonabiy be expected to discharg a oil in quantities that may bo harmful, as described in part 110 of 1111s chapter, into nr upon the navigable waters of tho United Slates or nrljoining shorelines, or into or upon the waters of Ilio contiguous zone, or in connection with activities under tiro Outer - Continental Shelf Lands Act or the Deepwater Port. Act of 1974, or that may affect natural resources belonging to. appertaining to, or undor the exclusive management authority of the United States (including resources under tho Magnuson Fishery Conservation and Management Act) that hes all in: (1) Any aboveground container; (2) Any completely buried tank as defined in § 112.2: (3) Any container that is used for standby storage, for seasonal storage, or for temporary storage, or not otherwiso "pormananily closod" as dofined in § 112.2; (4) Any "bunkered tank" or "partially buried tank" as defined in § 112.2, or any container in a vault, each of which is considered an aboveground storago container for purposes of this part. (n) As provided in section 313 of the Clean Water Act (CWA), depariments, agancios, and instrumentalities of the Federal governmont aro subject to this part to tho seine extent es any person. (d) Except as provided in paragraph (1) of this section, this port does not apply to: (1) The owner or operator of any facility, equipment, or operation that is not subject to the jurisdiction of tho Environmental Protection Agency (EPA) under section 311(f)(1)(C) of the CWA, OR follows: (I) Any onshore nr offshore facility, that duo to its location, could not reasonably bo expected to have s dischargo as described in paragraph (b) of this section. This determination must he based solely upon Considuration of the geographical and location aspocls of the facility (such as proximity to navigable' wators or adjoining shorelines, land contour, drainage, ate.) and roust exclude consideration of manmade features such ns dikes, equipment or other structures, Lvhich .nay swain to rostrain, hindor, contain, or othorwiso provoni a dischurge as descrihod in paragraph (lr) of this section. (il) Any equipment, or operation of a vessel or transportation -related onshore nr offshore facility which is tiuhject to the authority and control of tho U.S. Depertmont of Transportation, as defined in the Memorandum of Understanding botcveon the Secretary of Transportation and tho Administrator of { EPA. dated November 24, 1971 (Appendix A of this part). (Id) Any equipment, or operation of a vessel or onshore or offshore facility which is subject to ilia authority and control of tlio U.S. Department of Transportation or the U.S. Department of the Interior, as defined in the Memorandum of Understanding between the Secretary of Transportation, tho Secretary of the interior, and the Administrator of EPA, dated November 8, 1993 (Appendix 11 of this pari). (2) Any Facility which, although otherwise subject to the jurisdiction of EPA, meats both of the following requirements: (i) The completely buried storago capacity of the facility is 42.000 gallons or less of oil. For purposes of this exernption, the completely buried storage capacity of a facility excludes the capacity of a cornplotely buriod . tank. es dofinod in § 112.2, and connoctod underground piping, underground ancillary equipment, and containmonl systems, that is currently subjoct to all of the technical requirements of part 280 of this chapter or all of the technical requirements of a State program approved undor }cart 281 of this chapter. The completely buried storage capacity of a facility also excludes tho copacity ofa container that is "permnnently closed," as defined in § 112.2. (ii) Thu aggregate aboveground storage capacity of the facility is 1,320 gallons or less of oil. For purposes of this exemption, only containers of oil with a capacity of 55 gallons or greater are counted. The aggregate aboveground storago capacity of a facility excludes the capacity of a container that is "parmenently closed." as definod in § 112.2. (3) Any offshore ail drilling, production, or workovur facility that 19 subject to the notices and regulations of Chia Minorals Management Service, as specified in the Memorandum of Understanding between the Secretary of 'I'ranspurtutfon, the Socrelary of the Interior, nrid t)tn Administrator of EPA, dated November 8, 1993 (Appendix 11 of this port). (4) Any completely buried storage tnrtk, es defined in § 112.2, and connected underground piping, underground ancillary equipment, and containment systems. at any facility, that is subject to all of the technical raquirornonts of part 280 of this cheptar or Siete program approved under part 2111 of this chapter, except tint such a tank must be market! on the facility diagram as provided in § 112.7(4)(3), if • • Federal Register /Vol. 67, No. 137/Wednesday. July 17, 2002 /Rules and Regulations 47141 the facility is otherwise subject to this part. (5) Any container with a storage capacity of less than 55 gallons of oil. `6) Any facility or part thereof used exclusivoly for wastewater treatment and not used to satisfy any raquiremont of this part. The production, recovery, ar recycling of oil is not wastowatar treatment for purposos of this paragraph. (o) This part establishes rogttirornants for the preparation and implementation of Spill Prevention, Control, and Countormeasura (SPCC) Plans. SPCC Plans aro dosignod to complement existing laws, regulations, rules, standards, policies, and proceduros pertaining to safoty standards, Pira prevention, and pollution prevention rules. The purpose of an SPCC Plan is to form a comprehensive Federal/State spill prevention program that minimizes lila potential tar discharges. The SPCC Plan roust addross all relovant spill prevention, control, and countormoasures necessary at tho specific facility. Compliance with this pari dons not in any way roiiava tho owner or operator of an onshore or an offshore facility from.compltonca with other Federal, State, or local lows. (f) Notwithstanding paragraph (d) of this section. the Regional Administrator may requiro that the owner or operator of any facility subject to tho jurisdiction of EPA undor section 311(j) of tho CWA. preparo and implement an SPCC Plan, or any applicable part, to carry out the purposes of the CWA. (1) Following a preliminary determination, the Regional Administrator must provide a written notice to the owher or operator stating the reasons why ho must propara an SPCC Plan, or applicable part. Tho Regional Administrator must send such notice to iho owner or operator by certifiod mail ar by personal delivery. If the owner or operator is a corporation, the Ragional Administrator must also mail a copy of such notice to the rogistored arm. if any and if known, of the corporation in the State whore the facility is locatad. (2) Within 3t1 clays of receipt of such written notice, the owner or operator may provldn information and data and may consult with the Agency about the need to proparo an SPCC Plan, or applicable part. (3) Within 30 dnys following the time under paragraph (b)(2) of this section within which tho owner or operator may provide information and data and consult with the Agency about ilia need to pre ore an SPCC Plan, or applicable part. t}to Regional Administrator roust make a final determination regarding whothor the owner or operator is (as appropriate), ice conditions, required to prepare and imploment en temperatures, weather-related visibility, SPCC Pian, or applicable part. Tho and currents within the area in which Regional Administrator must Bond the the systoms or srluipmont is intended to final dotormination to the owner or function. operator by certified mail or by personal ,A/total/cm means any work on a delivory. If the owner or oparotor is a container involving cutting, burning, corporation, the Regional Administrator welding, or heating operations that must also mail a copy of the final changes tho physical dimensions or determination to the registered agent, if configuration of the container any and if known, of the corporation in Animal fat means a non-potroleum tha State whore the facility is locator]. oil, fat, or groaso of animal, fish, or (4) If the Regional Administratormarina mammal origin. . makes a final detorrnination that an Breakout tank means a container used SPCC Plan, or applicable part, is to reliove Burgos in an oil pipeline necessary, the owner or operator must system or to raceivv and store ail prepare the Pion, or applicable part. transported by a pipelino for reinjection within six months of that final and continued transportation by determination and implement the Plan, pipeline. or applicable part, as soon as possible, Bulk storage container moans any but not later than ona year aftor tho container usod to store oil. Those Regional Administrator has made a final containers are used for purposos determination. including, but not limited to, the storage (5) The owner or oporator may appeal of oil prior to use, while being used, or a final dotermination mado by the prior to further distribution in Regional Administrator requiring commerce. Oil -filled olsctrical, preparation and implamsntntion of an operating, or manufacturing equipment SPCC Plan, or applicable part, undor is not u bulk storage container. this paragraph, Tho owner or operator Bunkered lank means a container must make the appeal to the constructed or raced in the ground by Administrator of RPA within 3U days of nt the Borth and in th the paragraph (b)(3) of this section from the container Ina manner that brooks the rocelpt of the final determination under cutting re-covering Regional Administrator requiring surrounding natural grade. or that lies abovo grado, and is covorod with earth, preparation and/or implementation of an SPCC Plan, or applicable part. Tim sand, gravel, asphalt. or other material. orator must send a complete A bunkered tank is consfdorod an owner oro copy of the nppoal to the Ragional aboveground storage container for Administrator at the time ho makes Use purposes of this part. appeal to lira Administrator. The appeal Completely buried tank means any must contain a clear and concisu container cornploteiy below grado and statement of the issues and points of fact coverer] with earth, sand, gra vol, asphalt, or other material. Containers in in tho case. in the appeal, tho ownor or oparator may also provide additional vaults, bunkered tanks, or partially information. Tho additional information buried tanks aro considered may bo from any person. The abovoground storage containors for Administrator may request additionalptrrposas of this pari. information from the ownor or operator. Complex moans o facility possessing a Tho Adntirsistrator must render a combination of transportation -related decision within 60 days of rocoiving the and non -transportation -related appoal or additional information components that is subject to the submitted by tho owner or operator and jurisdiction of more than one irederal must servo the owner or operator with agency under section 311()) of the CWA. the decisionmade in tho appoal in Uro Contiguous none means the eon() manner described in paragraph (0(1) of established by tho United Stains undor this section. Article 24 of tho Convention of the Territorial Sea and Contiguous Zona, that is contiguous to the territorial sea and that extends nine miles seaward from the outer limit of the territorial area. Contract or other approved means means: (1) A written contractual ammonium with an oil spill re:nova] organization that iderttifios and ensures tho availability of the necessary personnel and equipment within apprnpriatu responso tiaras; and/or §112.2 Definitions. For tha purposos of this part: Adverse weather means weathor conditions that mob it difficult for response egsripmont and porsonnol to clean up or remove spilled oil, and that must bo considnrod when identifying rosponse systems and equipment ifs a responso plan for the applicable operating environment. Factors 10 considor include significant wave hoight as spncifiod in Appendix E to this part • • • 47142 Federal Register/ Vol, 67, No. 137/Wednesday, July 17, 2002/Rules and Regulations (2) A written certification by the owner or operator that the necessary personnel and equipment resources, owned or operated by the facility owner or operator, aro available to respond to e discharge within appropriate response times; and/or (3) Active membership In a local or regional oil spill removal organization that has identified and ensures adequate access through such membership to necessary personnel and uqulpment to respond to a discharge within appropriate response times in the specified geographic area; and/or (4) Any other specific arrangement approved by the Regional Administrator upon request of the owner or operator. Discharge includes, but is not limited to. any spilling, looking, pumping, pouring,, emitting. emptying, or dumping of oil, but excludes discharges in compliance with a permit under section 402 of the CWA; discharges resulting from circumstances identified, reviewed, and made a part of the public record with respect to a permit issuer] or modified under section 402 of the CWA, end subject to a.condition in such permit; or continuous or anticipated intermittent discharges from a point source, identified in a permit or permit epplicatioii under section 402 of the CWA, that are caused by events occurring within the scope of relevant operating or treatment systems. For purposes of this part, the term discharge shall not include any discharge of oil that is authorized by a permit issued under section 13 of the River and 1 -/arbor Act of 11339 (33 U.S.C. 407). Facility means any mobile or fixed, onshore or offshore building. structure, installation, equipment, pike, or pipeline (other than a vessel or a public vessel) used in oil well drilling oporetions, oil production, oil refining, oil storage, oil gathering, oil processing, oil transfer, oil distribution, and waste treatment, or in which oil is used, as described in Appendix A to this part. The boundaries of a facility depend on several site-specific factors, including, but not limited to, the ownership or operation of buildings. structures, and equipment on the same situ and the types of activity at the site. Fish and wildlife and sensitive environments means areas that only be identified by their legal designation or by evaluations of Aron Committees (for planning) or members of Ilia Federal Orn -Scene Coordinator's spill rosponsn structure (during responses). These areas may include wetlands, Nairenal and State parks, critical habitats for endangered or threatened species, wilderness and natural resource areas, marine sanctuaries and estuarine reserves, conservation areas, preserves, wildlife areas, wildlife refuge, wild an scenic rivers, recreational areas, national forests. Federal and State lands that are research national areas, heritage program areas. land trust areas, and historical and archaeological sites and parks. These areas may also include unique habitats such as aquaculture sites and agricultural surface water intakes, bird nesting areas, critical biological rosource areas, designated migratory routes, and designated seasonal habitats. Injury moons it measurable adverse change, either long- or short-term, in the chemical or physical quality or the viability of a natural resource resulting either directly or indirectly frum exposure to a discharge, or exposure to a product of reactions resulting from R dist ergo. Maximum extent practicable means within the limitations used to determine oil spill planning resources and response times for on -water recovery, shoreline protection, and clonnup for worst case discharges from onshore non - transportation -related facilities in adverse weather. it includes the planned. capability to respond to a worst case discharge in adverse weather, as contained in a response plan that meats the requirements in § 112.20 or in a specific plan approved by the Regional Administrator. Navigable waters means the waters of the United States, including the territorial sons. (1) The terra includes: (1) All wators that are currently used, were used in the past, or may be susceptible to use In intorstato or foreign commerce, including all waters subject to the ebb and flow of the tide; (Ii) All interstate waters, including interstate wetlands: (iii) Ali other wators such as intrastate lakes. rivers, streams (including intermittent strunms), mudflats, sandflats, wetlands, sloughs, prairie potholes, wet tneedows, playa takes, or tenured ponds. the use, degradation, or destruction of which could affect interstate or foreign commerce including any such waters: (A) That are or could he used by interstate or foreign travelers for recreational or other purposes; or (13) From which fish or shellfish aro or could be taken and sold in interstate or foreign commerce; or, (C) That are or could be used for industrial purposes by industries in interstate commerce; (iv) All impoundments of waters otherwise dofined as waters of tho United States under this section; (v) Tributaries of waters identified in d paragraphs (1)(i) through (iv) of this definition; • (vi) The territorial son: and (vii) Wetlands adjacent to waters (other than waters that era themselves wetlands) identified in paragraph (1) of !fats definition. (2) Waste treatment systems, including treatment ponds or lagoons designed to meet the requirements of the CWA (other than cooling ponds which also moat the criteria of this definition) are not waters of the United States. Navigable waters do not include prior converted cropland. Notwithstanding the determination of en areas status asr'ior converted cropland by any other Federal agency, for the purposes of the CWA. the final authority regarding CWA luriscllction rerneins with EPA. Non -petroleum oil means oil of any kind that is not petroleum-based, including but not limited to: Fats, oils, and greases of animal, fish, or marine mammal origin; and vegetable oils, including oils from seeds, nuts, fruits, and kernels. Offshore facility mewls any facility of any kind (other than a vessel or public vessel) located in. on, or under any of the navigable wators of the United States, and any facility of any kind that is subiect to the jurisdiction of the United States and Is located in, on, or under any other wators. Oil moans ail of any kind or in any form, including. but riot limited to: fats, oils, or greases of animal, fish, or marina nrarnrnal origin; vegetable oils, including oils from seeds, nuts, fruits, or kernels; and, other oils and greases, including petroleum, fuel nil, sludge, synthetic oils, mineral oils, oil refuse; or oil mixed with wastes other than dredged spoil. Oil Spill Fferoruvol Orgarrizotion rearms an entity that provides oil spill response resources, and includes any for-profit or not-for-profit contractor, cooperative, or in-house response resources that have been established in a geographic area to provide required response resources. Onshore facility means any facility of any kind located in, on, or under any land within the United Stales, other than submerged lands. Owner or operator means any parson owning or operating nn onshore facility or en offshore facility, and in the case of any abandoned offshore facility, Ila person who owned or operated or nraintained the facility immediately prior to such abandonment. Partially buried tank means a storage container that is partially inserted or constructed in rho ground, but not entirely below grade, and not • • Federal Register/Vol. 67, No. 137/Wednosday, July 17, 20021 Rules and Regulations 47143 completely covered with earth, sand, gravol, asphalt, or other material. A partially buried tank is considered an aboveground storage container for purposes of this part. Permanently closed moans any container or facility for which: (1) All liquid and sludge has been ramnved from each container and connocling line; and (2) All connecting lines and piping have boon disconnected from the container and blanked off, all valves (except for ventilation vaivos) have boon closed and locked, and conspicuous signs have been posted an each container stating that it is a parmnnontly closed container and noting the date of closure. Person includes an individual, firm, corporation. association, or partnership. Petroleum oil moans petroleum in any form, including but not limited to crude oil, !uol oil, mineral all, shidgo. oil rause, and rained products. Production facility means all slructuros (including but not limited to wells, platforms. or storage facilitlos), piping (including but not limited to ftowlinea or gathering linos), or equipment (including but not limited to workovor equipment, separation equipment, or auxiliary non - transportation -related equipment) used in the production, axtraction, rocovory, lifting, stabilization, separation or treating of oil, or associated storage or moasuronent, and located in a single geographical oil or gas field operated by a single operator. !legion o/Administrator means the ,Regional Adnninisirator of the Environmental Protection Agency, in and for the Region In which the facility is located. Repair moans any work nocessary to maintain or restoro a container to a condition suitable for safe operation. other than !bat necessary for ordinary, dayto-day maintenance to maintain the functional intogrity of the contalnor and that does not woakon the container. Spill Prevention, Control, and Countermeasure Plan; SPCC Plan, or Plan moans the document roquired by § 112.3 that details the equipment, workforce, procedures, and steps to prevent, control, and provido adequate countermeasures to o discharge. Storage capacity of a container means the shell capacity of the container. Tro?is port ation. rel °zed and non- transportation•related, as applied to an onshore or offshore facility, are defined in the Mornorandum of Understanding betwoon the Secratary of Transportation and the Administrator of the Environmental Protection Agency, dated Novomber 24, 1071, (Appendix A of this per). United States means rho States, the District of Columbia, the Commonwealth of Puerto Rico, tho Commonwealth of tha Northern Mariana Islands, Guam, American Samoa, the U.S. Virgin Islands, and the Pacific Island Covornmonts. Vegetable oil moans a non -petroleum oil or fat of vegetable origin, including hut not limitod to oils and fats dorivad from -plant seeds, nuts, fruits, and kornels. Vessel means ovary description of watercraft or other artificial contrivrsnco used, or capable of being used, as a means of transportation on water, other than a public vessel. Wetlands moans those areas that are inundatod or saturated by surface or groundwater at a frequency or duration sufficient to support, and that undor normal circumstances do support, a provalenco of vegetation typically adapted for life in saturated soil conditions, Wetlands genarally includo playa lakes, swamps, nnarshos, bogs, and similar areas such as sloughs, prairie potholes, wet meadows, prairie river overflows. mudflats, and natural ponds. Worst case discharge For an onshore nen-transportation•rolated facility moans the largest foreseeable discharge in adverse weather conditions as determined using the workshaots in Appendix D to this part. §112.3 Requirement to prapara and implement a Spill Prevention, Control, and countermeasure Plan. . The owner or operator of an onshore or oFfsharo facility subloct to this section must propare a Spill Prevention, Control, and Countermeasure Plan (hereafter "SPCC Plan" or "Plan)," in writing, and in accordance with § 112.7, and any other applicable section of this part, (a) if your onshore or offshore facility was in operation on or before August 16, 2002, you must maintain your Plan, but must amend it, if necessary to ensure complionca with this part, on or bofore February 17, 2003, and must implement tho amended Plan as soon as possible, but not ]alar than August 18, 2003. If your onshore or offshore facility becomes operational after August 1[3, 2002. through August 18, 2003, and could reasonably be expoctod 10 have a discharge as described in §112.1(b), you must prepare a Plan on or before August 18, 2003, and fully implement it es soon as possible. but not later than August 18, 2003. ib) If you are rho owner or operator of an onshore or offshore facility that becomes operational after August 113, 2003, and could reasonably be expected to have a discharge as described in § 112,1(b), you must prepare and implement a Plan before you begin operations: (c) If you aro the owner or operator of an onshore or offshore mobile facility. such as an onshore drilling or workover rig, harp mountad offshore drilling or workover rig, or portable fueling facility you must propare, implemont. and maintain a facility Plan as roquired by this section. This provision does not require that you prepare a new Pian each timo you move the facility to a new site. The Plan may ba a senora! plan. When you move tho mobilo or portable facility, you roust locate end install it using the discharge prevention practices outlinod In the Plan for the facility. You may not o orate a mobilo or portable facility subject to ibis part unless you have implemented tho Plan. The Plan is applicable only while the facility is in a fixed (non -transportation) operating mode. (d) A licensed Professional Engineer must review and certify a Plan for it to be effective to satisfy the requirements of this part. (1) By moans of this certification the Profossinnal Eaigineer atlas's: (1) That he is familiar with the ro uirements of this part ; (ii) That he or his agent has visited and oxarninod the facility; •(iii[ That the Pian has been prepared in accordance with good onginuoring. practice, including consideration of applicable industry standards. and with the requiromonts of this part; (iv) That procedures for ror aired inspactiofs and lusting have been established; and (v) That the Plan is adequate for the facility. (2) Such codification shall in no way relieve the owner or operator of a facility of his duty to propare and Fully implement such Plan in accordance with the requirements of this part. (el If you are tho owner or operator of a facility for which a Plan is required undor this section, you must: (1) Maintain a complete copy of the Plan at the facility litho facility is normally attonded at least four hours per day, or at the nearest field office if the facility is not so attended, and (2) Have the Plan available to the Regional Administrator for on-slto roviow during normal working hours. (1) Extension of time. 11) Tho Regional Administrator may authnrizo an extension of time for the preparation and full implementation of a Plan, or Fsisy arnondinent Ihoreto. beyond the time pormitied for the preparation. implementation, or amendment of a • • • 47144 Federal Register/ Vol. 67, No. 137 / Wednesday, July 17, 2002 /Rules and Regulations Pion under this part, when he finds that. the owner or operator of a facility subject to this section, cannot fully comply with the requiremonts as a result of either nonavailability of qualified personnol, or delays in construction or.equipment delivery beyond the control and without the fault of such owner or operator or his agoras or employees. (2) If you are en owner or operator soaking an oxtanslon of time under paragraph (f)(1) of this section, you may submit o written extension request to the Regional Administrator. Your re uost must include: (1) A full explanation of the cause for any such delay and tho specific aspects of the Plan effected by the dolay; (ii) A full discussion of actions being takon or contemplated to minimize+, or mitigate such delay; and. (iii) A proposed tlmo schodule for the implomentatlon of any corrective actions being taken or contemplated, including interim dates for complotlon of tosts or studios, installation and operation of any necessary equipment, or other preventive measures. In edditinn you may present additional ora} or written stetemonts in support of your extonsion request. (3) The submission of a written extension request under paragraph (f)(2) of this section does not relieve you of your obligation to comply with the requirements of this part. Tisa Regional Administrator may request a copy of your Phan to evaluate tho extonsion request. When the Regional Administrator authorizes an extonsion of Limo for particular oqulpmont or other specific aspects of thu Plan. such extonsion does not affect your obligation to comply with t)te requirements related to othor equipment or other spoclfic aspects of tlio Plan for which Ulu Regional Administrator has not expressly authorized an oxtanslon. §112,4 Amendment of Split Prevention, Control, and Countermeasure Plan by Regional Administrator. if you aro the owner or operator of a facility subjuct to this part, you must: (a) Notwithstanding compliance with § 112.3, whenovor your facility has discharged more than 1,000 U.S. gallons of oil in a single discharge as described in § 112.1(b), or discharged mato than. 42 U.S. gallons of oil in each of two dischargos es doscribod in §112.1(b), occurring within any twolve month period, submit the following information to the Regional Administrator within 00 days from the time ilia facility becomes subject to this section: (1) Nemo of the facility; (2) Your name; (3) Location of the facility; (4) Maximum storage or handling capacity of the facility and normal daily throughput; (a) Corrective action and countermeasuros you have taken, including a description of equipment repairs and replacoments; (6) An adaquato description of the facility, including maps, flow diagrams, and topographical maps, as necessary; (7)1 he causo of such discharge os described in § 112.1(b), including a failure analysis of ilea system or subsystem in which the failure occurred; (8) Additional preventive measures you have taken or contemplated to minimize tho possibility of recurrnnco; and (9) Such other information as the Regional Administrator may roasonably require pertinent to tho Plan or discharge. (b) Take no action under this saction until it applies to your facility. This saction does not apply until the uxpiration of the timo permitted for the initial preparation and implementation of the Plan undor § 112.3, but not including any amondinents to tho Plan. (c) Send to the approprlatn agoncy or agencies in charge of oil pollution control activities in the State in which tho facility is locaioda complete copy of all information you provided to the Regional Administrator under paragraph (a) of this section. Upon receipt of the information such State agency or agencies may conduct a reviow and make rocommondations to the Regional Administrator as to further procodures. methods, equiprnent, and other requirements necessary to prevent and to contain discharges from your facility. (d) Amend your Pion, if after reviow by the Regional Administrator of the Information you submit under paragraph (a) of this section. or submission of information to EPA by tho State agoncy under paragraph (c) of this section, or after on-site reviow of your Plan, tho Regional Administrator requires that you do so. The Regional Administrator inay require you to amend your Pion if he finds that it dues not meat the requirements of this part or that arsiondmenl is nocossary to prevent and contain discharges from your facility. (o) Act in accordanco with this paragraph when the Regional Administrator proposes by cortlfied mail or try personal delivery that you emend your SPCC Plan. if the owner ar operator is a corporation, he must also notify by mail the registered agent of such corporation, if any and if known, in the State in which the facility is locator!. Tho Regional Administrator must specify the toms of such proposod amendment. Within 30 days from receipt of such notice, you may submit written information, views, and arguments on the proposed amendment. Aftor considoring ell relevant material presented, the Regional Administrator must either notify you of any amendment roquirecl or rescind the notice. You must amend your Plan as required within 30 days niter such notico. unless the Regional Administrator. for good cause, specifies another effactivo date. You must implement the amended Plan as soon as possible, but not later than six months after you amend your Plan, unless the Regional Administrotor specifies another data. (f) If you appeal a decision made by the Rogional Administrator requiring an amendment to an SPCC Plan, sond the appeal to thea EPA Administrator in writing within 30 Boys of receipt of the notice from the Regional Administrator requiring the amondment undor paragraph (o) of this soction. You must send a complete copy of the appeal to the Regional Administrator at too time you make the appeal. The appeal must contain a clear and concise statement of iho issues rind points of fact in the case. It may also contain additional information from you, or from any other parson. The RPA Administrator may request additional information from. von, or from any other person. The EPA Administrator must render a decision within 00 days of receiving the appeal and must notify you of his decision. § 112.5 Amendment of Spill Prevonllon, Contrat, and Countermeasure Plan by owners or operators. If you are tho owner or operator of a facility subjoct to this part, you must: (a) Armond the SPCC Plan for your facility in accordance with the gonoral roquiromonts in §112.7, and with any specific section of this part applicable to your facility, when there is a change in the facility design, construction, operation, or maintunnnco that materially affects its potontial for a discharge as described in §112.1(b). Examples of changns that may require amendment of the Pion include, but aro riot limited to: commissioning or decommissioning containers; replacement. reconstruction, or movement of containers; reconstruction, replacement, or installation of piping systems; construction or demolition that might alter socondary containment structures; changes of product or service; or revision of standard operation ar niairitennnce procedures at r r Federal Register/Vol. 67, Na. 137/Wednesday, July 17, 2002/Rules and Regulations 471,45 a facility. An amendment made under this section must be prepared within six months, and implemented as soon as possible, but not later than six months following preparation of the amendment. (b) Notwithstanding compliance with paragraph (a) of this section, complete a review and evaluation of the SPCC Plan at least once every five years from the data your facility becomes subject to this part; or, if your facility was in operation on or before August 16, 2002, five years from the date your last review was required under this part. As a result of this review and evaluation, you must amend your SPCC Plan within six months of the review to include morn effective prevention and control technology If the technology has been field proven et the time of the review and will significantly reduce the likelihood of a discharge as described in § 112.1(h) from the facility. You must implement any amendment as soon as possible, hut not Inter than six months following preparation of any amendment, You must docunrontyour completion of the review and evaluation, and must sign a statement as to whether you will amend the Plan. either et the beginning or end of the Plan or in a log or an appendix to the Platt. The following words will suffice, "I have completed review and evaluation of the SPCC Plan for (name of facility) on (date), and will (will not) emend tho Plan as a result." (c) }lave a Professional Engineer certify any technical amendment to your Plan in accordance with § 112,3(d). § 112.6 (Reserved) § 112.7 General requirements for Spill Prevention, Control, and Countermeasure Plans. If you are the ownerOr operator of a facility subject to this part you must prepare u Plan in accordance with good engineering practices. The Plan must have the full approval of management at a level of authority to commit the necessary resources to fully implement the Plan. You roust prepare the Plan In writing. If you do not follow the sequence specified in this section for the Plan, you roust prepare an equivalent Plan acceptable to the Regional Administrator that meets all of the nppliceble requirements listed in this part. and you must supplement it with a section cross-referencing the Location of requirements listed in this part and the equivalent requirements in the other prevention plan. If tho Plan calls for additional facilities or procedures, methods. or equipment not yet fully operational. you must discuss these items in separate paragraphs, and (Iv) Countermeasures for discharge must explain separately the details of discovery. response, and cleanup (both installation and operational start-up. As the facility's capability and those that detailed elsewhere in this section, you might be required of a contractor); must also; (v) Methods of disposal of recovered (a)(1) Include a discussion of your materials in accordance with applicable facility's conformance with the legal requirements: and requirements listed in this part. (vi) Contact list and phone numbers (2) Comply with all applicable for the facility response coordinator, requirements listed in this part. Your National Response Center, cleanup Plan may deviate from the requirements contractors with wham you have an in paragraphs (g), (h)(2) and (3), and (1) agreement for response. and all of this section and the requirements in appropriate Federal, State, and local subparts 11 and C of this part, except the agencies who must be contacted in case secondary containment requirements in of a discharge as described in §112.1(b). paragraphs (c) and (h)(1) of this section, (`t) Unless you have 112.2subm0. pr a and §§ 112.8(c)(2),112.8(c)(11), response plan under § 112.20, provide a1nd § c){2), 112.1t1(C), 112.12(c){2}, information and procedures in your 112.9(c)(2), 112.''.13(c)(2), and Plan to enable a parson reporting a 112.14(c), where applicable to o specific dischargeas described in §112.1(b) to facility, if you provide equivalent slate information on the exact address environmental protection by some other or }oration and phone number of the moans of spill prevention. control, or facility; the data and time of the countermeasure. Whore your plan does discharge, the type of material d ischarged; estimates of the total not conform to the applicable quantity discharged; estimates of the requirements in paragraphs (g), (h)(2) quantity discharged es described in and (3), and 0) of this suction, or the §112.1(b); the source of the discharge; a requirements of subparts B and C of this description dell affected media; the part, except the secondary containment cause of the discharge; any damages or requirements in paragraphs (c) and injuries caused by the discharge; actions (hill) of this section, and §§112.8(c)(2), being used to stop, remove, and mitigate 112.0(c)(11), 112.O(c)(2), 112.10(x.), the effects of the discharge; whether an 112.12(c)(2), 112,12(c)(11), 112.13(0(2), evacuation may be needed; and, the and 112.]4(c). you must state the names of individuals and/or reasons for nonconformenca In your organizations who have also been Plan and describe in detail alternate contacted. methods and how you will achieve (5) Unless you have submitted a equivalent environmental protection, If response plan ander §1 12.20. organize •the Regional Administrator determines portions of the Plan describing that the measures described in your procedures you will use when a Plan do not provide equivalent discharge occurs in n way that wilt environmental protection, he may make them readily usable in en require that you amend your Plan, emergency, end include eppropriala following the procedures in § 112.4(d) supporting materiel as appendices. and (e). (ii) Where experience indicates a (3) Describe in your Plan lire physical reasonable potential for equipment layout of the facility and include a failure (such as loading or unloading facility diagram. which must mark the equipment, tank overflow, rupture, or location and contents of each container. leakage, or any other equipment known The facility diagram must include to bo a source of a discharge), include completely buried tanks that are in your Pian a prediction of the otherwise exempted from the direction, rose of flow, and total quantity requirements of this part under of oil which could bo discharged from § 112.1(d)(4). The facility dingram roust the facility as a result of each type of also include all transfer stations and major equipment failure. connecting pipes. You must also (c) Provide appropriate containment address in your Plan: and/or diversionary structures or (i) The type of oil in -each container equipment to prevent a discharge as and its storage capacity; described in §112.1(b), The entire (ii) Discharge prevention measures containment system, including walls including procedures for routine and floor, :trust be capable of containing trundling of products (loading, oil and must be constructed so that any unlnading, and/ facility transfers, etc.); discharge from a primary containment (iii) Discharge or drainage centrals system, such as a tank or pipe, will not such as secondary containment around escape the cnntninrnent system before containers and other structures, cleanup occurs. At a minimum. you equipment, and procedures for the must n9A ono of the following control of a discharge; prevention systems or its equivalent: • • • 47146 Federal Register/Vol. 67, No. 137/Wednesday, July 17, 2002 /Rules and Rogulations (1) For onshoro facilities: (i) Dikes, berms, or retaining walls sufficiently impervious to contain oil; (ii) Curbing; (iii) Cul sorting, gutters, or other drainage systoms; (iv) Weirs, booms, or other barriers; (v) Spill diversion ponds; (vi) Retention ponds; or (vii) Sorbent materials. (2) For offshore facilitios: (i) Curbing or drip pans; or (ii) Sumps and collection systems. (d) if you determine that the installation of any of tho structuros or pieces of equipment listed in paragraphs (c) and (h)(1) of this section. and 55112.0(c)(2), 112.8(c)(11), 112.9(c)(2), 112.10(c), 112.12(c)(2), 112.12(c)(11), 112.13(c)(2), and 112,14(c) to prevent a discharge as described in § 112.1(b) from any onshoro or offshore facility is not practicable, you must clearly explain in your Plun wiry such measuros are not practicable; fur bulk storage containers, conduct both periodic integrity testing of the containers and periodic intogrity and leak testing of the valves and piping; end, unless you have submitted a rosponse pian under § 112.20, provide in your Finn the following: (1) An oil spill conlingancy plan following the provisions of part 109 d this chapter. (2) A written commitment of manpower, oqulpmont, and materials required to uxpoditiousfy control and remove any quantity Of ail disc/la/god that may bo harmful. (a) Inspections, tests, and records. Conduct inspoctions and tests roquired by this pert in accordance with writton prucnduros that you or the certifying enginoor develop for tho facility. You must keep those written procedurus and a record of dm inspections and tests, signed by the appropriate supervisor or inspector, with the SPCC Plan for a period of three yours. Records of inspections and tests kept undor usual and customary business practices will suffice for purp(rossa of this paragraph. (f) Personnel, training, and discharge prevention procedures. (1) At n ntinfrrnsm, train your oil -handling personnel in the opuration and maintenance of oqulptnent to prevent discharges; discharge procecluro protocols; applicable pollution control laws, rules. and regulations; general facility operations; and, the contents of tho (nullity SPCC Plan. (2) Designate a person at such applicable facility who is accountablo for discharge prevention and who reports to facility manugament. (3) .Schedule end conduct discharge prevention briofings for your oil - handling personnel at least once a year to assure adequate understanding of the SPCC Plan for that facility. Such briefings must highlight and doscrihe known discharges es described in § 112.1(b) or failuros, malfunctioning components, and any recently rlovelopod precautionary measures. (g) Security (excluding oil production facilities). (1) Fully fenco each facility handling, processing, or•storing oil, and lock anchor guard entrance gates whon the facility is not in production or is unattendod. (2) Ensuro that tho master flow and drain valves and any other valves permitting direct outward flow of the container's contents to the surface have adequate security measures so that they remain in the closed position when in non•ogg orating or non -standby status. (3) Tock the starter control on each oil pump in the "off ' position and locato it at a sito accessible only to authorized personnol when the pump is in a non- oporating or mon-standby status. (4) Securely cap or blank -flange the loading/unloading connections of oil pipelines or facility piping when not in service or when in standby sorvlco for an oxtonded time, This security practico also nppllos to piping that is emptied of liquid content either by draining or by inert gas pressure. (5) Provide facility lighting commensurato with the type end location of lite facility that will assist in the: (i) Discovery of discliargos occurring during hours of darkness, both by operating personnol, if present, and by non-operating porsonnol (the gonoral public, local (police, etc.); and (it) Prevention of discharges occurring through acts of vandalism. (h) Facility tank car and tank track hailing/unloading rock (excluding offshore facilities). (1) Whore loading/ unloading arae drainago does not flow into a catchment basin or treatment fncflity designed lo handle dischergos, use a quick drainage system for tank car or tank truck loading and unloading areas. You must design any containment system to hold at least the maximum capacity of any singie r:ompartmont of a tank car or tank truck loaded or unlonded al the fircility. (2) Provido an interlocked warning light or physical barrier system, warning signs, whool chocks, or vehiclo break interlock system itt loading/unloading areas to provent vehicles from departing before complatto disconnection of floxiblo or fixed oil transfer lines. (3) Prior to filling and departure of any tank car or tank truck, closuly inspect for dischargos tate lowermost drain and all outlets of such vehicles, and if necessary, ensure that they are tightened, adjusted, or replaced to prevent liquid discharge while in transit. (i) If a field-constructod aboveground container undergoes a repair, alteration. reconstruction, or a change in service that might affect the risk of a discharge or failure duo to brittle fracture or other catastrophe, or has discharged oil or failed duo to brittle fracture fathom or other catastrophe, ovaluate tho container for risk of discharge or failuro due to brittle fracture or other catastrophe, and as necessary, take appropriato action. (1) Tit addition to the minimal prevention standards listed undor this section. include in your Plan a comploto discussion of conformance with the applicable requirements and other offective discharge prevention and containment procedures listed to this pari or any applicablo more stringent State rules, regulations, and guidelines. 3. Part 112 is amended adding subpart 13 consisting of §§112.13 through 112.11 to road as follows: Subpart D--Requirernents for Petroleum Oils and Non•Pntroleum Oils, Except Animal Fats and Oils anti Greases, and Fish and Marine Mammal Oils; and Vegetable 011s (including Oils from Seeds, Nuts, Fruits, and Kernels) Snc. 112.11 Spill Prevention, Control, and Countermeasure Plen requirements for unshorn facilities (excluding production facilities), 112.41 Spill Provcntion, Control. end Countonnensure Pion requirements for onshore oil production facllilles. I12.10 Spill Pruvention, Control, and Countermeasure Pian requirements for unshorn an drilling and workover frnaittties.. 112.11 Spill Prevention. Control, end Countermeasure Plan requirements for offshuro oil drilling, production, or workovor facilities. Subpart 8—Requirements for Petroleum 011s and Non -Petroleum OIIs, Except Animal Fats and Oils and Greases, and Fish and Marine Mammal Otis; and Vegetable Oils (Including 011s from Seeds, Nuts, Fruits, and kernels) §112.8 Spill Provonlion, Control, and Countermeasure Plan requirements for onshore faclllttos (excluding production facilities). if you are tho owner ur operator of en onshore fncillty (excluding a production facility), you must: (a) Moot the general requirements for tho Plan listed under § 112.7, and the spucific discharge prevention and containment procedures listod in this section. • Federal Register/ Vol. 67, No. 137/Wednesday. July 17, 2002 /Rules and Regulations 47147 (b) Facility drainage. (1) Restrain drainage from dikod storage areas by valves to pravant a dischargo into the drainage system or facility effluent treatment systom, oxcept where facility systems are designed to control such • discharge. You may ompty diked areas by pumps or ejnctars; howover, you must manually activate these pumps or ejectors and must inspoct tho condition of the accumulation before starting, to ensure no oil will be discharged. (2) Use valves of manual, opetnanl- closed design, for tho drainage of diked areas. You may not use flapper -type drain valves to drain diked areas. If your facility drainage drains directly into a watarcourso and not into an onsite wastewater treatment plant, you must inspect and may drain uncontaminated retained stormwater, as provided in paragraphs (c)(3)(i1), (iii), and (iv) of this soction. (3) Resign facility drainage systems frnrn undikod areas with a pntontial for a discharge (such as whore piping is located outside containment walls or where tank truck discharges may occur outsider tho loading arda) to flow into ponds, lagoons, or catchment basins designed to retain oil or return i1 to the facility. You must not locate catchment basins in areas subject to poriodic flooding. (4) if facility drainago is not engineered as in paragraph (h)(3) of this section, equip the final discharge ofall ditches insido tho facility with a divorsion system that would, in the ovent of an uncontrollod dischargo, retain oil in the facility. (5) Whero drainage waters are treated in more than ono troalmont unit and such trentmont is continuous, and pump transfer k needed, provide two "lift" pumps and pormunontly install at least ono of !ha pumps. Whalevor techniques you use), you must engineer facility drainage systems to provont a discharge ns doscribod in § 112.1(b) in caso thoro is an equipment failure or human error at the facility. (c) Milk storage containers. (1) Not use a container for the storage of oil unless its material end construction aro compatible with the material stored and conditions of storage) such as prossura and temporature. (2) Construct all bulk storago container installations so that you provide a secondary means of containment for the antis capacity of tho largest single containor and sufficient freeboard to contain precipitation. Yoti must ensure that diked areas ora sufficiently impervious to contain discharged oil. Dikos, containment curbs, and pits aro commonly arnployod for this purpose). You may also use en alternative system consisting of a drainage tronch onclosuro that must be arranged so that any discharge will torrulnalo and be safely confined in n facility catchment basin or holding pond. (3) Not allow•drainogo of uncontaminated rainwater from the diked area into a storm drain or dischargo dart effluent into an opon watercourse. lake, or pond, bypassing the facility treatment systom unless you: (i) Normally keep lila bypass valve sealod closed. (ii) inspect the retained rainwater to ensure that its prosonco will not cause a discharge as doscribod in §112.1(b). (iii) Cpan the bypass valve and reseal it following drainago under rosponsible su ervisiori, and (iv) Keep adequate records of such evonts, for oxenople, any records required under permits issued in accordance with H122.410)12) and 122.11(m)(3) of this chapter. (4) Protect any completely buried metallic storage tank installed on or after )enuary 10, 1974 from corrosion by coatings or cathodic protection compatible with local soil conditions. You must regularly leak test such completely buried metallic storage tanks. (5) Not use partially buriod ar bunkorod metallic tanks for the storage of oil, unless you protoct tho buried section of tiro tank from corrosion. You must protect partially buriod and bunkerod tanks from corrosion by coatings or cathodic protaction compatible' with local sail conditions. (f) Test each aboveground containor for integrity on a regular schodulo, and whenever you make material repairs. Tho froquoncy of and type of testing must take into account container size and design (such us Floating roof, skid - mounted, elevated, or partially buried). You roust combine visual inspection with anoihur testing tochniqua such as hydrostatic testing, radiographic lasting, ultrasonic tasting, acoustic omissions testing. or another system of non- destructive shell tasting. You must keep comparison records and you roust also inspect the container's supports and Foundations. In addition, you must fraquontly inspect ilio outside of the container for signs of detorioralion, discharges, ar accumulation of oil inside diked areas. Records of inspections and tests kopi undor usual and customary business practices will suffice for purposes of this aragraph. (7) Control leakage through defoctivo internal heating coils by monitoring tho steam return and axhnust linos for contamination from internal heating coils that discharge into an open watercourse, or pass the steam return or oxheust lines through a settling tank, skimmer, or other separation or retonlion systom. (81 Engineer or update each container installation in accordance with good engineering practice to avoid discharges. You must provide at least one of the following devices: (i) High liquid lavol alarms with an audible or visual signal al a constantly attended operation or surveillance station. In smaller facilities an audible) air vont may suffice. (ii) High liquid level pump cutoff devices set to stop flow at a predoterminod container content level. (ill) Direct audible or code signal communication between the container gauger and the pumping station. (iv) A fast rosponso systom for determining tho liquid level of each bulk storage containor such as digital computors, tolepulse, or direct vision gauges. If you use this alternative, a person must be present to monitor gaugos and the) overall filling of bulk storage containors. (v) You must regularly test liquid level sensing devices to onsura proper operation. (9) Obsorve affluent treatmont facilities frequently onoug}i to detect possible system upsets that could cause a dischargo as described in § 112.1(b). (10) Promptly correct visible discharges which rosult in a loss of oil from the container, including but not limited to seams, gaskets, piping, pumps, valves; rivets. and bolts. You must promptly romovo any accumulations of oil in diked areas. (11) Position or locale mobile or portable oil storago containers to prevonl a dischargo as doscribod in § 1 i2,1(b). You must furnish a secondary moans of containment, such as a dike) ar catchniont basin. sufficient to contain the capacity of the largest single compartment or container with sufficient freeboard to contain precipitation. (d) Facility transfer operations, pumping, and facility process. (1) Provide buried piping that is installed or repiacecl on or after August 16, 2002, with a protective wrapping and coating. You must also cathndically protect such buried piping installations or otherwise satisfy the corrosion protection standards for piping in part 288 of This chapter or a Stnto program approvod under port 281 of this chapter. If e stiction of buried lino is exposed for any reason, you must carefully inspect it for deterioration. If you find corrosion damage, you must undortako additional examination and corrective) action as • • • 47140 Federal Register/Vol. 67, No. 1371Wednesday, July 17, 20021 Rules and Regulations indicated by the magnitudo of tho damage. (2) Cap or blank -flange tho torminal connection at tho transfer point and mark it as to origin whop piping is not in service or is in standby service for an extended time, (3) Properly design pipe supports to minimize abrasion and corrosion and allow for expansion and contraction. (4) Regularly inspoct all aboveground valves, piping, and appurtenances. [luring the inspection you must assess the general condition of items, such as flange joints, expansion joints. valva glands and bodies, catch pans, pipeline supports. locking of valves, and metal surfaces. You must also conduct integrity and leak testing of burins] piping at the time of installation, modification, construction, relocation, or replacement. (5) Warn all vehicles entering the facility to bo suro that no vehicle will ondangor aboveground piping or other oil transfer operations. 5112.9 Spill Prevention, Control, and Countermeasure Plan requlramonts for onshore oil production facilities. ]f you are tho owner or operator of an onshore production facility, you roust: (n) Meat the general requirements for tho Plan listed under§ 112.7, and the specific discharge provontion and containmant procedures listed under this section. (b) Oil production facility drainage. (1) At tank batteries and separation end treating eroas where there is a reasonable possibility rola discharge as • described in § 112.1(b), close end seal at all times drains of dikes or drains of equivalent mammas required under §112.7(c)(1), except w]ien draining uncontaminated rainwater. Prior to drainage, you must inspect the diked area and take action as provided in § i12.tt(c)(3)(ii), (iii), and (iv). You must remove accumulated oil on the rainwater and return it to storage or disposo of It in accordance with logally approved methods. (2) Inspect at regularly scheduiod intervals field drainage systems (such as draftingo ditches or road ditches), and oll traps. sumps, or skirnmors, for an accumulation of oil that may have) rosulted from any small discharge. You must promptly remove any accumulations of oil. (c) Oil production facility balk storage containers. (1) Not use a containor for the storage of oil unless its material and construction are compatible with the material storod and the conditions of storage. (2) Provide all lank battory, separation, and treating facility installations with a secondary moans of containment for the antiro capacity of the largest single container and sufficient freeboard to contain precipitation. You must safely confine drainage from undlked areas in a catchment basin or holding pond. (3) Periodically and upon a regular schedule visually inspect each container of oil for deterioration and maintenanco neads, including tho foundation and support of oach container that is on or above the surfaco of the ground. (4) Engineer or update. new and old tank baltary installations in accordance with good engineering practice to prevent discharges. You must provide) et loast ono of tho following: (i) Container capacity adequate to assure that a container will not overfill if a pun-Tor/gauger is delayed in making regularly scheduled rounds. (11) Ovorflow equalizing lines between containers so that a full container can overflow to an adjacont container. (til) Vacuum protactlun adoquetn to provont containor collapse during a pipoline run or other transfer of oil from the container. (iv) High level sensors to generato and transmit an alarm signal to the computer whuro tho facility is subject to a computer production control system. (d) Facility transfer operations, oil production facility. (1) Periodically and upon a regular schedule inspect all aboveground valves and piping associated with transfer oporations for the general condition of flango joints, valvo glands and bodies, drip pans. pipe supports. pumping well polish rod stuffing boxes, bleoder and gauge valvas, and other such items. (2) Inspect saltwater (oil fio]d brine) disposal facilities often, particularly following a suddon change in atmospheric temperature, to detect possibin systani upsots capable of causing a discharge. (3) Have a program of flowlino mai rntenanca to prevent dischargos from each llowline. §112.10 Spill Prevontlon, Control, and Countermeasure Plan requirements for onshore oil drilling and workovor fatuities. If you aro the owner or aporator of an onshore oil drilling and workover facility, you must: (a) Moot the general roqulrernonls listed under § 112.7, end also meet tha specific discharge prevention and containment procedures listed under this section. (b) Position or locate mobile drilling or workover equipment so as to pravonl a discharge ns described in § 112.1(b)• (c) Provide catchment basins or diversion structures to intorcapt acid contain discharges of fuel, crude oil, or oily drilling fluids. (d) Install a blowout prevention (BOP) assembly and well control system before drilling below any casing string or during workover oporations. The BOP assembly and well control system must be capable of controlling any wall -head pressure that may be encounterod while that BOP assembly and well control system are on the wolf. § 112.11 Spill Prevention, Control, and Countermeasure Plan requirements for offshore oil drilling, production, or workover facilities. If you aro the owner or operator of an offshore oil drilling, production, or workovor facility, you must: (a) Meet the general requirements listed under § 112.7, and also meat the specific discharge provontion and containment procedures listed under this section. (b) Use all drainage collection equipment to prevent and control small. oil discharges around pumps, glands, •valves, flanges, expansion joints, hoses, drain linos, separators, treaters, tanks, and associated uqulpmenl. You must control and direct facility drains toward a control collection sump to prevent the facility from having a discharge as described in §112.1(b). Whore drains and sumps are not practicable. you must remove oil contained in collection equipment as often es necessary to prnvenl overflow. (c) For facilities employing a sump system, provide adequatoly sizod sump and drains and nrako available a spare pump to romovo liquid from tho sunup and assure that oil does not oscape. You must employ a regularly scheduled preventive maintenance inspection and testing program to assure reliable operation of the liquid removal system and pump start-up devico. Redundant automatic sump pumps and control devices may bo required on some installations. (d) At facilities with areas where separators and trotters are equipped with dump valves which predominantly fail in tho closed position and whore pollution risk is high, spocially equip tho facility to proven! the dischargo of oil. You must prevent the discliergo of oil by: (1) Extending the flare lino to a dlkod area if Ilia separator is noor shore: (2) Equipping this separator with a high liquid lave] sensor that will automatically shut in wells producing to the separator: or (3) Installing parallel rodundant dump valvas. (u) Equip atmospheric storage or surgo containers with high liquid love] Federal Register/ Vol. 67, No. 137/Wednesday, July 17. 2002/Rules and Regulations 4714t1 sousing devices that aclivato an alarm or control tho flow. or otherwise prevent discharges. (f) Equip prossura conlainors with high and low pressure sensing devices that nctivata an alarm or control the flow, (g) Equip containers with suitable corrosion protection. (h) Propare and maintain at the facility a written procedure within the Plan for inspecting and Costing pollution prevention equipment and systems. (i) Conduct testing and Inspection of the pollution prevention equipment and systems at the facility on a scheduled periodic basis, commensurate with the complexity, conditions, and circumstances of the facility and any othor appropriate regulations. You rnust use simulated dischargos for testing and inspecting human and equipment pollution control and countormoasuro systoms. (y) Describe in detailed records surface and subsurface wail shut-in valves and devices in use at the facility for each wall sufficiently to determine their method of activation or control, such as pressure differential, change in fluid or flow conditions, combination of pressure and flow, manual or ramoto control mechanisms. (k) Install a BOP assomhly and wall control system during workovor oporatlons and before drilling below any casing string. Tho BOP assombly and well control system must be capable. of controlling any well -head prossura that may bo encountered while Ora BOP assembly and well control system aro on tho wail. (1) Equip all manifolds (headers) with check va)vos on individual llowlinos. (m) Equip the Bowline with a }sigh pressure sensing device and shut-in valve at the wellhead if tiro shut-in well pressure is grantor than the working pressure of tha flowline and manifold valves up to and Including tho holder valves. Alternatively you may provide a pressuro relief system for flnwlinas. (n) Protect all piping appurtenant to the facility from corrosion, such as with protective coatings or cathodic protocli on. (o) Adequately protect sub -marina piping appurtenant to the facility against onvlronmental stresses and nthor activitios such as fishing oporatIons, (p) Maintain sub -marine piping appurtenant to the facility in good operating condition at ail times. You roust poriodically and according to a schedule inspect or test such piping for failures. You must document and keep a record of such inspoctions or tests at the facility. 4. Part 112 is amended by adding subpart C consisting of §5112.12 through 112.15 to road es follows:: Subpart C—Roqulrements for Animal Fats and Oils end Greasus, and Fish and Marine Mammal Otis; end for Vegetable Oils, Including 011e from Sorirls, Nuts, Fruits and Kernels Soc. 112.12 Spill Prevention, Control, and Countermeasure Plan requirements for onshore facilities (excluding production facilities). 112.13 Spill Prevention, Control. end Countermeasure Plan requirements for onshore oil production facilities. 112.14 Spill Provontion, Control, and Countermeasure Plait requirements for onshore ail drilling and workover facititios. 112.15 Spill I'rnvonlion, Control, and Countermeasure Plan requiremonts for offshore oil drilling, production, or workovar fncihities. Subpart C—Requirements for Animal Fats and Oils and Greases, and Fish and Marine Mammal Otis; and for Vegetable Oils, Including Oils from Seeds, Nuts, Fruits, and Kernels, § 112.12 Spill Prevention, Control, and Countermeasure Plan roqulrarnonis for onshore Iaclllllos (excluding production facilities) if you aro Cho owner or operator of an onshore facility (excluding a production facility), you must: (a) Moot tho gonoral requirements for the Plan listed under § 112.7, and the specific dischargo provontion and containment procoduros listed in this section. (b) Fociiitydroinago. (i) Rost rain drainago from dikod storage areas by valves to prevent n discharge into tho drainago system or facility offluunt troatmont system, except whore facility system's aro designed to control such discharge. You may empty dikod areas by pumps or ejectors; howover, you roust manually activate those pumps or ejectors and must inspect the condition of tho accumulation before starting. to ensure no oil will be discharged. (2) Use valves of manual, open-and- closod design, for the drainage of dikod areas, You may not use flapper -typo drain valvas to drain dikod areas. If your facility drainage drains directly into a watercourse and not into an ort -site wnstowater treatment plant, you must inspect and may drain uncontatninated retained stormwator, subjact to the requirements of paragraphs (c)(3)(ii), (iii), and (iv) of this section. (3) Design facility drainage systems from undikod areas with a potnniial for a discharge (such as whore piping is located outside containment walls or wlrerct tank truck rlischargas may occur outside the loading area) to flow into ponds. lagoons, or catchment basins designed to retain ail or return it to the facility. You must not locate catchment basins in areas subjact to periodic flooding. (4) if facility drainage is not engineered as in paragraph (b)(3) of this section, aquip the final discharge of all ditches inside the facility with a diversion system that would. in the event of an uncontrolled discharge. retain oil in the facility.. (5) Where drainage waters are treated in more than one treatment unit and such treatment is continuous, and pump transfer is needed, provide two "lift" pumps and permanently install at least one of tho pumps. Whatever tochniquas you use, you must enginoar facility drainago systems to prevent a discharge as (Inscribed in § 112.1(b) in case !hero is an oquipment failure or human error at Cho facility. (c) fink storage containers. (1) Not use a container for the storage of oil unless its ntntoral and construction are compatiblo with the material stored and conditions of storage such as prossura and tomporatura. (2) Construct all bulk storage container installations so that you provide a secondary moans of containment for the entire capacity of the largest single container and sufficiont freeboard to contain precipitation. You must ensure that dikod areas aro su[flciontly impervious to contain discharged oil. Dikes, containmant curbs, and pits aro commonly employed for this purpose. You may also use an alternative systorn consisting of a drainage tronch enclnstrro that must be arranged so that any dischargo will torminato and bo sofnly confined in a facility catchment basin or holding pond. (3) Not allow drainago of uncontaminated rainwater from the diked area into a storm drain or discharge of an affluent into an open watercourse, lake, or pond, bypassing Cha facility treatment system unless you: (i) Normally koep the bypass valva soalod closed. (11) inspoct the retained rainwater to ensure that its prosenco will not rause a discharge es described in § 112.1(b). (ill) Upon the bypass valvo and reseal it fallowing drainage under rosponslhle supervision; and (iv) Kuop adequatr: rocords of such events. for example. any records required under permits issued in accordance with §§122.41(})(2) and 122.4 1(111)(3) of this chapter. (4) i'rotocl any completely buried mntal1ic storage tank installed on or after lauunry 10. 1974 from corrosion by • • • 47150 Federal Register fVal. 67, No. 137/ Wednesday, July 17, 2002/Rules and Regulations coatings or cathodic protection compatible with local soil conditions. You must regularly leak test such completely buried metallic storage tanks. (5) Not use partially bur'lod or bunkered metallic tanks for the storage of oil, unless you protect the burled section of tite tank from corrosion, You mast protect partially buried and bunkered tanks from corrosion by coatings or cathodic protection com patiblo with local soil conditions. (13 Test ench aboveground contalnor for integrity on a regular schedule, and wlronovoryou make material ropairs. Tho frequency of and type of testing must take into account container size arid design (such as floating roof, skid- mountod, elevated, or partially buried). You must comhino visual inspection with another tosting technique such as hydrostatic resting, radiographic testing, ultrasonic tasting, acoustic emissions testing, or another system of non- destructivo sholl testing, You must hop comparison records and you must also inspect tho containor's supports and foundations, hi addition, you must frequently Inspect the outsido of tlto container for signs of deterioration, . discharges, or accumulation of oil inside diked areas. Records of Inspections and tests kept under usual and customary business practices will suffico for purposes of this paragraph. (7) Control leakage through defective internal heating coils by monitoring Ilia steam return and exhaust lines for contamination from internal heating coils that discharge into an open watercourso, or pass tlia steam return or exhaust linos through a sattlfng tank, skimmer, or other separation or retention system. (a) Engineer or update each conlniner installation fn accordance with good engineering practice to avoid discharges. You must provicin et Ieast one dale following dovicos: (1) High liquid levo] alarms with en audible or visual signal at a constnntly attended operation or surveillance station. in smaller faciiitios an audible air vont may suilico, (ii) High liquid loyal pump cutoff devices sat to stop flow at a predaterrninod containor content level. {[ii) 17iroct eudlbla or code signal connnunit.ation botwoen tho container gouger and the pumping station. (3v) A fast response sysioni for determining tho liquid levo] of each bulk storage container such as digital computers, telopulso, or diroct vision gauges. If you use this altorriativo, a parson roust be present to monitor gauges end the overall filling of bulk storage containers. (v) You must regularly test liquid level sensing devices to ensure proper operation. (9) Observe effluent treatment facilities froquantly enough to detect possible system upsets that could cause n discharge as described in §112.1(b). (10) Promptly correct visihlo discharges which result in a loss of oil from the container, including but not Ilmiiod to seams, gaskets, piping, pumps, valves, rivets, and bolts. You must promptly remove any accumulations of oil in diked areas. (11) Position or locate mobile or portable oil storage containers in prevent a discharge as doscribod in 5 112.1(b). You must furnish n secondary means of containment, such as a diko or catchment basin, sufficient to contain the capacity of the largest singly cornpartrnont or containor with sufficient freeboard to contain precipitation. (d) Facility transfer operations, pumping, and facility process. (1) Provide buried piping !hot is installed or replaced ort or nfter August 18, 2002, with a protective wrapping and coating. You must also cnthcdicnlly prosect such buried piping installations or otherwise satisfy tho corrosion protection standards for piping in part 200 of this chapter or a State program approved under part 2111 of this chapter. If a section of buried line Is exposed for any reason, you must cnrefuily inspect it for doterioration. If you find corrosion damage, you must undertake additional examination and corrective action as 'indicated by the magnitude of the damage. (2) Cap or blank -flange the terminal connection at the transfer point and mark it as to origin when piping Is not in servico or is in standby service for an extended thee. (3) Properly design pipe supports to minimize abrasion end corrosion and allow for expansion and contraction. (4) Regularly inspect all aboveground valves, piping, and nppurtenancas. During the inspection you must assess the general condition of items, such as flange joints, expansion joints, valva glands and bndias, catch pans, pipeline supports, locking of valves, and motel surfaces. You must also conduct integrity and leak testing of buried piping at the now of tnsiollation, modification, construction, rolot;rttion, Or replacement. (5) Warn all vehicles entering the facility to be sure that no vehicle will endanger aboveground piping or other oil transfer operations. § 112.13 Spill Prevention, Control, and Countermeasure Plan requirements for onshore ell production facilities. If you aro the owner or operator of an onshoro production facility, you must (a) Meet tho general ioquirentenls for the Plan listed under § 112.7, and the specific discharge prevont.ion and contninmont procedures listed under this section. (b) Oil production .facility drainage. (1) At tank batteries and separation and treating areas where there is a reasonable possibility of a discharge as described in § 112.t(b), close and soal at all limes drains of dikes or drains of equivalent measures required under § 112.7(c)(1), except when draining uncontaminated rainwater. Prior to drainage, you must inspect the diked aroa and take action as provided in 112.12(c)(3)(ii), ([II), and (iv). You must remove accumulated oil on the rainwater and return ii to storage or dispose of it in accordance with legally approved methods, (2) Inspect at regularly scheduled intervals field drainage systems (such as drainage ditches or road ditches), and oil traps, sumps. or skimmers, for an accumulation of oil that may have resulted from any small discharge, You must promptly remove any accumulations of oil, (c) QiI production facility bulk storage containers. (1) Not use a container for this storage of oil unless its malarial and construction aro compatible with the motorial storod and the conditions of storage. (2) Provide all tank battery, separation, and treating facility installations with a secondary means of containment for the entire capacity of the largest single containor and sufficient freeboard to contain precipitation. You must safely confine drainage from undiked areas in a catchment basin or bolding pond. (3) Periodically arid upon a regular schedule visually inspect each container of oil fur deterioration and maintenance needs, including tho foundation and support of each container that is on or ahova tate surface of the ground. (4) Engineer or update now and old tank haltory installations in accordance with good engineering practice to provent discharges. You must provide at least ono of Ilia following: (i) Contnlnor capacity ndequate to assure that a container will not overfill if a pumper/gauger is delnycd in making regularly scheduled rounds. (ii) Overflow equalizing linos batwoon containers so that a hill container can overflow to an adjacent container. ([iii) Vacuum protection adequate to prevent container collapso during a Federal Register/Vol. 67, No. 137/Wednesday, Ju}y 17,`2002/Rules and Regulations 47151 pipeline run or other transfer of oil from the container. (iv) High level sensors to generate and transmit an alarm signal to the computer where tho facility is subject to a computer production control system. (d) Facility transfer operations, oil production facility. (1) Periodically end drain lines, separators. treaters, tanks. and associated equipment. You must control and direct facility drains toward a central collection sump to prevent the facility from having a discharge as described in §112.1(b). Where drains and sumps aro not practicable, you must remove oil contained in collection upon a regular schedule inspect ail equipment as often as necessary to aboveground valves rind piping prevent overflow. associated with transfer operations for (c) For facilities employing a sump the general condition of flange joints. system, provide adequately sized sump valve glands and bodies, drip pans. pipe, and drains and make available n spare supports, pumping well polish rod pump to romovo liquid from the sump stuffing boxes, bleeder and gauge valvos, and assure that oil does not °scope. You and other such items. must employ a regularly scheduled (2) Inspect saltwater (oil field brine) preventive maintenance inspection and disposal facilities often, particularly testing program to assuro reliable following a sudden change in operation of the liquid removal system atmospheric temperature, to detectand pump start-up device. Redundant possible system upsets capable of automatic sump pumps and control causing a discharge. devices may be required on some (3) Have a program of flowline installations. maintenance to prevent discharges from (d) At facilities with areas where each Bowline. separators and treaters are equipped 112.14 Spill Prevention, Control, and with dump valves which predominantly Countermeasure Plan requirements for fail in the closed position and where onshore oil drilling and workover facilities. pollution risk is high, speciallyy equip if you ora the owner or operator of an the facility to prevent the discharge of onshore oil drilling and workovar oil. You must prevent the discharge of facility, you must: all by: (a) Moot the general requirements (1) Extending the flora Ilea to a diked listed under § 112.7, and also moot the area if the separator is near shote; specific discharge prevention and (2) Equipping the separator with a containment procedures listed under high liquid level sensor that will this section. automatically s]iul in wells producing to (b) Position or locate mobilo drilling the separator; or or workover equipment so as to prevent (3) Installing parallel redundant dump a discharge as described in 6112.1(h). valves. (c) Provide catchment basins or fel Equip atmospheric storage or surge diversion structures to intercept and containers with high liquid level contain discharges of fuel, crude oil, or sensing devices that activate an alarm or oily drillingfluids. control the flaw, nr otherwise prevent (d) Instala blowout prevention (BOP) discharges, assembly end well control system before (f) Equip pressure containers with drilling below any coring siring or high end low pressure sensing devices that activate an alarm or control the during workovor operations. The BOP assembly and well control system must flow' be capable of controlling any well -head (g) Equip containers with suitable pressure that may be encountered while corrosion protection. tint BOP assembly and well control (]n) Prepare and maintain tit the system are on tho well. facility a written procedure within the Ilan for inspecting and testing pollution § 112.15 Spin Prevention, Control, and prevention equipment and systems. Countermeasure Pian requirements for (1) Conduct testing and inspection of offshore oil drilling, production, or the pollution prevention equipment and workover facilities. systems at the facility on a scheduled If you aro the owner or operator of an periodic basis, commensurate with the offshore nil drilling, production, or complexity, conditions, and wnrkover facility, you must: circumstances of the facility and any (a) Meet the general requirements other appropriate regulations. You must listed under § 112.7, and also meet the use simulated discharges for testing and specific discharge prevention and inspecting human and equipment containment procedures listed under pollution control and countermeasure this section. systems. (h) Use oil dralnoge collection (j) Describe in detailed records surface equipment to prevent and control small and subsurface well shut-in valves and oil discharges around pumps. glands, devices in use at the facility for each valves. flanges, expansion joints, hoses, well sufficiently to determine thoir method of activation or control, such as pressure differential, change in fluid or flow conditions, combination of pressure and flow, manual or remote control mechanisms. (k) Install a BOP assembly and well control system during workovor operations end before drilling below any casing string. The IIOP assembly and well control system must be capable of controlling any well -head pressure that may ho encountered while that BDP assembly end well control system are on the well. (1) Equip all manifolds (headers) with check valves on individual Bowlines. (rn) Equip the Bowline with a high pressuro sensing device and shut-in valve at the wellhead if the shut-in welt pressure is grouter than the working pressure of die Bowline and manifold valves up to and including the header valves. Alternatively you may provide a pressure relief system for Bowlines. (n) Protect all piping appurtenant to the facility from corrosion, such as with protective coatings or cathodic protection. (o) Adequately protect sub -merino piping appurtenant to the facility against environmental stresses and Other activities such as fishing operations, (p) Maintain sub-morino piping appurtenant to the facility in good operating condition at all times. You :must periodically and according to n schedule inspect or test such piping for €eilures, You must document and keep a record of such inspections or tests at tho facility. 5. Part 112 is emended by designating §§ 1 12.2 0 and 11221 as subpart D, and adding a subpart heading as follows: Subpart i3—Response Requirements Sec. 112.20 Facility response plans. 112.21 Facility response training and drills/ exercises. Subpart t3—Rosponso Requirements Section 112.20 is amended by revising the first sentence of paragraph (h) to read as follows: § 112.20 Facility response pians. • . • A 0 (h) A response plan shall follow the formal of the model facility -specific response plan included in Appendix F to this part, unless you have prepared an equivalent response plan acceptable to the Regional Administrator to mad Siete or other Federal requirements. • " • • • • 47152 Fedora/ Register! Vol. 67, No. 1371 Wednesday, July 17. 2002 / Rules and Regulations Appendix C-1AmendedJ 7. Appendix C of part 112 is amended by: . Revising the first sentence of section 2.1; and b. Revising the title and first sentence of section 2.4. Appendix C to Part 112 ---Substantial Alarm Criteria 2.1 Nott-Trarrsporlolion- lolnted Facilities With a Total Oil Storng Capacity Greater Than or Equal to 42,000 Gallons Where Operations include Over -Water Transfers of Oil A Ran-tninsportation•rolatud facility with a total ail storage capacity greeter then or equal to 42,000 gallons that transfers nil over water to or from vessels must submit a response plan to EPA. " ' ' • • • • 2.4 Proximity to Public Drinking Water intakes at Facilities with a Total Oil Storage Capacity Greater than or Equal to 1 Million Gallons A facility with a total oil storage capacity grantor than or equal to 1 million gallons must submit its response plan if it is located at a distance such that a discharge front the facility would shut clown n public drinking water intake, which is analogous to a public water system as described al 40 CFR 143.2(0. i • Appendix D--1Atnnndndl 8. Appendix D of part 112 is amended by revising footnote 2 to section A,2 of Part A to rend as follows: Appendix 11 to Part 112--Oaturrninntion of n Worst Casa Discharge Planning Volume • . • • • Pert A • • • A.2 Secondary Centaininont—Muitlple-'Tank Facilities • . . • Secondary containment is described in 40 CFR part 112, subparts A through C. Acceptable methods end structures fur containment ora also given in 40 CFR 112.7{r.)(1 J. . • 1 Appendix F—IAnteiirietil 9. Appendix 1,` of part 112 is amended by: a. Revising section 1.2.7; b, Revising the second and lest sentences of section 1.4.3; c. Revising paragraph (7) and the undesignated paragraph and NOTE following paragraph (7) in section 1.7.3; d. Revising section 1.8.1; 0. Revising the first two sentences of section 1.11.1.1. introductory text; f. Revising the next to tho last sentence of section 1.8.1:3; g. Revising the next to last sentence of section 1,10.; h. Revising paragraph (0) of section 2.1; 1. Remove the acronym "SIC" In section 3.0, and add in alphabetical order the acronym "NAICS": and. j. Remove the reference to "Standard Industrial Classification (SIC) Code" in Attochnient F--1, General Information, and add in In alphabetical order a reference to "North American Industrial Classification System (,NAICS) Code." 'fife revisions road as follows: Appendix F to Part 122--Facility-Specific Response flan • • • 1.2.7 Current Operation tirlefIy describe the facility's opnrations and include the North American Industrial Classification System (NAICS) code. • 4 • * • 1.4.3 Analysis of the Potential for an Oil Discharge " ' This analysis shall incorporate factors such as ofI discharge history, horizontal range of a pocenitol discharge. and vulnerability to natural disaster. end shall. es appropriate, incorporate other factors such es tank ago. • • ' The owner or operator may need to research the age of the tanks the oil discharge history si the fncillty. A • • • • 1.7.3 Containment and Drainage Planning • . • • (71 Other cloanup materials, In nddiiion, a facility owner or operator rnust moat the inspection end mrinituring requirements for drainage contained in 40 CFR part 112. subparts A through C. A copy of 010 containment and drainage pians that ern required In 40 CFR part 112, subparts A through C may he inserted in this section, Including ony diagrams in those plans. Note: 'Tho general permit for storrnwnter drainage may contain additional requirements. * • • 1.11.1 Facility Self-lnspeclion Under 40 CFR 112.7(e), you MUM include the written procedures and records of inspections for each facility in 010 SPCC Plan. You must Include the inspection records for each container, secondary containment. end item of response equipment at the facility. You must cross• reference the records of inspections ofeach container and secondary containment required by 40 CFR 112.7(ai In the facility response plan. The Inspection record of response equipment is a new requirement in this pion. Facility self -inspection requires two -stops: (1) a checklist of things to Inspect; and (2) a method of recording tiro actual inspection and Its findings. You must note the date clutch inspection. You must keep facility response plan rocurds for five years. , You must keep SPCC records for three years. • • R • • 1.8.1.1. Tank inspection The tank inspection checklist presented below has neon included as guidance during inspections and monitoring. Similar requirements exist In 40 CFI part 112, subparts A through C. ' • • • • • • 1.8.1.3 Secondary Containment inspection • • . • • Similar requirements exist in 40 CFR part 112, subparts A through C. • ' • • • • * 1.10 Security According to 40 CFR 112.7(g) facilities are required to mointntn o certain level of security. as appropriate. • • ' . . . A * 2.1 General Information * • • • • (eJ North American industrial Classification System (NAICS) Code: Enter Ilan facility's NAICS code as determined by the Office of tvfanegenrent and Budget {this information may bo obinined from public library resources., ' 4 * . * .7.0 Acronyms NAICS: North American industrial. Classifit ntlon System ▪ • Attne:hrnonls to Appendix F Attachment F -1 ---Response Nen Custer Shard A • • R • Gemara! information • * • • • North American Industrial Clnssibcntion System (NAICS) Code: 4 4 A . (FR Dec. 02--16052 Piled 7-16-02; (1:45 arnl 0ILLING CODE 6SC6-5e-P • • • Federal Register/Vol. 67, No. 137/Wednesday, July 17, 2002/Ruins and l<ogulations uiu,r3 SUMMARY OF MAJOR REVISIONS TO THE CURRENT SPCC RULES Current SPCC rule Revised SPCC rule Comment Section 112.1: General Applicability • § 112.1(b): Explains that the SPCC rule applies to owners or operators of facililfes that drill, produce, gather, store, process, refine, trans- fer, distribute, or consume oil and oil prod- ucts, and might reasonably be expected to discharge oil In harmful quantities Into or upon navigable waters of the United Stales or adjoining shorelines. § 112.1(d)(2)(i): Section 112.1(d)(2) exempts from the rule a facility which meets both cri- teria specified In §112.1(d)(2)(1) and (il). The first criterion, found In § 112.1(d)(2)(1) is: the completely buried storage capacity of the fa- cility Is 42,000 gallons ar less of oil, The threshold eppties to storage capacity con- tained In operating equipment as well as lo storage capacity contained In tanks. § 112.1(d)(2)(II): The second criterion, found In § 112,1(d)(2)(II) Is: the storage capacity, which is not buried, of the facility is 1,320 gatlkne or less of oil, provldad that no single container has a storage capacity of greater than 550 gallons, The threshatd applies to storage capaclly contained In operating equipment as well as to storage capacity in containers, § 112.1(b): Explains that the SPCC rule ap- plies to owners or operators of (aclfities that drill, produce, gather, store, process, refine. transfer, distribute, use, or consume oli and oll products, end might reasonably be ex- pected- t0 discharge oil fn quantities that may be harmful Int] or upon navignbla wa- ters of the Untied altos or adjoining shore- lines, or waters of the contiguous zone, or in cohnaotlon with activates under the Cuter Continental Shelf Lands Act or Deepwater Port Act, or affecting ceriafn :neural re- sources, 112.1(d)(2)(1): Section 112.1(d)(2) exempts from the rule a facility which meets both cd - feria specified in § 112.1(d)(2)(1) and (14). The first criterion, §112.1(d)(2)(1) is: the completely buried storage capacity of the facility is 42,000 gallons or loss of oil. For purposes of ibis exemption, the completely burled storage capacity of a facility does not Include the capacity of completely hur- led tanks, as defined In § 112.2, that are currently subject to alt of the lechntcal re- quirements of 40 CFR part 280 or all of the technical requirements of a Slate program approved under 40 CFR part 281. Also, the completely hurled storage capacity of a fa- cility does not include the capacity of cam- pfetely burled tanks the' are "permanently closed," as defined In § 112.2. The thresh- old applies to storage capacity contained In operating equipment es well as to storage capacity contained In tanks. § 112,1(d)(2)(t1): The second creerian found in § t12.1(d)(2)(I1) is: the aboveground storage capacity of the racillty Is 1.320 gallons or less of cll. For purposes of this exemption, only containers of oil with a capacity of 55 gallons or greater ere counted. The above- ground storage capacity of a fadAty dogs not include the capacity of containers that are "permanently dosed," as defined in 112.2. The threshold applies In storage ca- pacity contained in operating equipment as well as to storage capacity to containers. §11 fd)(4): No counterpart fn current rule § 112.1(d)(4): Exempts from the SPCC re• qulrements completely burled storage tanks, as defined in § 112.2, as wet! as con- nected underground piping. underground ancillary equipment. and containment sys- tems, when ouch tanks aro sublect to all of the technical requirements of 40 CFR part 280 ar a Slate program approved under 40 CFR part 2111, except [hat such tanks must be marked on the facility diagram es re- quired by §112.7(a)(3), If the facility is oth- erwise subject to this part. § 112,1(d)(5): No counterpart In current rule § 112.1(d)(5): The revised rule exempts cart - trainers with a storage capacity of foss than 55 gallons of alf (nen all SPCC require- ments. §112.1(b): The revised rule clarifies that users of oil aro also subject to the rule. II also expands the scope of the rule 10 can- farm with the expanded jurisdiction in the amended Clean Water Act. §112.1(d)(2)(1): The revised rule provides that completely buried tanks subject to all of the technical requirements of parts 280 or 281 do not count in the calculation of the 42,000 gallon threshold. It also clarifies that perma- nently closed tanks do not count In the cal- culation of That threshold. The threshold continues to apply to storage capacity con- tained in opereltng equipment as well as to storage capacity contained in tanks. § 112.1(d)(2)01)i Tho revised rule raises the threshold for aboveground storage capaclly by eliminating the provision hat triggers the requirement to prepare and Implement en SPCC Plan if any single container has a capacity greater than 660 gallons, II main- tains the greater Than 1,320 gallon thresh- old, The revised rule also establishes a de rnlnlxuts container capacity size to calculate aboveground .storage capacity. Only con- tainers wltls a capacity of 55 gallons or greater are muffled In the calculation of aboveground storage capacity. The revised nrlo clarifies that permanently closed con- lainerS do not count In the calculation of aboveground storage capacity. The thresh- old continues to apply to storage capacity contained In operating equipment as well as lo storage capacity In containers. §112.1(d)(4): Completely burled storage tanks subject In all of the technical requirements of 40 CFR pad 200 or a Slate program ap- proved under 40 CFR part 281 aro no longer required to comply with SPCC provi- sions, except for the facility diagram. EPA estimates that under lhf: new rule, most gasoline service stations will drop out of the SPCC program. §112.1(d)(5): in response to comments, EPA has established a minirnum size oantainer for purpaees of the rogufatery threshold. Containers with a storage capadty of less teen 55 gallons al oil are exempt from all SPCC requirements. 47044 Federal Register/Vol. 67, No. 1371 Wednesday, July 17, 2002/Rules and Regulations SUMMARY OF MAJOR REVISIONS TO THE CURRENT SPCC RULES—Continued Current SPCC rule Rrivised SPCC rule Comment §112,1(h): Explains that the SPCC rule applies to owners or operators of facllilles That drill, produce, gather, store, process, refine. trans- fer, dlslribule,. or consume oil and oil prod• ucls, and might reasonably be expected to discharge elf In hamifuf quantilles into or upon navigable waters of the United Stales or adjoining shorelines. §112.1(d)(2)(1): Seaton 112.1(d)(2) exempts from the rule a facility which meets both cri- lona spedfled In §112.1(d)(2)(1) and ([1). Tha first criterion, found In 5112.10)(2)M Is: Ille completely buried storage capacity of tae fa- cility is 42,000 gallons or tess of oil. The threshold reviles to storage capacity con- tained In operating equipment as well as to storage capacity contained In tanks. §112.1(d)(2)(11): The second criterion, lound In §112.1(d)(2)(10 Is: the storage capacity, which Is not buried, of the facility Is 1.320 galions or less of oft, provided that no single container has a storage capacity of greater than 660 gallons. The threshold applies to storage capacity contained In operathlg equipment as well ae lo storage capacity in containers. §112.1(d)(4): No counterpart In current Hole §112.10)(5): No counterpart in current rule §112.1(b): Explains that the SPCC rule ap- plies to owners or operators of facilities that drift, produce, gather, store, process, refine,. transfer. -distribute, use, or consume ell and oil products, and might reasonably be ex- pected to discharge 011 In quentflles That may be harmful into or upolr navigable wa- ters of the United States or adjoining shore- lines, or waters of the contiguous zone, or In connection with activities under the Cuter Continental Shelf Lands Act or Doepwater Port Act, or affecting certain natural re- sources. §1112.1(d)(2)(f); Section 112,1(d)(2) exempts from the rote a facility which meals both cri- teria specified In §112.1(d)(2)(1) and (II). The first criterion, §112.1(d)(2)(l) is: the completely buried storage capacity of the facility -1s 42,000 gallons or less of oil. For purposes of this exemption, the completely burled storage capacity of a facility does not Incudo tho capacity of completely bur- ied tanks, as defined In §112.2, that are currently subject to all of the technical re- quirements of 40 CFR part 250 or all of the technical requirements of a State program approved under 40 CFR part 281. Also, the completely buried storage capacity of a fa- cility does not Include the capacity of com- pletely burled tanks that are "permanently closed," as defined In § 112.2. The thresh - aid applies to storage capacity contained In operating equipment as well as to storage capacity contained in tanks. §112.1(d)(2)(11): The second criterion found In § 112.1(4)(2)(11) Is: the aboveground storage capacity of the facility is 1,320 gallons or less of oil. For purposes of this exempllun, only containers of oil wllh a capaclly of 55 gallons or greater are counted. The above- ground storage capacity of a fadllty does not Include the capacity of containers that ars "permanently closed," as defined In 112.2. The threshold applies to storage ca- pacity contained in'operattng equipment as well as to storage capacity In containers._ §112.10)(4): Exempts from the SF'CC re- qufromnnts completely buried storage Tanks, as defined In § 112.2, as well es con- nected underground piping, underground ancillary equipment. and containment sys- tems, when such tanks erre subject to all of the technical requirements of 40 CFR part 200 or a Stale program approved under 40 CFR part 281, except thnt such tanks must tra marked on the facility diagram as re- quired by §112.7(a)(3), if the facility Is oth- erwise subject to this part. § 112.1(d)(5): The revised rule exempts con- tainers with a storage capacity of foss than 55 gallons of 011 from all SPCC require- ments, §112.1(b): The revised rule clartlias That users of elf aro also subject to the rule. ft also expands the scope of the rule to Con- form with the expanded jurisdiction in the amended Clean Water Act. §112.1(d)(2)(1): The revised rut° provides that completely burled tanks subject to alt of the technical requirements of pans 280 or 281 do not count In the calculation of the 42,000 gallon threshold. It also clarifies that pemaa- n©ntly closed tanks do not count In the crit- euiagon of That threshold. The threshold continues lo apply to storage capacity con- tained in operating equipment as wall as In storage capacity contained in tanks. §112.1(d)(2)(It); The revised rule raises the threshold for aboveground storeue capacity by eliminating the provision that triggers the requirement to prepare and Implement an SPCC Plan if arty single container has a capacity greater than 660 gallons. It main- tains the greater Than 1,320 gallon thresh- old. The revised rule also establishes a de minlmis container capacity size to calculate aboveground storage capacity. Crtfy con- tainers with a capacity of 55 gallons or greater are counted In the calculation of aboveground storage capacity. The revised tufa clarifies chat permenonuy dosed con- tainers do not count in the calculation of aboveground storage capacity. The thresh- old continues to apply to storage capacity contained In operating equipment as well as to storage capacity in containers. §112.1(d)(4): Completely burled storage tanks subject to all of the technical requirements of 40 CFR part 280 or a State program ap- proved under 40 CFR part 281 are no longer required to comply with SPCC provi- sions, except for the fecilly diagram. EPA estimates That under this new rule, most gasoline service Matrons will drop out of the SPCC program. § 112.1(d)(5): in response to comments. EPA has established a minimum size conlalner for purposes of the regulatory threshold. Containers with a storage capealy of less lhan 55 gallons of oil are exempt frorn all SPCC requirements. Federal Register/Vol, 67, No, 137/Wedn day, July 17, 2002 /Rules and Regulations 47045 SUMMARY OF MAJOR REVISIONS TO THE CURRENT SPCC RutEs—Continued Current SPCC nrle Revised SPCC rule Cornmeni. §112.1(d)(6): No counterpart In current rule §112.1(1): No counterpart In current rub ._»..... §112.1(d)(6): Exempts any facility or part thereof from the rule, If used exclusively (or wastewater treatment and not used lo meet any otter requirement of pan 112. The pro- duction, recovery, or recycling of oil Is not wastewater treatment for purposes of this paragraph. § 112.1(0: Notwithstanding any regulatory ex- emptions, the Regional Administrator may require that the owner or operator of any fa- cility subject la EPA jurisrectfon under sec- tion 311(J) of the Clean Water Act (CWA), prepare and implement an SPCC Plan, or any applicable part, to carry out the pur- poses of the CWA. The rule includes notice and appeal provisions. §112.1(d)(6): A facility or part thereof used exclusively for wastewater treatment will no longer ba subject to prevention planning un- less It is used to meet part 112 roquire• merits. 5 112.140: This amortdmeni gives the Re- gional Administrator authority to require preparation of an entire SPCC plan, or ep- p!icabie part, by an owner or operator of a facility exempted from SPCC requirements when it becomes necessary fo achieve the purposes of the CWA, This authority wilt he exercised on a case-by-case basis. The de- cision to require a Plan could be based on the presence of environmental concerns not adequately addressed under other regula- tions, or other relevant environmental far.• tors, far example, discharge history. Section 112.2—Definitions 5112.2—definition of facility.' No counterpart In current rule. § 112.2—definition of lecNlfy: "Facility" is de- fined as any mobile or fixed, onshore or off- shore building, structure, instaftelion, equip- ment, pipe, or pipeline Used in oil well drill - Ing operations, oil production, oil refining, oil storage, oft riaihering, oli transfer. oil dis- tribution, and waste treatment, or in which oil is used.. . §112.2--deflnitlon of facility: The revised rule clarifies that a taclltty may be as email as n piece of equipment, for example, a tank, or an largo as a military base. Section 112.3: Requirement to prepare and Implement Spill Prevention, Control, and Countermeasure Plan §112'.3(a): An owner or operator of an onshore or offshore facifily In operation on or before January 10, 1974, that leas had a discharge to navigable waters or adjoining shorelines, or, dun to lis location, could reasonably bo expected to have a discharge to navigable waters or adjoining shorottnes, must prepare and rutty implement an SPCC Piarr, in writing and In accordance with § 112.7. The owner or operator must prepare the Plan within 6 months, and fully Implement 11 as soon es possible, but not later than within 1 year. §112.3(b): The owner or uperalor of an on- shore and offshore tacitly that becomes operational atter January 10, 1974, and That has had a discharge to navigable waters or adjoining shorelines, or could reasonably bo expected to have a discharge la navigable waters or adjoining shorelines, must prepare an SPCC Plan. Unless the owner or operator is granted an extension of time lo prepare and implement the Plan by the Regional Ad- ministrator, he roust prepare the Plan within 6 months anti fully Imptamenl it as son es pos- sible, hut not later than within 1 year. § 112.3(a): An owner or aperulor (010) of an onshore or offshore facility in operation on or before August 16, 2002, that has had a discharge as described in § 112.1(b), or, due to its location, could reasonably be ex- pected to have a discharge as described In §112.1(b), must prepare a written Plan In accordance with § 112.7 and any other ap- plicable section w]Ihin 6 months of the ef- fective dale of the rule, and implement ll ns soon as possible, but not later Than within 1 year of Ihu effective date of the rule. The 0/ 0 of facility that becomes operaltonal after August 16, 2002 through August 18, 2003 must prepare end Implement a Plan not later than August 18, 2003. § 112.3(b): The owner or operator of an on- shore or offshore facility that becomes operational after August 18, 2003, and could reasonably be expected to have a discharge as described in §112.1(b), from that facility, must prepare and Implement an SPCC Plan before beginning oparaltons, §112.3(a): For those facilities already in oper- ation on the effective date of the rule, an owner or operator of a facility subject lo the rule most prepare an SPCC Plan within the current little frame of six months. He may lake up to un additional six months to im- plement the Plan. The revlsed rule extends Ihle same time frame to amendments nec- essary to bring the Plan into compliance watt rule revisions. An owner or operator of a ladiity becorning operational after August 16, 2002 through August 18, 2003 must prepare and implement a Plan not later than August 18, 2003. §112.3(b): Tho owner nr operator of a facility that becomes operational attar August 18, 2003 must now prepare and implement an SPCC Plan before beginning operations. The lime frame In the current rule is up to 6 months for Plan preparalton and up to 6 months mord for Plan implementation. 47046 Pederal Register/Vol. 67, No. 137/Wednesday, July 17, 2OO2/Rules and Regulations SUMMARY OF MAJOR REVISIONS TO THE CURRENT SPCC RuLEs—Conifnued 14111 Current SPCC rule • Revised SPCC rule Comment 112.3(d): No SPCC Plan Is effective to satisfy the requirements of the SPCC rule unless lI has been reviewed and certified bye Reg- istered Professional Engineer (PE), By means of this certification the PE, having ex- amined the facility and being familiar with the provisions of the SPCC rule. attests thal the SPCC Plan hes been prepared in accord- ance with good engineering practices. The PEs certification does not relieve the owner or operator of an onshore or offshore facility of his duty to prepare arid fully Implement the Plait In accordance wen all applicable ra- qutremenis. §112.3(e): An owner or operator of a facility for which an SPCC Plan is required must main- tain a complete copy of the Plan at the facil- lty if the facility is attended es toast 8 hours per day, ar al the nearest field office tf the fa- cility 1s not so attended, and must melte the Plan available to Iha Regional Administrator for on-site review during normal working hours. § 112.3(1): The Regional Administrator may au- thorize an extension of time for the prepara- lion and implementation of an SPCC Plan, when he finds that the owner or operator canna' comply with all SPCC requirements as a result of either nonovalialilitly at quali- fied personnel. or delays In construction or equipment delivery beyond his control and without his fault, or the fault of his agents or employees. The rule also specifics what Ute leiter requesting art extension must contain. § 112.30): No SPCC Plan Is effective to sat- isfy the requirements of the SPCC Tula un- less It has been reviewed and certified by a PE. By means of this certification the PE al - tests that: (I) he is familiar with the require- ments of the SPCC rule; (11) he or his agent has visited and examined the facility; (HI) the Plan has boon preparers in accordarice with good engineering practice, including consideration of applicable Industry stand- ards. and with [ha requirements of the SPCC rite; (Iv) procedures for required In- spections and testing have been estab- lished; and, (v) Ihe Plan is adequate for the facility. The PE's certification does not re- lieve the owner or operator of an onshore or offshore facility of his duty Io prepare and fully Implement the Plan in accordance with all appttcable requirements. § 112.3(e): An owner or operator of n facility for which an SPCC Plan Is required must maintain a complete copy of the Plan at the facility if the facility is attended at least 4 hours per day, ar at the nearest Geld office if the faclllty Is not so attended, end must make the Plan available to the Regional Administrator for on-site review during nor- ms! working hours. 112.3(0: The Regional Administrator may authorize en extension of lime for the prep - oration and Implomentallon of an SPCC Pian, or any amendment thereto, When he finds Out the owner or operator cannot comply with all SPCC requirements as a m- aul! of either nonavallablllly of qualified per- sonnel, ur delays In ronstruc'ton or equip- ment delivery beyond his conlrol and with- out his fault, or the fault of his agents or employees. The rule also specifies what the letter requesting nn extension must oanlain. §112.3(d): The revised rule adds speclfrdty to the PE's attestation. The specificity Includes a requirement that the PE consider applica- ble industry standards and certify that the Pian Is prepared in accordance with part 112 requirements. Presently, the PE must attest only that Ihe Plan has been prepared In accordance with good engineering prac- tice. The revised rule aitows an agent of the PE to visit and examine the facility In place of Ihe PE, but the PE must review the agent's work, and certify the Nen, §112.3(e): The revised rule requires the facii- Ily owner or operator to maintain a copy of the Plan at the facility if It is attended at least 4 hours a dey, In contrast lo the cur- rent requirement lo maintain 11 at the facility Ii it Is allonded at least b hours a dny. §112.3(1): The revised rule provides for exten- sion for amendments of the Plan, as well as the entre Pier. Section 112.4: Amendment of Spill Praveniton, Control. and Countermeasures Plan by Regional Administrator §112.4(a): Whenever an SPCC facility has: (1) discharged more Pion 1,000 U.S. gallons of all into or upon the navigable waters of the United Slates or adjoining shoreliries In a sin- gle discharge to ravlgahle waters or adjoin- ing shoretlnes, or (2) discharged oil in harm- ful quantities, as defined in 40 CFR part 110, into or upon the novlgnble waters of the United States or adjoining shorelines In each of 2 discharges to navigable wales or adjoin- ing shorelines, reportable under section 311(tr)(5) of the Clean Water Act, within any 12 -month period, the owrier or operator of Ilia facility must submit to the Regtcnrtl Ad- ministrator (RA). within 60 days from the time Ihe facility becomes subject la this section, 10 different Items of Information, plus addi- tional Infomtalton pertinent to isle Plan If the RA requests II. § 112.4(b): Section 112.4 does not apply until the expiration of the dins metaled for the preparation and Implementation of the Pion under § 112.3. § 112,4(a): Whenever an SPCC facility has: (1) discharged more Man 1.000 U.S. gal- lons of oil in a single discharge es de- salted In §112.1(h), or (2) discharged more then 42 U.S. gations of oil, es de- scribed In §112.1(b), in each of 2 dis- charge, within any 12 -month period. the owner or operator of the facility must submit to the R.A. within 00 days from the Lima the facility becomes subject to this section, 8 different Items of Information, plus addi- tional information pertinent to the Plan if the RA requests Il. § 112.4(b): Section 112.4 does not apply until the expiration of the time permitted for the preparation and implementation of the Plan under §112.3. § 112.4(a): Wu have revised the geographic scope of Elie rule In accordance with the GWA amendments, by using the phase "discharge as described In § 112.1(b)." We also raised the threshold fur reporting two discharges na described in §112.1(b), from a "reportable" quantity under the Clean Water Act, to n Threshold of more tree 42 U.S. gallons, or 1 barrel. In each of those discharges. Tho 1,000 gorion threshold for a single discharge as descrlbed in §112.1(b) remains unchanged. We also re- duced the amount of information Chet must ntlrrhnatly bo subeitted to Tho RA. §112.4(b): Section 112.3 In Ute revised rule allows marc llrne for some facilities for preparation and Implementation of a Plan, or any amendments !hereto, titan In the 1991 proposed rule. Therefore, the imple- mentation of the requirements of §112.4 is postponed until the new time frames In §112.3 hove passed. Federal Register/Vol. 67, No. 137/Wednesday, July 17, 2002/Rules and Regulations 47047 r.. SUMMARY OF MAJOR REVISIONS TO THE CURRENT SPCC Rul_l=s--Continued Current SPCC rule RelAsed SPCC rule Comment §112.4(c): The owner or operator Is required to §112.4(C): The owner or operator Is required § 112.4(c): The revised nhfa changes the re - provide the same information he provided to to provide the same Information he pro- quirement from nolilfcallon to the Stale EPA, under §112.4(a), to the Slate agency In vlded lo EPA, under § 112.4(a), to the Slate agency In charge of water pollution ccnlrol charge of water pollution control activities In agency In charge of oil pollution control ac• activities In notification to the Slate agency and for the Stale to which the facility Is lo- %ales In the Slats In which the facility is to- In charge of oil pollution control Activities. sated at the same time he provides 11 io EPA. cated al the same lime he provides It to There may be more than one such agency After receiving' that Information, the State EPA. After receiving that information, the In some States. agency may conduct a review and make roc- Stele agency or egendes may conduct a ommendations to the Regional Administrator review and make recommendntlons to the es to further procedures. methods, equipment Regional Administrator as to further orrice - end other requirements for equipment nec- dares, methods, equipment and ether re- essary to prevent and to contain discharges qutrements for equipment necessary to pre - of oil from the facility. vent and to contain discharges of oil from the facility. § 112.4(d): This section allows the Regional Ad- §112.4(d): This section allows the Regional § 112.4(d): The revised rule provides that the minisirator to require a factlily owner or aper- Administrator to require a facility owner or Regional Administrator may require Plan alar to amend his Pian after review of mate- operator to amend his Plan after review of .amendment after on-site review of the Plan. reals iha owner or operator submits under materials the owner or operator submits 5112.4 (a) and (c). under § 112.4 (a) and (c), or after on-site review of the Plan. Section 112,5: Amendment of Spill Prevention, Control, and Countermeasures Pian by owners or operators §1112.5(b): This section requires an owner or operator to review his Plan at feast every 3 years from the date a facility becanhes sub- Joct to the SPCC rule. As result of this re- view and evaluation. the owner or operator must amend the SPCC Plan within 6 months of the review to indude more effective pre- veniton and control technology If: (1) Such technology wit significantly reduce the likeli- hood of a discharge to navigable waters or adjoining shorelines from the facility; and (2) if such technology has been field -proven at the lime of the review. §112,5(c): This section roqutres that a Profes- sional Engineer certify any amendments to an SPCC Plan. S§ 112.5(h): This section requires an owner or operator to re low his Plan at least every 5 years from the date a facility becomes sub. Jeri to the SPCC nate; nr for an existing fa- cility, b years from the date the fast review was required under this part. The owner or operator muse amend the SPCC Pian wilitin 6 months of the review to Include more ef- fective prevention and control technology if: (1) Such technology will significantly reduce the likelihood of a discharge as described In §112.1(b) from the facility; and (2) if such technology has been field -proven at the time of the review. Implementation of amendments Is required within 6 months following amendment. Tho owner or oper- ator must document completion of the re- view and evaluation, and must sign a state- ment as to whether he will amend the Pian, either at the bean ntng or end of the Plan or In a tog or an appendix to the Plan. The fol- lowing will suffice, "1 hove completed review and evaluation of the SPCC Plan for (name of facithy} on (dale), end will (will not) amend the Plan as a result," 112.5(c): This section requires that a Profes- sional Engineer certify any technical amendments In an SPCC Plan. §112 51b) The revised rule changes the pe- riod of review for SPCC Plans from 3 to 5 years. 11 also requires documentation of completion of the review and evaluation, §112.5(c): The revised ruts clarifies that e Professional Engineer must certify only technical amendments, PE certification Is not required for non-Iochnlcal amendments, like changes to phone numbers, names,. etc. Section 112.7: Spill Prevention, Control, and Countermeasure Pion general rertuirements. We have reorganised § 112.7 of the current regutallon Inti §§112.7, 112 8, 112.9, 112.117, 112,11, 112.12, 112.13, 112.14, and 112.15 of the final rule based on facility type and type of ail. 47048 Federal Regis' r/Vol. 67, Na. 137 /Wednesday, July 17, 2002 /Rules and Regulations SUMMARY OF MAJOR REVISIONS TO THE CURRENT SPCC RULES—Contir3ued Current SPCC rule Revised SPCC rule Comment § 112.7: This section specifies Mel a Plan must be prepared in accordance with good engi- neering practices, and hove the full approve! of management et a level with authority la commit the necessary resources. The SPCC Pion must follow the sequence specified In this rule, and include a discussion of the fa- cility's conformance with the requirements of the nip. §112.7(a)(2): No counterpart In current ruts §112,7(a)(3): No counterpart in current rule §112.7(c): This section is the general provision requiring secondary containment. §112.7(d): When It is not practicable to Install secondary containment al your ladllty, this section requires That you explain why and provide o strong oil spill contingency plan In your SPCC Plan. The contingency pian must follow the provisions of 40 CFR part 103. You must also provide in your SPCC Plan a written comrtiltmonl to manpower, equipment and rentertats required to expeditiously con- trol and remove any harmful quantity of oil discharged. §112.70)(0): This section requires that the owner or operator conduct required Mose- lions in accordance with written procedures devetaped for lite facility. The owner or oper- ator must maintain these written procedures and a record of Inspedlorrs, signed by the appropriate supervisor or respecter. as part of the SPCC Plan, and maintain ihenr for a pe• dud of 3 years. §112.7: This section specifies Thal a Plan must he prepared In accordance with good engineering prectices, and have the full ap- proval of management el a level with au- thority to commit the necessary resources. The SPCC Plan must follow the sequence sped:led In the rule, and Include a discus- sion of the facility's conformance with the requirements of the rule, if you do not fol- low the sequence specified In the rola, you must prepare en equivalent prevention Plan acceptable to the Regional Administrator that meets all applicable requirements, and you must supplement It with section cross- referencing the location of requirements list- ed In the SPCC rule to the equivalent re- quirements In the other prevention plan. §112.7(a)(2): This provision explicitly allows deviations from most of the rule's 'sub- stnnttve requirements (except for secondary containment requirements), provided that you explain your reasons for nonconform- ance with the requirement, and provide equivalent environmental protection with ars allemale measure. if the Regional Adminis- trator delemtlnes that the orientate measure described In your Plan does not provide equivalent pretecllon, he may require that you amend the Plan. §112.7(a)(3): This section requires a facility owner or operator to describe the physical layout of the facility end include a facility diagram In the Plan. § 112.7(c): This section is lire general provi- sion requiring secondary containment. § 112.7(d): When It Is not practicable to Install secondary containment at your facility, this section requires that you explain why and provide a strong oil spill contingency pian In your SPCC Men. The contingency pian must follow the provisions of 40 CFR part 109. You must oleo provide in your SPCC Plan a written commitment to munpower, equipment and materiels required to expo dlllously control and remove any quantity of oil discharged that may be harmful; conduct periodic integrity testing of the containers; end, conduct periodic Integrity end leak lasting of the valves end piping. 112.7(e): This section requires that the owner or operator conduct required inspec- tions end tests In accordance with written procedures developed by him or by the cer- tifying engineer for the facility. The owner or operator must maintain these written proce- dures arid a record of inspections and rests, signed by the appropriate supervisor or in- spector, with the SPCC Plan, and maintain them for e period of 3 years; Records of In- speclions and tests kept pursuant to usual and customary business practices are suffi- cient for purposes of the rule. §112,7: The revised rule allows differing for- mat for the Plan, other than the one formal now specified. While you may use the for- mal specified in the rule, you may also use other formals, such as Siete plans, inte- grated Contingency Plans, and any other formals acceptable to the Regional Admin- istrator. If you use another format, you must crass -reference its previsions to the require- ment listed In the SPCC rule. Also, if you use another format, you must ensure that the formal includes nil applicable SPCC re- quirements, or you must supplement (hal fennel to include all applicable SPCC re- quirements. §112.7(a)(2): The revised rule explicitly nttows deviations from most of the rule's sub- stantive requirements (except for secondary containment requirements), ,provided ihol you explain your reasons for nonconform- once with the requirement, and provide equivalent environmental protection with an alternate measure. If the Regional Adminis- trator determines that the alternate measure described in your Plan does not provide equivalent protection, he may require that you amend your Pian. §112.7(a)(3): The facility diagram must le - dude completely burled tanks exempted from other SPCC raquIrerrlants. § 112.7(c): The revised rule maintains the cur- rent standard that dikes, bemts, or retaining watts must be "sufficiently impervious" to contain oil. We withdrew the proposed standard that such secondary containment must be Impermeable for 72 hours. §112.7(d): The revised rule adds new require- ments for periodic integrity tenting of con- tainers, end periodic integrity and leak test- ing of valves and piping. We clarify that tf you have submitted a facility response plan under 012.20 for a fadllty, you need not provide fur that facility either a conlingency plan following tiro provisions of part 109, nor a written commitment of manpower, equipment, and materials required to expe- ditiously control and remove any quantity of oil dlschnrged that may be harmful, §112.7(e): The revised rule allows use of usual and customary business records to serve as a retxard of tests or inspections, In- stead of keeping duplicate records. It also allows the owner or operator to keep diose records as an appendix to the Plan, or in a separate log, etc., wall the Plan, rather than requiring Itrol those records be a part of the Plan. The rote also acknowledges that the certifying engineer, es well as the owner or opernlor, has a rote In the development of inspection procedures, Federal Register/Vol. 67, No. 1;37 /Wednesday, July 17, 2002 /Rules and Regulations 47049 SUMMARY OF MAJOR REVISIONS TO THE CURRENT SPCC Rut-ES—Canilnued Current SPCC rule Revised SPCC rule Cement §112.7(e)(10): The owner or operator of a fedl- Ity is responsible for properly Instructing per- sonnel to the operation and maintenance of equipment io prevent the discharges of oil and applicable pollution control laws, ones, and regulations. An owner or operator must designate a person at each facility who Is ac- countable for o!I discharge prevention and who reports to factiity management. An owner or operator must schedule and con- duct discharge prevention briefings tor oper- ating personnel at intervals frequent enough to assure adequate underelanding of the SPCC Plan for that faculty. Such briefings must highlight and describe known dis- charges to navigable waters or adjoining shorelines, or failures, malfunctioning compo- nents. and recently developed precautionary measures.. §112.7(f): The owner or operator of a facillly, at a minimum, rnust Crain oil -handling per - sonnet in the operation and maintenance of equipment to prevent the dlschertje of oil; discharge procedure protocols; applicable pollution control laws, rules, and regula- tions; general facility operations; and, the contents of the facility Pfan. An owner or operator must designate a person at each facility who Is accountable for oil discharge prevention and who reports to facility man- agement. An owner or operator must schedule and conduct discharge prevention briefings for oil -handling personnel at least once a year to assure adequate under- standing of the SPCC Plan far that facility. Such briefings must highlight and describe known dtschnrges as described In §112.1(b), ar failures, malfunctioning com- ponents, and recently developed pre- cautionary mensures. §112.7(f); The revised rule mandates training only for oli-handling employees, instead of all employees. it specifies additional topics for the training of these employees, tt also specifies that discharge prevention briefings must be conducted al least once a year, In- stead of at "Intervals frequent enough to assure adaqunte undrestanding of the SPCC Plan for that facility." 5112,7(f): No counterpart. In current rule §112.7(I): This section requires evaluation for field -constructed aboveground containers undergoing repair, alteration, reconstruction, or change in service That might affect the risk of a discharge nr failure due In fracture or other catastrophe. It also requires such evaluation when there hes actually been a discharge or failure due In Milne fracture or other catastrophe. §112.711): The brittle fracture requirement was triggered by Itle Ashland CI1 lank collapse In 1088 due to brittle fracture. Soclton 112.8: Requirements for onshore facllliles (excluding production facJlIIles). §112,7(e)(2)(111): This section establishes sub- stantive requirements for stormwater drain- noe from diked areas, and recordkeeping re- quirements for stoneware: bypass events. §112.70)(2)(1: This provision requires that aboveground containers he subject to peri- odic integrity testing. laking into account tank design (floating roof, etc.) and using such techniques es hydrostatic lusting, visual In- spection, or a system of noir-destructive shell Ihlckness testing. The owner or operator roust keep comparison records where appro- priate, and must include tank supports and foundations in these inspections. In addition, operating personnel must frequently inspect the outside of the container for signs of dete- norellon, teaks, or accumulation of all insldo inked areas. §112.8(c)(3): This section establishes sub- stantive requirements for stormwater drain- age from diked areas, and recnrdkeeping requirements for stormwater bypass events. The revised rule provides that records re- quired under permits Issued In accordance with the National Pollutant Discharge Eliml- nation Systems (NPDES) rules are suffl- clanl for recording slormweter bypass events, §112.8(c)(6): The revised rule requires That aboveground containers he tested for Integ- rity on a regutar schedule, and when mate- rial repairs are done. The frequently and type of testing must /eke Into accouni con- tainer size and design (floating roof, skid - mounted, elevated, partially burled. for ex- ample), The owner or operator must com- bine visual Inspection with another lasting technique such as hydrostatic testing, radio- graphic lashing, ultrasonic testing. acoustic emissions testing, or ether system of non- destructive shell testing. The owner or opor- alor must keep compartson records end must include lank supports and foundations In these inspecftone. In addition, nporating personnel must frequently inspect the out- strip of the container far signs of daierlara- tton, leaks, ar accumulation of oil Inside diked areas. Records of inspections and tests kept pursuant to usual and customary business practices are sufttdenl for pur- poses of the rule. §112.00)(3): Tho revised rule allows recarde required by NPi]ES permit regulations to record slormw,nter bypass events to be used for SPCC purposes In lieu of events records specifically prepared for purpose. 112.0(c)(5): The revised rule requires Thal an owner nr operator Zest aboveground conleiners for integrity on a muter sched- ole, and when material repairs are done. The rationale for adding a testing require- ment when material repairs aro done Is that materiel repairs might increase the potential for oil discharges. Usual and customary business records may be used for the pur- pose of Integrity testing, Instead of records spedflcaliy canted for this purpose. 47050 Federal Register/Vol. 67, No. 137 /Wednesday, July 17, 2002 /Rules and Regulations SUMMARY OF MAJOR REVISIONS TO THE CURRENT SPCC RULES --Continued Current SPCC rule Revised SAGO rule Comment §112.7(0)(3)(i). This section requires that bur- § 312.8(d)(1): This section requires that buried § 112.8(d)(1): The revised rule requlnss that led piping installations have prolective wrap- piping that k Installed or replaced on or all buried piping that is installed or replaced ping and coating and cathodic protection, if after August 18. 2002 must have protective on or after August 16, 2002 must have pm- soil conditions warrant. wrapping and coating and cathodic prolac- 'active wrapping artd coaling and cathodic tion, or otherwise satisfy the corrosion pro- proleclicn, or otherwise satisfy the oemo- tection provisions for piping In 40 CFR pari star protection provisions for piping In 40 280 or a State program approved under 40 CFR part 280 or a State program approved CFR part 281. under 40 CFR part 281, for all soil condi- tions. Section 112.9: Requirements for onshore oil production foci/Ries. § 112.7(e)(5)(!I): Ties section provides require- ments for stomrowalor drainage events, S112.7(05)011)(6): This section requires sec- ondary containment for onshore production facltllles. §112.9(b)(1): This section provides require- ments for etormwaler drainage events. §112.9(c)(2): This section requires secondary containment for onshore production facilities. §112.9(b)(1): The revised rule provides that records required by NPDES permit regula- tions are allowable to record stormwater by- pass events for SPCC purposes in lieu of records specifically generated for that pur- pose. §112.9(c)(2): The revised rule clarifies that the secondary containment must Include sufficient freeboard lo contain precipitation. July I5, 2005 Mr. Ram Seetharam Colorado Department of Public Health & Environment Air Pollution Control (Division Construction Permit Section, APCD-SS-B l 4300 Cherry Creek Drive South Denver, Colorado 80246--1530 Re: Modification to Permit No: 02GA0014, Modification -8 Parachute Creek Gas Plant, Garfield County, Colorado Facility ID: 045/03651999 Dear Ram: 0 IP EXPLORATION & PtuODuc-rtON Tower 3. Sure 1000 1515 Ar pahoc $trees Denver, CO 80202 303/572.3900 303/629-8282 Fax 41Wiiarns-7Prr+uction .RMT Company (Williams) plans to modify the Parachute Creek Gas Plant (PCGP) to add a third gas processing plant referred to as Planta Modifications associated with the new Plant 3 portion of the facility are discussed in detail below. A completed Application for Construction Permit or Permit Modification form and completed APENs for new sources are provided in Attachment 1. Proposed Modifications. Williams plans to install one additional 300 MMscf/day gas processing plant, Plant 3, at the PCGP. Regulated emission sources associated with the Plant 3 expansion include eight (8) compressor engines, one (1) process heater, one (1) amine sweetening unit, one (1) gas dehydration unit, one (1) process and emergency flare, one (1) thermal oxidizer, two (2) condensate storage tanks, one (1) exempt condensate loadout source, one (1) exempt NGL loadout source, and one (1) fugitive VOC from leaking equipment emission source. Specific emission sources are discussed below. Plant 3 Compressor Engines: Williams plans to install eight (8) residue gas compressor engines (Source ID: ENG -17 through ENG -24) at the Plant 3 portion of the facility. These engines will each be Caterpillar 3612 TALE, four cycle lean burn engines site rated at 3,210 horsepower and equipped with selective catalytic oxidation (SCO) emission control systems. Emissions from each unit are estimated at 21.7 tpy NO, 5.4 tpy CO, and 3.0 tpy VOC, based on emission factors of 0.7 gfbhp-hr NOx, 0.18 glbhp-hr CO, and 0.1 gfbhp-hr VOC. Completed APENs for ENG -17 through ENG -24 are provided in Attachment 1. Because these engines are subject to the 40 CFR 63 Subpart ZZY.7 RICE NESHAP, Williams is providing a completed Form 1 Initial Notification of MACT Applicability for engines ENG -17 through ENG -24 in Attachment 3. A completed Form 1-A Initial Notification - Identification of Emission Points that includes these emission sources is also provided in Attachment 3. Plant 3 Process Heater: Williams plans to install one (1) natural gas-fired process heater at the Plant 3 portion of the facility. The Plant 3 riot COI Neater (Source ID: 1 -ITR -3) will be rated at 60.0 'MMBtu/hr. Criteria and Non -Criteria Reportable pollutant emissions from this heater are estimated at 25.3 tpy NOx, 21.2 tpy CO, and 1.4 tpy VOC, based on AP -42 emission factors. A completed APEN for this emission unit is provided in Attachment 1. Because this heater is subject to the 40 CFR 63 Subpart DDD[) MACT for heaters/boilers, Williams will be providing a • • Mr_ Ram Seetharam CDPHE July i 5, 2005 Page 2 completed Form 1 Initial Notification of MACT Applicability under separate a cover letter next week. Plant 3 Amine Sweetening Unit: Williams's plans to install one (1) 150 MMscf/day amine unit associated with the Plant 3 portion of the facility (Source ID: AMINE -3). This unit will be used to remove carbon dioxide from the Plant 3 inlet gas. It will have a maximum amine circulation rate of 720 gallons per rninute. The flash tank overhead vapor stream from this unit will be routed to a new Plant 3 Process and Emergency Flare (Source ID: FLARE -3), and the amine still vent overhead vapor stream will be routed to a new Plant 3 Thermal Oxidizer (Source ID: TO -2) where VOC contained in this stream will be combusted. There will be no direct emissions to atmosphere from the Plant 3 amine sweetening unit. A completed APEN for this emission unit is provided in Attachment 1. Uncontrolled emissions listed on the APEN for this unit are based on the GRI AMINECaic computer model. Controlled emissions from this unit are reported in the FLARE -3 and TO -2 control device APENs provided in Attachment 1. A control efficiency of 96% is assumed for the process and emergency flare FLARE -3, and a control efficiency of 99.9% is assumed for the Plant 3 Thermal Oxidizer, as discussed below. Plant 3 Gas Dehydration Unit: Williams will install a new 300 MMscf/day ethylene glycol (EG) dehydration unit associated with the Plant 3 portion of the facility (Source ID: DEHY-4). It will receive a commingled stream comprised of 50.0% plant inlet gas and 50.0% sweet gas from the Plant 3 amine unit. The flash tank overhead vapor stream from the Plant 3 dehydration unit will be routed to a new Process and Emergency Flare (Source ID: FLARE -3) associated with the Plant 3 portion of the facility, and the regenerator still vent overhead vapor stream will be routed through a 120 deg. F condenser to the Plant 3 Process and Emergency Flare (SOURCE ID: FLARE -3). VOC contained in the dehydration unit still vent condenser overhead stream will be combusted at a 96% control efficiency. This unit is designed in compliance with the requirements of the 40 CFR Part 63 Subpart HH ONG MACT standard. Emissions are based on the GRI GLYCalc computer model. There will be no direct emissions to atmosphere from the Plant 3 gas dehydration unit. A completed APEN for this emission unit is provided in Attachment 1. Uncontrolled emissions listed on the APEN for this unit are based on the GRI GLYCaIc cornputer model. Controlled emissions from this unit are reported in the FLARE -3 control device APEN provided in Attachment 1. A control efficiency of 96% is assumed for the process and emergency flare FLARE -3, as discussed below. Plant 3 Process and Emergency Flare: Williams will install a new process and emergency flare (Source ID: FLARE -3) associated with the plant 3 portion of the facility. It will be of similar configuration to the existing FLARE -1 and FLARE -2 units. It will receive pilot and purge gas, flash gas from the Plant 3 amine and dehydration units, the still vent condenser overhead stream from the Plant 3 dehydration unit, and plant gas during emergency shutdown of the Plant 3 gas processing skid. It is designed to meet the requirements of 40 CFR Part 60.18 for smokeless operation of flares used as control devices. Emissions of NO; , CO, PM 10, and SO, are based on AP -42 emission factors for flares. Emission estimates for VOC from the Plant 3 flare are estimated based on a combination of GRI GLYCaic and AMINECaIc modeled emissions in addition to AP -42 emission factors. Annual emissions from the FLARE -3 emission source are estimated at 1.5 tpy NO,, 8.1 tpy CO, and 3.7 tpy VOC. A completed APEN for this unit is provided in Attachment I. Plant 3 Thermal Oxidizer: Williams plans to install a gas-fired 27.0 MMBrulhr Thermal Oxidizer (TO) unit that will serve as a Volatile Organic Compound (VOC) emission control device and waste heat recovery unit for Plant 3. Specifically, the TO unit (Source ID: TO -2) will Mr. Ram Seetharam CDPHE July 15.2005 Pate 3 receive VOC from the AMINE -3 sweetening unit still vent overhead stream and supplemental natural gas fuel that will be used to oxidize the VOC in a 1,600 deg. F flame. Waste heat will be recovered from the TO unit and used to supplement the hot oil system of the plant. Estimated VOC control efficiency of the TO -2 unit is 99.9%, based on manufacturer's specifications. Estimated emissions from the TO -1 unit are based on AP -42 Section I.4 emission factors for natural gas combustion, and are 11.8 tpy NO,,, 9.9 tpy CO, and 0.4 tpy VOC. Because the AMINE -3 flash tank is routed to the Plant 3 process and emergency flares (FLARE -3), and the AMINE -3 still vent stream will be routed through the TO -2 unit, there will not be any direct VOC emissions to atmosphere from the AMINE -3 still vent or flash tank emission unit. A completed APEN for the Plant 3 thermal oxidizer unit TO -2 is provided in Attachment 1. Plant 3 Condensate Storage Tanks: Williams will install a new dedicated Plant 3 condensate tank emission source (Source ID: TK-51TK-6) similar to the existing condensate tank emission sources. The VOC emission limit for this source is based on an assumed condensate collection rate of 6.0 bbl/day, a recent representative pressurized condensate sample analysis, and the E&PTANK2.0 computer model. The annual VOC emission limit proposed for this source is 20.4 tpy, and a completed APEN for this source is provided in Attachment 1. Exempt Plant 3 Condensate and NGL Loadout Source Activities: Williams will install a new condensate loadout emission source (Source ID: LOAD -5) and a new NGL loadout emission source (Source ID: LOAD -6), both associated with the Plant 3 portion of the facility. As with the existing loadout emission sources, estimated annual VOC emissions from the Plant 3 condensate loadout emission source and from the Plant 3 NGL loadout emission source are each below the 2.0 tpy threshold for APEN reporting and therefore are exempt from permitting and. APEN reporting. Plant 3 Fugitive VOC from. Leaking Equipment Source: An additional fugitive VOC emission source (Source ID: FUG -3) will be associated with the Plant 3 portion of the facility. Estimated VOC emissions from the Plant 3 fugitive emission source were based on an estimated equipment component count, a recent inlet gas analysis for PCGP, and the use of the Oil and Gas Production Operations equipment leak emission factors (from OAQPS TTN BBS, EPA -4531R-95-017, Table 2-4). The emission factors assumed a 75% control efficiency. Annual fugitive VOC emissions for this source are estimated at 3.1 tpy. This source is subject to the leak detection and repair requirements of 40 CFR Part 60 Subpart KKK. A completed APEN for this source is provided in Attachment 1. Facility -Wide Ambient Air Quality Modeling Williams has conducted ISCST3 Air Dispersion Modeling of the Parachute Creek Gas Plant NO* emissions. The modeled maximum ambient air NO2 concentration was 87.3 lugIm3, inclusive of a background concentration of 7.5 pglm3. This value is below the standard of 100 pg(m3, and the facility is in compliance with the annual NO2 NAAQS. A detailed description and resulting data from the ambient air quality modeling are provided in Attachment 4. Net Change in Permitted Emissions Resulting From This Modification Net changes in permitted emissions of criteria pollutants associated with this modification are summarized in the table presented below. Total permitted facility -wide emissions are changing from the permit limits applied for on July 15, 2005 under the Plant 1 & Plant 2 modification Mr. Ram Seetharam CDPHE July 35, 2005 Paste 4 submittal of 239.6 tpy NOx, 153.3 tpy CO, and 129.5 tpy VOC, to new totals of 451.7 tpy NO, 235.9 tpy CO, and 184.7 tpy VOC. PARACHUTE CREEK GAS PLANT PLANT 3 MODIFICATION NET CHANGE IN PERMITTED EMISSIONS Activity/Equipment NOx CO VOC Add ENG -17 Through ENG -24 173.6 43.2 24.3 Add HTR -3 25.3 21.2 1.4 Add FLARE -3 (AMINE-3IDEHY-4) 1.5 8.1 3.7 Add TO -2 (AMINE -3) 11.8 9.9 0.4 Add TK-5ITK-6 20.4 Add Exempt LOAD -5 0.2 Add Exempt. LOAD -6 1.6 Add FUG -3 3.1 Net Change in Permit. Emiss. 212.2 82.4 55.1 Facility -Wide Prior to Mod. 239.6 153.3 129.5 Facility -Wide Under This Mod. 451.7 235.9 184.7 Summary of Permitting and PS» Applicability The PCGP facility is located in an area that is designated as "attainment"' for all criteria pollutants. Under the most recent PCGP permit modification application submitted on July 15, 2005 for Plant 1 & Plant 2, Williams proposed to install VOC emission controls and has requested federally enforceable VOC limits on several emission sources at the PCGP, thereby assuring that the facility's potential to emit (PTE) VOC is less than 250 tpy. The federally enforceable VOC emission limits will become effective upon issuance of a modified construction permit, and, as such qualify the facility as a Synthetic Minor Source for VOCs under the PSD program. The PTE of all other criteria pollutants are below the PSD Major Source threshold of 250 tpy. Williams requests that the Division process this permit modification application (Plant 3) and the July 15 Plant 1 and Plant 2 application concurrently but issue the Plant 1 and Plant 2 permit modification before issuing the modification requested in this application. Consequently, under this approach, the Plant 3 modification at PCGP is subject to construction permit requirements for modifications at non -PSD major sources. This permit approach is consistent with the determination of PSD applicability discussed in the July 11, 2005 letter from Gary Kaufman (CDPHE) to Richard L. Griffith, LLC (Williams counsel). Please note that installation of the PCGP Plant 3 portion of the facility is a new project in response to new exploration and development of natural gas reserves in the Piceance Basin and resulting new contracts for gas processing and delivery. The need for a Plant 3 expansion of the PCGP facility was not anticipated at the time the plans for the Plant 1 or Plant 2 portions of the facility was being developed. The PCGP Plant 3 expansion, therefore, is not part of an ongoing project at the PCGP facility, and constitutes a single project in and of itself. This issue is addressed in greater detail in separate correspondence. ATTACHMENTS ATTACHMENT 1: Completed Application for Construction Permit or Permit Modification Completed APENs for New and Modified Emission Sources Completed Form 1 and Form 1-A Initial Notification of NMACT Applicability Revised Emissions Inventory Spreadsheet and Supporting Calculations ATTACHMENT 4: ISCST3 Air Dispersion Modeling Analysis ATTACHMENT 2: ATTACHMENT 3: ATTACHMENT 1 Completed Application for Construction Permit or Permit Modification Completed APENs for New and Modified Emission Sources • APPLICATION FOR CONSTRUCTION PERMIT OR PERMIT MODIFICATION SEE INSTRUCTIONS ON REVERSE SIDE. Mail completed application, APENs, and filing fee to: Colorado Department of Public Health and Environment Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 Telephone: (303) 692-3150 1. Permit to be issued to: Williams Production RMT Company 2. Mailing Address: 1515 Arapahoe Sr., Tower 3, Suite 1000 Denver, Colorado 80202 3. Agent for Service: Gerard G. Alberts 4. General Nature of Business Exploration and Production of Natural Gas 5. Air Pollution Source Description: Natural Gas Gathering SIC code (if known) 4922 Is this a Portable Unit? No 6. Source Location Address (Include Location Map) If portable, include the initial location and home base location Parachute Creek Gas Plant - Plant 3 NE 1/4 NE 1/4 Section 33 Township 6 South Range 96 West. Garfield County, Colorado 8190! 7. STATUS New or Previously Unreported Source a' Requesting Modification of Permitted Source (Control Equipment added, process change, etc.): Change in Emissions, Throughputs, or Equipment ❑ Transfer of Ownership — Include an Administrative Amendment Form ❑ Requesting to limit a source's Potential to Emit (Synthetic Minor) for criteria or Hazardous Air Pollutants using Regulation No. 3 (for new and existing sources) ❑ Requesting to limit a source's Potential to Emit for Hazardous Air Pollutants only using Regulation No. 8 (for existing sources only) 111 Other: 9. Projected or Existing Source Startup Date: Fourth Quarter 2005 11 1 ►�1 10. Enclose check to cove APEN FILING FEF • ne APEN should be fiI d for each emission point/or group of points NOTE: Additional p sing fees must ._ so be pa .nor to perm' ' suance. Si azure Of Legally Autho zed Person (NOT Vendor or Equipment Manufacturer) Gerard G. Alberts - Principal Environmental Specialist Type or Print Name And Official Title Of Person Signing Above 11. Check appropriate box if you want: Copy of preliminary analysis conducted by Division To review a draft of the permit prior to issuance Nae' C. reeking either %e+n could resuh m sr eased rtes amlfue processeng lime, Sec Reverse L o Date Signed Phone: (303) 606-4386 Fax: (303) 629-8275 For Division Use Only: Permit Number: AIRS ID: Revised July 2001 http://www.cdphe.state.co.us/ap/stationary.asp AIPPOLLUTANT EMISSION NOTIC• PERMIT No.: 02GA0014 FIRM NAME Williams Production RMT Company AIRS ID.:015/0365/*** MAIL ADDRESS_,j515 Arapahoe St., Tower 3. Suise 1000 _ STATE: CQ ZIP: 80202 PLANT NAME & LOCATION Parachute Creek Gas Plant N 1/2 of_NE2,4 Session 33. T6S R96W COUNTY: Garfield PORTABLE SOURCE PERMIT HOME -BASE FOR PORTABLE SOURCE PERSON TO CONTACT REGARDING THIS INFORMATION•JVi . Gerard 0, Alberts TITLE Principal Environmental Specialist GENERAL DESCRIPTION OF THIS PLANTS FUNCTION Natural Gas Processing E-MAIL ADDRESS: ; err y . aiberts@wi 11 iams . corn PHONE (303)-572-3900 A. GENERAL INFORMATION Normal Operation of This Source Process Seasonal Through ut (% of Annual) ADDITIONAL INFORMATION OR REMARKS: Hours/Day 24 Days/Week l T Weeks/Year 52 Dec -Feb 25 Mar -May 25 Jun -Aug 25 — Sep -Nov 25 B. STACK OR VENT INFORMATION f ldenttfv below which suck if plant has two or more: refer to attached sker h of plant lavoutl Height 28.0 ft Diameter 1 I.5 ft Temperature 858 °F r Flow Rate 23,4-61 ACFM Velocity 13,276 ftimin Moisture Plant ID No. for Stack NA % ENG -17 - -- C. C. FUEL INFORMATION Design nput RateAnnual Fuel Consumption J Fuel Heating Value: Percent b Weight Seasonal Fuel UseS96 of Annual Use) Space Description of Combustion Unit (106 BTU/hr) Kind of Fuel Burned Requested level Actual level (Data year level) (BTU/Ib, BTI]/gal, or BTU/scf) Sulfur Ash Dec -Feb Mar -May Jun -Aug Sep -Nov (90 Ar Natural Gas Compressor Engine 21.7 MMBtu/hr Nat .Gas 183 MMscf/yr 1,040 Btu/wt. Neg1. Negl, 25 25 25 25 Make/Model: CATERPILLAR G36I2 TALE, 3,210 hp with SCO Catalyst Control - Serial No, Unknown D. PROCESS INFORMATION Raw Materials Used Raw Materials _Annua Consumption Design Process Rate Finished Product Finished Product-Annua Output Description of Processing Unit - Description Requested level Actual level (Data year level) (Specify Units/Hour) Description Requested level Actual level (Data year lev — Makt:JMode1: - SenaTNo.: - -- - E. POLLUTION CONTROL EQUIPMENT Overall ESTIMATED EMISSIONS ACTUAL ESTIMATION CHECK • New or previously unreported • Requesting modification Change in emissions, Transfer of ownership (List previous owner Previous APEN is expiring Request for Emission (Specify) ALL BOXES THAT APPLY source of existing permit t t throughputs or equipment I in REMARKS section of box A.) 1 1 Reduction Credit t 1 Pollutant Type of Control Equipment Collection Efficiency (TONS/YEAR) AT THROUGHPUTS REQUESTED ABOVE EMISSIONS (from data year) METHOD Pnmary Secondary CONTROLLED UNCONTROLLED Particulate - NA Negl. PM le _ NA Negl. SO, - NA Neg1. NO, None 0 °,6 21.7 21.7 Manufacturer ' Complete all applicable portions of APEN t Complete ' Requested Level' values for permit limits I Complete all information above box A, and those remaining portions which reflect changes VOC SCO Catalyst 93% 3.0 42.9 Manufacturer CO SCO Catalyst 93% 5.4 - 77,1 Manufacturer PLEASE USE APCD NON.CR.ITERIA REPORTABLE AIR POLLUTANT ADDENDUM FORM TO REPORT SU r • POLLUTANTS OR POLLUTANTS NOT LISTED A t t, 'E. C . CK HERE 1 10 IF YOU WISH THE DIVISION TO CALCULATE YOUR . SES gi, SSION ESTIMATES" INSTRUCTIONS ON BACK. Signature of Person Legal y Authorized to Supply Dater A d J ,. all ....-- IAt rt J YEAR FOR WHICH THE ACTUAL DATA APPLIES: Typed Name and Title Gerard G. Alberts, Principal Envtronmer4i Specialist Date source began or will begin operation: 2005 THIS NOTICE IS VALID FOR FIVE YEARS. A revised notice shall be bled prior to this expiration dale, whenever a permit limitation must he modified, whenever control equipment is changed, and annually whenever a significant emission change occurs. For specific details see Regulation 3, Part A, ' I1.C.1. A $1.19.96 FILING FEE IS REQUIRED FOR EACH NOTICE FILED, Send completed forme with fnne tn• Colorado Dept. o Public Health & Environment APEN #_I_of I5 Air Pollution Control Division T 4300 Cherry Creek Drive South, APCD-SS-B t For information, Call _ r>........ t".......-.4.- 0111AZ 1elr, „�� -- -, NON -CRITERIA REPORTABLE AIRUTANT EMISSION NOTICE ADDE JM (Instructions on reverse side) Permit Number Company Name: Plant Location: Person to Contact: e-mail Address: 02GA0014 — ENG -17 Williams Production RMT Company AIRS Number 045/0365/*** Near Parachute, Colorado Gerard G. Alberts ierr'Y,alberts@willitms.com County Garfield Zip Code 81635 Phone 303 572- 3900 Fax 303 629-8275 Chemical Abstract Service Number Chemical Name Reporting Bin Control Equipment/ Efficiency Emission Factor (include units) Emission Factor Source Requested Emissions (lbs/yr) Actual Emissions f the Data Year (lbs, 75-07-0 Acetaldehyde A 93 % 0.00836 lb/MMBtu less Catalyst Efficiency AP -42 less Catalyst Efficiency111 107-02-8 Acrolein A 93 %lbfMMBtu 0.00514 less Catalyst Efficiency AP -42 less Catalyst Efficiency 68 50-00-0 Formaldehyde A 93 %703 • 0.0528 lb/MMBtu less Catalyst Efficiency AP -42 less Catalyst Efficiency — Form for reponi Air Signa Gerard G. A . er Name of a Responsible Official (please print) tants. Ox ne Depleting Compounds. and other Non•Criteria Reponable Pollutant a ndor Year For Whi The Actual Data Applies --% —1 i —i spon a� tal (not or consultant) ate Principal Environmental S pecialist Title AIR POLLUTANT EMISSION NOTICE PERMIT No.: 02GA0014 AIRS ID.:04510365/*** FIRM NAME Williams Production RMT Company MAIL ADDRESS 1515 Arapahoe St., Tower 3, Suite 1000 STATE: CO ZIP: 80202 PLANT NAME & LOCATION Parachute Creek Gas Plant N 54 of NE rt4 Section 33. T6S R96W COUNTY: Garfield REQUEST PORTABLE SOURCE PERMIT HOMEBASE FOR PORTABLE SOURCE PERSON TO CONTACT REGARDING THIS INFORMATION Mr. Gerard G. Alberts TITLE Principal Environmental Specialist PHONE ^(303)-572-3900 GENERAL DESCRIPTION OF THIS PLANTS FUNCTION Natural Gas Processin E-MAIL ADDRESS ;eery.alberts@williams.00m A. GENERAL INFORMATION Normal Opera ion of This Sou ce Process Seasonal Throughput (% of Annual) ADDITIONAL INFORMATION OR REMARKS: Hours/Day 24 Days/Week 7 Weeks/Year 52 Dec -Feb 25 Mar -May 25 Jun -Aug 25 Sep -Nov 25 B STACK OR VENT INFORMATION (tdentifv below which stack if plant has two or more: refer to attached Sketch or tont layout) Height :5 0 ft Diameter 1.5 ft Temperature i 558 "F Flow Rate 23.461 ACFM Velocity Moisture 13.276 ft/min NA % ' Plant ED No. for Stack ENG -15 Space (% Ar I C. FUEL INFORMATION Design n ut Rate Annual Fuel Consumption Fuel Heating Value: Percent by Weight Seasonal Fuel UscS%of Annual Use Description of Combustion Unit (106 BTU/hr) Kind of Fuel Burned Requested level Actual level (Data year Ieveo) (BTU/lb, BTU/gal, or BTU/scf) Sulfur Ash Dec -Feb Mar -May Jun -Aug Sep -Nov Natural Gas Compressor Engine 21.7 MMBtulhr Nat .Gas 183 MMscf/yr 1.040 Btu/scf Negl. - - Negl. , 25 25 25 25 Make/Model. CATERPILLAR G3612 TALE, 3.21.4 hp with SCO Catalyst Control _ - - — Serial No. Unknown D. PROCESS INFORMATION Raw Materials Used Raw Materials-Annua Consumption Design Process Rate Finished Product Finished Product -Annual Output Description of Processing Unit Description Requested level Actual level (Data year level) (Specify Units/Hour) Description Requested level Actual level (Dara year lev. -- Ma. e+Model r Serial No.: E. POLLUTION CONTROL EQUIPMENT Overall ESTIMATED EMISSIONS ACTUAL ESTIMATION CHECK ALL BOXES THAT APPLY Pollutant Type of Control Equipment Collection Efficiency (TONS/YEAR) AT THROUGHPUTS REQUESTED ABOVE EMISSIONS (from data year) METHOD • New or previously unreported sources ■ Requesting modification of existing permit t t _ Primary Secondary CONTROLLED UNCONTROLLED Change in emissions. throughputs or equipment t Particulate NA 1 Negl. - 1 Transfer of ownership ({st owner in REMARKS section of box A.) t Philo NA Negl. previous Previous APEN is expiring I SO, NA _ Negl. Request for Emission Reduction Credit t t None Manufacturer (Specify) NO, 0 % 21.7 21.7 • of APEN l Comletea{Requested VOC SCO Catalyst _ 93% 3.0 - 42.9 Manufacturer Lacableevelort'ns values for permit limits t Comple a CO SCO Catalyst 93% 5.4 77.1 Manufacturer t Complete all information above box A. and those remaining PLEASE USE APCD NON•CRITtRIA REPORTABLE AIRportions POLLUTANT ADDENDUM FORM TO REPORT SUC POLLUTANTS OR POLLUTANTS NOT LISTED AB . CH i' K HERE IF YOU WISH THE DIVISION TO CALCULATE YOUR TO EE " SSION ESTI" INSTRUCTIONS ON BACK. which reflect changes ii. 1,ignalurc of Person Legally Authorized to Supply Data: D7: -(r"- 0 EAR FOR WHICH THE ACTUAL DATA APPLIES: yped Name and Title: Gerard G Alberts, Principal Environmental Specialist Date source began or will begin operation: 20 )5 y HIS NOTICE IS VALID FOR FIVE YEARS. A revised notice shall be Filed prior to this *Oration date, whenever ri Pertnfl limitation must be modified, whenever control equipment I c rl,ene.rA end n..n.,almu .i..i.u•.r....I..wili.-..... �....�.i..w-.1..., «......,....... C..v .,._.,in.... �...ii....., A $1I19.96 FILING FEE IS REQUIRED FOR EACH NOTICE FILED. Colorado Depi. o Air Pollution Control ...., �. Public Health & Environment APEN M_2_af_15 Division II NON -CRITERIA REPORTABLE AIR LL UTANT EMISSION NOTICE ADDE vM (Instructions on reverse side) Permit Number Company Name: Plant Location: Person to Contact: e-mail Address: 020A0014 — ENG -18 Williams Production RMT Company AIRS Number 045/03651*** Near Parachute, Colorado Gerard G. Alberts l errxr . alberts@wi111ans . com County Garfield Zip Code 81635 Phone 303 572- 3900 Fax 303 629-8275 .. Chemical Abstract Service Number — Chemical Name Reporting Bin Control Equipment/ Efficiency — Emission Factor (include units) Emission Factor Source v Requested Emissions (lbs/yr) Actual Emissions the Data Year (Ib 75-07-0 Acetaldehyde A 93 % 0.00836 lb/MMBtu less Catalyst Efficiency AP -42 less Catalyst Efficiency 111 107-02-8 Acrolein A 93 % 0.00514 IbIMMBtu less Catalyst Efficiency AP -42 less Catalyst Efficiency 68 50-00-0 Formaldehyde A 93 940 0.05281bfMMBtu less Catalyst Efficiency AP -42 less Catalyst Efficiency 703 - — Use thi for reporting )1 it P lut Depleting Com SignatResponsible Official not a vendor or consultant) Gerard G. Alberts Name of a Responsible Official (please print) and other Non -Criteria Reportable Pollutant Year For Which/Pie—Actual Data Applies:. Date Principal Environmental Specialist Title AIROLLUTANT EMISSION NOTICE• PERMIT No.: 02GA0014 AIRS ID.:045/0365/*** FIRM NAME Williams Production RMT Company MAIL ADDRESS I51$ Arapahoe St., Tower 3, Suite 1000STATE: CO ZIP: 80202 PLANT NAME A LOCATION parachute Creek Gas Plant N Vs of NE N. Section 33. T6S. R96W COUNTY: Garfield REQUEST PORTABLE SOURCE PERMIT HOME -BASE FOR PORTABLE SOURCE PERSON TO CONTACT REGARDING THIS INFORMATION Mr. Gerard G. Alberts TITLE Principal Environmental Specialist GENERAL DESCRIPTION OP THIS PLANTS FUNCTION Natural Gas Processing E -MAL ADDRESS. H erry . alberts@wi 11 Jams . Corn PHONE(303)-572-3900 A. GENERAL INFORMATION Norm Operation of This Source Process Seasonal Through ut (% of Annual) ADDITIONAL INFORMATION OR REMARKS: Hours/Day 24 DaysfWeek 7 Weeks/Year 52 Dec -Feb 25 Mar -May 25 Jun -Aug 25 Sep -Nov 25 - 13 STACK OR VENT INFORMATION (Wenn f. bel) ' which stack if plant has two or more: refer to attached sketch of plant layout} - Height 28.0 ft Diameter 1.5 ft Temperature 858 "F Flow Rate 23,461 ACFM Veloci y 13,276 ftimin Moisture NA % Plant ID No. for Stack ENG -19 C. FUEL INFORMATION Design Input Rate Annual Feet Consum non Fuel Heating Value: Percent by Weight Seasonal Fuel UseS% of Annual Use) Space F Description of Combustion Unit (I0° BTU/hr) Kind of Fuel Burned • equeste. eve Actua eve (Data year level) (BTUIIb, BTU/gal, or BTUlscf) Sulfur Ash Dec -Feb Mar -May Jun -Aug Sep -Nov (% Ant Natural Gas Compressor Engine 21.7 MMBtulhr Nat .Gas 183 MMscflyr I,040 Btulsef Negl. Negl. 25 25 25 25 MakclModcl: CATERPILLAR G3612 TALE, 3.210 hp with SCO Catalyst Control Serial No. Unknown D. PROCESS INFORMATION Description of Processrng Unit - Raw Materials Used Raw Materials -Annual Consum.tion Design Process Rate Finished Product Finished Product•Annual Out,ut Description _ - Requested level r (Specify Units/Hour) Descrption - Requested level Actua eve (Data year leve ake/Model: - - - Senai No.: E POLLUTION CONTROL EQUIPMENT Overall ESTIMATED (TONS/YEAR) REQUESTED EMISSIONS AT THROUGHPUTS ABOVE — ACTUAL EMISSIONS (from data year) ESTIMATION METHOD CHECK ALL BOXES THAT APPLY U New or previously unreported source' • Requesting modification of existing permit t : Change in emissions. throughputs or equipment r Transfer of ownership (List previous owner in REMARKS section of box A.) t Previous APEN is expiring I Request for Emission Reduction Credit t t (Specify) Pollutant Type of Control Equipment Collection Efficiency Pnmar, Secondary CONTROLLED UNCONTROLLED -- - - Particulate - NA Negl. - - P>41.n - NA Meg'. g SO, NA Negl. NO, None 0 % 21.7 21.7 Manufacturer of APEN t Complete 'Requested lete alt Leev llicable a' values for permit Limits Complete all information above box A, and those remaining portions which reflect changes VOC SCO Catalyst 93%ons t CO SCO Catalyst 93%4 77.1 Manufacturer PI EASE USE APCD ih1OPI•CRITERIA ADDENDUM P@RM POLI lJ TANTS QR PQLLIJTANTS REFQRTABLE AI Ry TQ REPORT SUCH NOT LISTED AROV CHECK HERE IFPOLLUTANT am 1' r. rWISH * s CALCULATEa UR ` a ON Signature of Person Legally Authorized to Supply Data: rg ilIF,7%Il� i? .,` R FOR WHICH THE ACTUAL DATA APPLIES: ypcd Name and Tide: 1 Gerard G. Alberts. Pnnci.al Environmenta S. ialiSt Date source began or will begin operation: 2005 THIS NOTICE IS VALID FOR FIVE 1'i:ARS. A revised notice shall be riled prior to this exist ration date, whenever a permit limitation must be modified, whenever control equipment is changed, and annually whenever a significant emission change occurs. For specific details se Regulation 3, Part A, ' H.C.I. A $119.96 FILING FEE IS REQUIRED FOR EACH NOTICE FILED• Send completed Terms with fere in' Colorado Dept of Public Health & Environment ADEN ii3 of_I5 Air Pollution Control Division 4300 Cherry Creek Dnve South, APCD-SS-B I For Information, Call _ n.,,,,.. r ,,.,..e, an -.4.6.1 ezn rzna% m1.11 cn •NON -CRITERIA REPORTABLE AIR P 1, UTANT EMISSION NOTICE ADDENOivI Permit Number Company Name: Plant Location: Person to Contact, e-mail Address: (instruct 02GA0014 —ENG -19 Williams Production RMT Company AIRS Number 045/0365/*** Near Parachute, Colorado Gerard G. Alberts iierrv.alberts@william*_.com County Garfield Zip Code 81635 Phone 303 572- 3900 Fax 303 629-8275 Chemical Abstract Service Number Chemical Name Reporting Bin Control Equipment/ Efficiency Emission Factor (include units) Emission Factor Source Requested Emissions (lbslyr) Actual Emissions fro the Data Year flbsiyn 75-07-0 Acetaldehyde A w 93 % 0.00836 lbIMMBtu less Catalyst Efficiency AP -42 less Catalyst $/less at fi ciy . 11 1 107-02-8 Acrolein A 93 % 0.00514 1bIMMBtu less Catalyst Efficiency AP -42 less Catalyst Efficiency 68 50-00-0 Formaldehyde A 93 % 0.0528 1b/MMBtu less Catalyst Efficiency AP -42 less Catalyst Efficiency 703 Use this for reporting H Air P e Dep€etin Clmonsitilierancl other Non -Criteria Reportable Pollutant Signature 9 a 1 es • - sible Official of a vendor or consultant) Gerard G. Alberts Y For Which The Actual'Applies: Date Principal Environmental Specialist Name of a Responsible Official (please print) Title .° AIT P OLLUTANT EMISSION NOTICE FIRM NAME Williams Production RMT Company MAIL ADDRESS 1515 Ara.ahoe t. Tower 3 Suit 1000 PLANT NAME & LOCATION Parachute Creek Gas plant Nth of NE 4 Section 33 MS R96W COUNTY: Gar REQUEST PORTABLE SOURCE PERMIT HOMEBASE FOR PORTABLE SOURCE PERSON TO CONTACT REGARDING THIS INFORMATION Mr. Gerard G. Alberts GENERAL DESCR IPTION OF THIS PLANTS FUNCTION Natural Gas Process nt=_ PERMIT No.: 020A0014 AIRS D.:045/0365f*** STATE: CO ZIP: 80702 TITLE Principal Environmental Specialilt E-MAIL .ADDRESS- - err' . a? berts@wi 11iatnS . Cort! PHONE D03)-572 900 A. GENERAL ! 'FORMATION Normal Operation of This Source Process Seasonal Througtput (57 of Ann all ADDITIONAL INFORMATION OR REMARKS: Hours/Day 24 Days/Week 7 Weeks/Year 52 Dec -Feb 25 Mar -May 25 tun -Aug 25 Sep -Nov 25 B. STACK OR VENT INFORMATION (identify below which track i f plant has two or n ore: refer to attached sketch of plant layout) Height 28 0 ft Diameter l.5 ft Temperature 855 "F Flow Rate 233.461 ACFM Veloci y 13,276 ftim n Moisture NA % Plant ID No, for Stack ENG -20 t- C. FUEL INFORMATION Design 'Tut Rate Annual Fuel Consum tion - Fucl Heating Value: Percent by Weight Seasonal Fuel Use (% of Annual Uscj Space H+ (rib Ann Description of Combustion Unit (1 On BTUihr) Kind of Fuel Burned • equesce• eve Actual evel (Data year level) (BTU/lb, BTU/gal. or BTU/scf) Sulfur Ash Dec -Feb Mar -May Jun -Aug Sep -Nov Natural Gas Compressor Engine 21.7 MM 13tuihr Nat .Gas 183 MMscffyr 1,040 Btu/scf - NegI. Negl. 25 25 25 25 Make/Model: CATERPILLAR 03612 TALE, 3.210 hp with SCO Cowl • t Control - -� Serial No. Unknown D. PROCESS INFORMATION Raw Materials Used Raw Materials -Annual Consumption Design Process Rate Finished Product Finished Product.Annua Output Requested level Actual level (Data year level) Description of Processing Unit Description Requested level Actual level (Data year level) !Specify Units/Hour) Description - MakeiModel: SenatNo. E. POLLUTION CONTROL EQUIPMENT Overall ESTIMATED EMISSIONS ACTUAL ESTIMATION CHECK ALL BOXES THAT APPLY Pollutant Type of Control. Equipment Collection Efficiency (TONS/YEAR) AT THROUGHPUTS REQUESTED ABOVE EMISSIONS (from data year) METHOD ■ New or previously unreported source" 1 Requesting modification of existing permit t t Primary Secondary CONTROLLED UNCONTROLLED r Change in emissions. throughputs or equipment ; Particulate NANegl. - Transfer of ownership (List owner in REMARKS section of box A.) t PM,n NA Negl. g previous Previous APEN is expiring 1 SO, NA Negl. Request for Emission Reduction Credit t s None (Specify) NO, 096 21.7 21.7 Manufacturer * Complete of APEN VOC SCO Catalyst 93% 3.0 42.9 Manufacturer all applicable ponions t Complete ' Requested Level ` values for permit limits CO SCO Catalyst 93% 5.4 77.1 Manufacturer $ Complete all information above box A, and those remaining PLEASE USE APCD NON -CRITERIA REPORTABLE AIR POLLUTANT ADDENDUM FORM TO REPORT SUCH POLLUTANTS OR POLLUTANTS NOT LISTED ABOVE CHECK HERE IF YOU WISH THE DIVISION TO CALCULATE YOUR EMISSI IA . EE "EMI ON ESTIMATES" INSTRUCTIONS ON BACK. portions which reflect changes Signature o Person Legally Authorized to Supply Data: W 11,11r c rte[ YEAR FOR WHICH THE ACTUAL DATA APPLIES: Typed Name and Title: ` Gerard G. Alberts, Princi p al Environmental Specialist Date source began or will begin operation: 2005 err' Colorado Dept. o Air Pollution Control 4300 Cherry Creek -- .- Public Health & Environment APEN 00_4_�of_15.. Division Drive South. APCD-SS-B I For lnfornation, Gill _ . •. --- HIS NOTICE I3 VALID FOR FIVE YEARS. A revised notice shall be filed prior to this xpiratlon date, whenever a permit limitation must be modified, whenever control equipment s changed, and annually whenever a significant emission change occurs. For specific details see I' eaulatian 3. Part A. ' II.C.1_ A 5119.96 FILING FEE IS REQUIRED FOR EACH NOTICE FILED. Send cmmnlitwel forme with fwec rn • NON -CRITERIA REPORTABLE AIR PRL UTANT EMISSION NOTICE ADDEN UM* (Instructions on reverse side) AIRS Number 04510365/*** Permit Number Company Name: Plant Location: Person to Contact: e-mail Address: 02GA0014 — ENG -20 Williams Production RMT Company Near Parachute, Colorado Gerard G. Alberts lee'rv. alberes(wi1liarns. com County Garfield Zip Code 81635 Phone 303 572- 3900 Fax 303 629-8275 Chemical Abstract Service Number Chemical Name Reporting Bin Control Equipment/ Efficiency Emission Factor (include units) Emission Factor Source Requested Emissions Obs/ r) Actual Emissions In the Data Year (Ibs/) 75-07-0 Acetaldehyde A 93 % 0.00836 lbIMMBtu less Catalyst Efficiency AP -42 less Catalyst Efficiency 111 107-02-8 Acrolein A 93 %lb/MMBtu 0.00514 less Catalyst Efficiency AP -42 less Catalyst Efficiency 68 50-00-0 Formaldehyde A g30 0.0528 IbIMMBtu less Catalyst Efficiency AP -42 less Catalyst Efficiency 703 * Use This forpI (or reporting Bazar Dcple • . ompounds, and other Non -Criteria Reportable Pollutant ear For Which The Actual Data Applies: Signature of'Res }onstble Of ial •t a vendor or consultant) Gerard C Alberts Name of a Responsible Official (please print) Date Principal Environmental Specialist Title A.I. OLLUTA.NT EMISSION NOTICE FIRM NAME Williams Production RMT Company MAIL ADDRESS. 1515 Arapahoe St„ Tower 3, Suite 1009 STATE: CO ZIP: .80202 PLANT NAME & LOCATION Parachute Creek Gas Plant N 1 of NE k4 Section 33. TGS R96W COUNTY. _Garfield REQUEST PORTABLE SOURCE PERMIT HOME -BASE FOR PORTABLE SOURCE PERSON TO CONTACT REGARDING THIS INFORMATION Mr. Gerard G. Alberts TITLE Principal Environmental Specialist PHONE - 72- • PERMIT No.: 020A0014 AIRS ID.:O45/0365/* GENERAL DESCRIPTION OF THIS PLANTS FUNCTION Natural Gas Processing E-MAIL ADDRESS: err y.albertsaw.liams.com A. GENERAL INFORMATION Normal Operation of This Source Process Seasonal Throughout (% of Annual) ADDITIONAL INFOR.'SLATION OR REMARKS Hours/Day 24 Days/Week 7 WeekslYear 52 Dec -Feb 25 Mar -Mal. 25 Jun -Aug [Sep_Nov 25 25 B STACK OR VENT INFORMATION (ldentifv below _ which stack if plant has two or more: refer to a Cached sketch of plant layout) � 1.., Height 28.011 O,ameter 1.5 ft Tcmperaturc 858 "F Flow Rate 23,461 ACFM Velocity 13,276 ft/min Moisture NA % _ Plant ID No. for Stack ENG -21 C. FUEL INFORMATION Description of Combustion Unit Design nput Rate (10`i BTU/hr) Kind of Fuel Burned Annual Fuel Consumption Fuer Heating Value: (BTU/lb. BTU/gal, or BTUlscf) Percent by Weight Seasonal Fuel Use (% of Annual Use] Space H (% Ann Requested leve[ Actual level (Data year level) Sulfur Ash Dec -Feb Mar -May Jun -Aug Sep.Nov Natural Gas Compressor Engine 21.7 MMBtu/hr Nat .Gas 183 MMscflyr 1,040 Btu/scf Negl. 1 Neg.!. 25 25 25 25 MakefModel: CATERPILLAR G3612 TALE. 3,210 hp with SCO Catalyst Control Serial No. Unknown - _ __. _— D. PROCESS INFORMATION Rave Materials Used Raw Materials -Annual Consumption Design Process Rate Finished Product Finished Product-Annua Output Description of Processing Unit Description Requested level Actual level (Data year level) (Specify Units/Hour) Description Requested level Actual level (Data year level. 7vtake/Model: - - Senal No.: - CHECK • New or previously unreported • Requesting modification Change in emissions, Transfer of ownership (List previous owner Previous APEN is expiring Request for Emission (Specify) ALL BOXES THAT APPLY source* of existing permit throughputs or equipment in REMARKS section 1 Reduction Credit t t t t t of box A.) t E. POLLUTION CONTROL EQUIPMENT Overall ESTIMATED EMISSIONS (TONS/YEAR) AT THROUGHPUTS REQUESTED ABOVE _ ACTUAL EMISSIONS (from data year) ESTIMATION METHOD Pollutant Type of Control Equipment Collection Efficiency Primary Secondary CONTROLLED UNCONTROLLED Particulate - NA Nut. PM10 - NA Negi. SO, — - - - NA Negl. _ - - - NO, None 0 % 21.7 21.7 Manufacturer ' Complete alt applicable portions of APEN t Complete `Requested Level' values for permit limits t Complete all information above box A. and those remaining portions which reflect changes VOC SCO Catalyst 93%3,(} 42.9 Manufacturer CO SCO Catalyst 935'0 5.4 77.1 Manufacturer PLEASE USE APCD NON -CRITERIA REPORTABLE AIR POLLUTANT ADDENDUM FORM TO REPORT SUCH POLLUTANTS OR POLLUTANTS NOT LISTED ABOVE. CHECK EMISSI ti IF YOU WISH THE DIVISION TO CALCULATE YOUR S. "EM.a N ESTIMATES" INSTRUCTIONS ON BACK. Signature of Person Legally Authorized to Supply Data: lr, I10 J i �. f l O YEAR FOR WHICH THE ACTUAL DATA APPLIES: sped Name and Title: Gerard G. Alberts. Princi .al Environ ntal 5 ecialist Date source began or will begin operation: 2005 THIS NOTICE 15 VALID FOR FIVE YEARS. A revised notice shall be filed prior to this expiration date, whenever a permit limitation must be modified, whenever control equipment is changed, and annuallyy whenever a significant emission change occurs. For specific details se Rt¢ulation 3. Parr A. 1 I1.CA. $119.96 FILING FEE IS REQUIRED Colorado Dept. o .1 OR EACH NOTICE FILED. Air Pollution Control 4300 Ch Creek Cwnrl rmmnl.r.,i f...,..a. c .u:.f..,' tr..r ._..._ �--- .. Public Hcalth & Environment APEN p_5_of_I5 _ Division Drive South., APCD-SS-81 For Informaion,tCall - _. • . --- - i ON -CRITERIA REPORTABLE AIR P L UTANT EMISSION NOTICE ADDEN SI* (Instructions on reverse side) AIRS Number 045/03651*** Permit Number Company Name:. Plant Location: Person to Contact: e-mail Address: 02GA0014 -- ENG -21 Williams Production RMT Company Near Parachute, Colorado Gerard G. Alberts ierrv.a1berts williarns.corn County Garfield Zip Code 81635 Phone 303 572- 3900 Fax 303 629-8275 Chemical Abstract Service Number ChemicaI Name Reporting Bin Control Equipment/ Efficiency Emission Factor (include units) Emission Factor Source Requested Emissions (lbsiyr) Actual Emissions In the Data Year OW; 75-07-0 Acetaldehyde A 93 % 0.00836 Ib1MMBtu less Catalyst Efficiency gP.421ess Catalyst Efficiency 111 107-02-8 Acrolein A 93 % 0,00514 lbIMMEtu less Catalyst Efficiency - AP -42 less Catalyst Efficiency 68 50-00-0 Formaldehyde A 93 %0.0528 IbfMMBtu less Catalyst Efficiency AP -42 less Catalyst Efficiency 703 -- - r - - Use this form f ng Hazardous Air ting Compounds. and other Non -Criteria Reportable Pollutant Signature of a Gerard G. berts nsib e Official (not a ndor or consultant) Year For Which The ActualApplies: Date Principal Environmental Specialist- - Name of a Responsible Official (please print) Title AllgOLLUTANT EMISSION FIRM NAME Williams Production RMT Comoa • MAIL ADDRESS 1515 Arapahoe St., Tower 3, Suite 1000 STATE: Q ZIP: _mai_ PLANT NAME & LOCATION Parachute Creek Gas Plant N VI of NE V4 Section 33 T6S R96W COUNTY: Garfield REQUEST PORTABLE SOURCE PERMIT HOME -BASE FOR PORTABLE SOURCE - PERSON TO CONTACT REGARDING THIS INFORMATION Mr. Gerard G. Albert, TITLE Principal Environmental Specialist PHONE (303)-572-3900 GENERAL DESCRIPTION OF THIS PLANTS FUNCTION Natural Gas Processing E-MAIL ADDRESS: ] erry - a lbert @wi l l i ams , com A. GENERAL INFORMATION Normal Operation of This Source Process Seasonal Through ut (% of Annual}_ ADDITIONAL INFORMATION OR REMARKS: Hours/Day 24 Days/Week 7 Weeks/Year 52 Dec -Feb 25 Mar -May 25 Jun -Aug 25 Sep -Nov 25 B. STACK OR VENT INFORMATION (Identify below which stack if plant has two or more: refer to attached sketch of plant layout) Height 28.0 ft Diameter 1.5 ft Temperature 858 °F Flow Rate 23,461 ACFM Velocity 13.276 ftfmin Moisture NA % Plant ID No. for Stack ENO -22 c C. FUEL INFORMATION Design nppul Rate Annual Fuel Consumption Fuel Heating Value: Percent by Weight Seasonal Fuel Use % of Annual Use) Space Description of Combustion Unit (Id' BTU/hr) Kind of Fuel Burned Requestevel Actual level (Data year level) (BTU/lb. BRequested-revel(% or BTUlscf) Sulfur Ash Dec -Feb Mar -May Jun -Aug Sep -Nov Ai Natural Gas Compressor Engine 21.7 MMBtulhr Nat .Gas 183 MMscflyr 1,040 Btulscf Negl. Negl. 25 25 25 25 Make/Model; CATERPILLAR 03612 TALE. 3.210 tip with SCO Catalyst Control r Serial Na. Unknown D. PROCESS INFORMATION Raw Materials Used Raw Materials -Annual Consumption_ Design Process Rate Finished Product Finished Product -Annum Output Description of Processing Unit -- Description Requested level Actual level (Data year level) (Specify Units/Hour) Dcscri ption Requested level Actual level (Data year Icy ' Make/Model Sen al No.: - E. POLLUTION CONTROL EQUIPMENT Overall ESTIMATED EMISSIONS ACTUAL ESTIMATION CHECK ALL BOXES THAT APPLY Pollutant Type of Control Equipment Collection Efficiency (TONS/YEAR) AT THROUGHPUTS REgUESTED ABOVE - EMISSIONS (from data year) METHOD ■ New or previously unreported source* • Requesting modification of existing permit t t Primary Secondary CONTROLLED UNCONTROLLED - Change in emissions, throughputs or equipment I Particulate NA Nest. Transfer of ownership (List owner in REMARKS section of box A.) t Pit, NA Ne 1 g previous Previous APEN is expiring I SO, NA Nee. Request for Emission Reduction Credit t I NO, None (Specify) 0 % 21.7 21.7 Manufacturer ' Complete APEN VOC SCO Catalyst 93% 3.0 42.9 Manufacturer all applicable portions of t Complete "Requested Level' values for permit limits CO SCO Catalyst 93% 5,4 77,1 ..- Manufacturer t Complete all information above box A, and those remaining PLEASE USE APCD NON -CRITERIA REPORTABLE AIR POLLUTANT ADDENDUM FORM TO REPORT SUCH POLLUTANTS OR POLLUTANTS NOT LISTED ABOVtp_ CHECK EMISS44S. HERE IF YOU WISH THE DIVISION TO CALCULATE YOUR SEE "ENDS ESTIMATES"' INSTRUCTIONS ON BACK. portions which reflect changes Signature oUPcrson Legally Authorized to Supply Data. �� t7A • -rYEAR FOR V HICH THE ACTUAL DATA APPLIES: IL 1+'�,~.• 1 � / :\ C1 ypcd Name and Title: Gerard G. Alberts, Principal Env' nmental S.ecialist Date source began or will begin operation: 2005 THIS NOTICE I5 VALID FOR FIVE YEARS, A revised nuke shall be filed prior to this expiration date, whenever a permit limitation must be modified, whenever control equipment is changed, and annually whenever a significant emission change occurs- For specific details see. Regulation 3. Part A. li.C.t. A $11996 FILING FEE IS REQUIRED FOR EACH NOTICE FILED. Cervi rmmnI.i.A f'..''..,:.i. a.....-.... Colorado Dept- of Public Health S; Environment APEN P_6_of_15_ Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS•B I For Information. Call •NONCR1TERIA REPORTABLE AIR P L UTANT EMISSION NOTICE ADDEN 1vI (Instructions on reverse side) AIRS Number 045103651*** Permit Number Company Name: Plant Location: Person to Contact: e-mail Address: 020A0014 ENG -22 Williams Production RMT Company Near Parachute. Colorado Gerard G. Alberts ierre,alberts@wi11iams.coal County Garfield Zip Code 81635 Phone 303 572- 3900 Fax 303 629-8275 Chemical Abstract Service Number Chemical Name Reporting Bin Control Equipment/ Efficiency Emission Factor (include units) Emission Factor Source Requested Emissions (lbs/yr) Actual Emissions fro the Data Year (lbs/y. 75-07-0 Acetaldehyde A 93 % 0.00836 lb1MMBtu less Catalyst Efficiency AP -42 less Catalyst Efficiency 1 1 1 107-02-8 Acrolein A 93 %lb/MMBtu 0.00514 less Catalyst Efficiency AP -42 less Catalyst Efficiency 68 50-00-0 Formaldehyde A 93 %0.0528 _ ib1MMBtu less Catalyst Efficiency AP -42 less Catalyst Efficiency 703 Use this (arm_.r rep; ring Hazardo Pollut is Ozer pleting Compounds. and other Non -Criteria Reportable Pollutant Signature of Res . onsl + e Officia o a ven+or or nsultant) Gerard G. Alberts Year For Which The Actual Data Applies: C Date Principal Environmental Specialist Name of a Responsible Official (please print) Title AIR OLLUTANT EMISSION NOTICE FIRM NAME Williams Production RMT Company MAIL ADDRESS 1515 Arapahoe Si, Tower 3, Suite 1000 PERMIT No.: 020A0014 AIRS ID.:045/0365/*** STATE: CO ZIP: 80202 PLANT NAME & LOCATION Parachute Creek Gas Plant N i of NE i/• Section 33. T6S. R96W COUNTY:Garfield REQUEST PORTABLE SOURCE PERMIT HOMEBASE FOR PORTABLE SOURCE - - PERSON TO CONTACT REGARDING THIS INFORMATION Mr. Gerard G. Alberts TITLE Principal Environmental Specialist PHONE 0031-572-3900 GENERAL DESCRIPTION OF THIS PLANTS FUNCTION Natural Gas Processing E-MAIL ADDRESS: erry.a1ber'ts@williams-corn A. GENERAL INFORMATION Normal Operation of This Source Process Seasonal Through ut (% of Annual) ADDITIONAL INFORMATION OR REMARKS: Hou Day 24 DaysfWeek 7 Weeks/Year 52 Dec -Feb 25 Mar -May 25 Jun -Aug 25 Sep -Nov 25 B STACK OR VENT INFORMATION , Identify below which stack if plant has two or more.. refer to attached sketch of plant lavoutl - Height 28.0 ft Sit Diameter 1.5 It Temperature 858 'T' Flow Rate 23,461 ACFh1 i'elacsty 13,276 ft/min Moisture NA Plant 1D No. for Stack ENG -33 T C. FUEL INFORMATION Design nput Rat c Annual Fuel Consumption Fuel Heating Value: Percent by Weicht Seasonal Fuel Use (% of Annual Use) Space Ht (% Ann. Description of Combustion Unit (i 0" B'TUfhr) Kind of Fuel Burned Requested level. Actual level (Data year level) (BTU/lb. BTU/gal, or BTU/scf) Sulfur Ash Dec -Feb Mar -May ]un -Aug Scp-Nov Natural Gas Compressor Engine 21.7 MMBtulhr Nat .Gas 183 MMscf/yr 1,040 Btu/so f Negi. Negi, 25 25 25 25 Make/Model: CATERPILLAR G3612 TALE, 3,210 hp with SCO Catalyst Control Serial No. Unknown D PROCESS INFORMATION Raw Materials Used Raw Materials -Annual Consumption Design Process Rate Finished Product Finished Product-Annua Output Description of Processing Unit Description Requested level Actual level (Data year level) (Specify Units/Hour) Description -- Requested level Actual level (Data year level) Make/Model, - Sena]. No: CHECK ALL BOXES THAT APPLY • New or previously unreported source' • Requesting modification of existing permit t t Change in emissions. throughputs or equipment t Transfer of ownership (List previous owner in REMARKS section of box A.) i Previous APEN is expiring .1 Request for Emission Reduction Credit t s (Specify) - - - E. POLLUTION CONTROL EQUIPMENT Overall ESTIMATED EMISSIONS a . • VESTED ABOVE ACTUALESTIMATION • NS Morn data year) Pollutant Type of Control Equipment Collection Efficiency Pnmary Secondary CONTROLLED UNCONTROLLED Pat[iculate NA hit I. P,Mtq NA e NI. g SO, 4 NA Negl NO, None 0 % 21.7 21.7 Manufacturer Complete all applicable portions of APEN t Complete ' Requested Level' values for permit limits t Complete all information above box A. and those remaining which reflect changes t''�' VOC SCO Catalyst 93%3.0 42,9 Matnufactuner CO SCO Catalyst 93% 5.4 77.1 Manufacturer PLEASE USE APCD NON•CRITERIA REPORTABLE AIRportions POLLUTANT ADDENDUM FORM TO REPORT SUCH POLLUTANTS OR POLLUTANTS NOT LISTED ABOVE. A CHECK HE IF EMISSION , SEE YOU WISH THE DIVISION TO CALCULATE YOUR "EMISSION TES" INSTRUCTIONS ON BACK. Signature of Person Legally Authorized to Supply Data. 1 - ■ ra-: YEAR FOR WHICH THE ACTUAL DATA APPLIES Typed Name and Title- Gerard G Albers, Pnnctpat Envtro ental 5 calist Date source began or will begin operation: 2005 THIS NOTICE IS VALID] FOR FIVE YEARS, A revised notice shall be filed prior to this expl ration date, whenever a permit limitation must be modified, whenever control equipment is changed, and annually whenever a significant emission change occurs. For specific details see Regulation 3, Part A. ' I.C.I.I ,A $119.96 FILING FEE IS REQUIRED FOR EACH NOTICE FILED. Send completed forms with fees to: Colorado Dept. of Air Pollution Control 4300 Che Creek r,,,,.....r .,.,r„ Public Health & Environment APEN M-7_of_I — Division Drive South, APCD-SS-B I For Information, Call ame.s. 5 Inn ']A� 1 N de 1, °^ - NON -CRITERIA REPORTABLE AIR i,L UTANT EMISSION NOTICE ADDEUM* (Instructions on reverse side) Permit Number Company Name: Plant Location: Person to Contact: e-mail Address: 02GA0014 — ENG -23 Williams Production RMT Company AIRS Number 045/0365/*** Near Parachute, Colorado Gerard G. Alberts lerry.alberu@williams.com County Garfield Zip Code 81635 Phone 303 572- 3900 Fax 303 629-8275 Chemical Abstract Service Number ... Chemical Name Reponing Bin Control Equipment/ Efficiency Emission Factor (include units) Emission Factor Source Requested Emissions [lbs/yr) Actual Emissions fr the Data Year (lbs/; 75-07-0 Acetaldehyde A 93 % 0.00836 lbfMMBtu less Catalyst Efficiency AP -42 less Catalyst Efficiency 111 107-02-8 Acrolein A 93 % 0.00514 ibfMMBtu less Catalyst Efficiency AP -42 less Catalyst Efficiency 68 50-00-0 Formaldehyde A 93 % 0.0528 lb/MMBtu Tess Catalyst Efficiency AP -42 less Catalyst Efficiency 703 Use this form for reporting Ha us it Plutants `. a De.letin: Compounds, and other Non -Criteria Reportable Pollutant Signature o9-R'4porzsible r i l a no a vendor : consultant) Gerard G"Alberts Year For Which TheActs ata Applies: Date Principal Environmental Specialist Naive of a Responsible Official (please print) Title AIR. 3LLUTANT EMISSION NOTICE FIRM NAME Williams Production RMT Company, MAIL ADDRESS 1515 Ar4tlahoe St.. Tower 3. Suite 10(19 • PERMIT No.: 02GA0014 AIRS UD.:045/0365f*** STATE: CQ ZIP: 80202 - PLANT NAME & LOCATION Parachute Creek Gas Plant N'h of NE r/• Sectfot+ }. T§5,296W COUNTY': Garfield REQUEST PORTABLE SOURCE PERMJT HOME -BASE FOR PORTABLE SOURCE - PERSON TO CONTACT REGARDING THIS INFORMATION Mr. Gerard G. Alberts TJTLE Principal Environmental Specialist PHONE,•_„(3Q3)-572-39GO GENERAL DESCRIPTION OPTICS PLANTS FUNCTION Natural Gas Processing E-MAIL ADDRESS. ierry . alberts@wi 11 tares . c om A. GENERAL INFORMATION Normal Op anon of This Source Pracess Seasonal Dec -Feb 25 Throughput Mar -May 25 % of Annual) Jun -Aug 25 Sep -Nov 25 ADDITIONAL 1NFOIt..Lt.TION OR REMARKS: Hours/Day 24 I Days/Week 7 WeeksIYear 52 B. STACK OR VENT ItiFORMATION (Identify below whtch stack if plant has two or more; refer to attached sketch ofplant layout) - Height 28.0 ft Diameter 1.5 ft Temperature 858 °F Flow Rate 23,461 ACFM Velocity 13.276 ft/min Moisture NA ` Plant ID No. for Stack ENG -24 C. FUEL INFORMATION Design npput Rate Annual Fuel Consum non Fuel Heating Value: Percent by Weight Sensona Fu Use r% of Annual Use) Space Hil Description of Combustion Unit ( 106 BTUIhr) Kind of Fuel Burned • equeste. eve Actun leve (Data year level) tBTU/ib. BTU/gal, or BTU/scf) Sulfur Ash Dec -Feb Mar -May Jun -Aug Sep -Nov (% Ann.) Natural Gas Compressor Engine 21.7 MMBtuihr Nal .Gas 183 MMscfJyr 1,040 Btuiscf Negl. Negl. ® 25 5 ® Make/Model: CATERPILLAR G3612 TALE, 3,210 hp with SCO Catalyst Control 5enal No. Unknown D. PROCESS INFORMATION Raw Materials Used Raw Materials -Annus Consum+Cion Design Process Rate Finished Product Finished Product-Annua Output Descn.lton of ProceSsin _ Unit Descri.tion Re• nested level ciao eve (Data ye it 1e •^? r5pecify Un1tslHour Dcscnption R-•uested level Actual level _ Data ear level Make1Mode1: ens �. E. POLLUTION CONTROL EQUiPM_ENT Overall ESTIMATED EMISSIONS ACTUAL ESTIMATION CHECK ALL BOXES THAT APPLY Pollutant Type of Control Equipment Collection Efficiency (TONS1Yl~AR) AT THROUC•HPUTS REQUESTED ABOVE EMISSIONS (from daw year) METHOD ■ New or previously unreported source' ■ Requesting modification of existing permit t 3 PnmarySecondary CQNTRQLLt:D UNCONTROLLED Change in emissions, throughputs or equipment r Particulate NA Negl. - Transfer of ownership (List in REMARKS section of box A.) t PM,e NA Negi. previous owner Previous APEN is expiring I • NA Negl. Request for Emission Reduction Credit t t • t % 21.7Manufacturer (Specify) •n 21.7 • ADEN •• Manufacturer Complete all applicable portions of t Complete 'Requested Level , values for permit limits • SCO Catalys 93% 5 4 77. t Complete all information above box A. and those remaining PLEASE USE 1POLLUTANT 1 r NON -CRITERIA ADDENDUM• REPORTABLE AIR • REPORT CHECK HERE• DIVISION TO CALCULATE YOURportions . a1 which reflect changes _-_ Signature of Person Legally Authorized to Supply Data:FI D • l ': — .! �i YEAR FOR WHICH THE ACTUAL DAT.A .A PLIES yped Name and Tule: Gerard G. Alberts, Principal Enviro nental ciaiist Date source began or will begin operation: 2005 'HIS NOTICE IS VALID FOR FIVE YEARS. A revised notice shatI he tiled prier to this A 5119.96 FILING FEE IS REQUIRED xpiration date, whenever a permit limitation must be modified, whenever control equipment IFOR EACH NOTICE FILED. a changed, and annually whenever a significant enzlsslon change occurs. For specific details see r• •roaFlan 1 Part A. • it i. conA rmm�l.t.rt fnnno ..,`tr. Cowl... ul Colorado Dept. of Air Pollution Control 4300 Che Creek .__.. Public Health & Environment APEN 4e8_of_15_ Division Drive South, APCs? -S5 -B 1 For Information, Call w�... ..+. • NON -CRITERIA REPORTABLE AIR IC UTANT EMISSION NOTICE ADDELJM* (instructions on reverse side) Permit Number Company Name: Plant Location: Person to Contact: e-mail Address: 020A0014 — ENG -24 Williams Production RMT Company AIRS Number 045/03651*** Near Parachute, Colorado Gerard G. Alberts Ierry,aiberts@awi11iams.cQm County Garfield Zip Code 81635 Phone 303 572- 3900 Fax 303 629-8275 Chemical Abstract Service Number Chemical Name Reporting Bin Control Equipment/ Efficiency Emission Factor (include units) Em ssion Facto SourceEmissions Requested (lbslyrp Actual Emissions fi the Data Year (lbs! 75-07-0 Acetaldehyde A 93 % 0.00836 1bIMMEtu less CatalystEfficiency Efficiency AP -42 less Catalys 1 l 1 107-02-8 Acralein A g3 0.00514 ibIMMBtu less Catalyst Efficiency Efficiency 68 50-00-0 Formaldehyde A - 93 % 0.0528 lbfMM19ru less Catalyst Efficiency Efficienc 703 • Use this form for repo g Hazardous Air Po g Compounds. and other Non -Criteria Reportable Pollutant Signature of a Resp • ": •ficial nota ven•or or consuhant) Gerard. G. Alberts Name of a Responsible Official (please print) Year For Which Theata Applies: Date Principal Environmental Specialist Title AIR OLLUTA.NT EMISSION NOTICE FIRM NAME Williams Production RMT Company MAIL ADDRESS 1515 Arapahoe St, Tower 3, Suite 1000 PLANT NAME & LOCATION_ Parachute Creek Gas Plant N of NE YID Settlor! 33. T65, R96W COUNTY: Garfield PERMIT No.: 02GA0014 AIRS ID,:045/0365/*** STATE: %O ZIP• 80202 REQUEST PORTABLE SOURCE PERMIT HOME -BASE FOR PORTABLE SOURCE PERSON TO CONTACT REGARDING THIS INFORMATION Mr. Gerard G. Alberts TITLE Principal Environmental Specialist PHONE (303)-572-3900 GENERAL DESCRIPTION OF THIS PLANTS FUNCTION Natural Gas Processtng E-MAIL ADDRESS: i erry . a lberts @wi 11 isms . corn A. GENERAL INFORMATION Normal Operation of This Source Process Seasonal Through ut (% of Annual) ADDITIONAL INFORMATION OR REMARKS: Hours/Day 24 Days/Week 7 Weeks/Year 52 Dec -Feb 25 Mar -May 25 Jun -Aug 25 _ Sep -Nov 25 B. STACK OR VENT INFORMATION (Identify below which stack if plant has two or more: refer to attached sketch of plant layout) Height 20.0 ft Diameter 3.0 ft Temperature 500 °F Flow Rate I 18,692 ACFM Velocity 2,644 ft/min Moisture NA % Plant ID No. For Stack HTR -3 Space H (% Ann C. FUEL INFORMATION Design nput Rate Annual Fuel Consum.tion FOCI Heating Value: Percent b Wei tSeasonal Fuel Use of Annual Use} Description of Combustion Unit (14° BTU/hr) Kind of Fuel Burned • cquesteeve Actua eve (Data year level) (BTU/Ib, BTU/gal. or BTU/scf) Sulfur AshDec Feb Mar -May Jun -Aug Sep Nov Plant 3 Hot Oil Heater .1,1 MMBtu/hr Nat •Gas 5 S5M sc /yr 1,040 Btu/scf Negl. Negl. 25 25 25 25 Make/Model: NA Serial No. Unknown D. PROCESS INFORMATION Raw Materials Used Raw Materials -Annual Consumption Design Process Rate Finished Product Finished Product -Annual Output Requested level Actual levet (Data year levet; Description of Processing Unit Description Requested levelr Actual level (Data year level) (Specify Units/Hour) Description Make/Modei: f Senaf No.: - f E. POLLUTION CONTROL EQUIPMENT Overall ESTIMATED EMISSIONS ACTUAL ESTIMATION CHECK ALL BOXES THAT APPLY Pollutant Type of Control Equipment Collection Efficiency (TONS/YEAR) AT THROUGHPUTS REQUESTED ABOVE EMISSIONS (from data year) METHOD i New or previously unreported source* i Requesting modification of existing permit t t Primary Secondary CONTROLLED UNCONTROLLED Change in emissions. throughputs or equipment t Portico late NA — Negl, Transfer of ownership (List owner in REMARKS section of box A.) t PM 10 NA Negl. previous Previous APEN is expiring I SO, NA Negl, Request for Emission Reduction Credit t t (Specify) NO, NA 25.3 AP -42 ' Complete APEN VOC NA 1.4 all applicable portions of AP 42 I Complete ' Requested Level' values for permit limits CO NA 21.2 AP 42 t Complete all information above box A, and those remaining PLEASE USE APCD NON -CRITERIA REPORTABLE AIRportions SUCHPOLLUTANT ADDENDUM FORM TO REPORT SUCH POLLUTANTS OR POLLUTANTS NOT LISTED ABO l'. CHECIG HERE IF YOU WISH EMI iYiL,.` 5 • which reflect changes THE DIVISION TO CALCULATE YOUR ON ESTIMA "INSTRUCTIONS ON BACK. .P'...-- Signature of Person Legally Authorized to Supply Data; fip /1 I DT' t r—...0 .1 YEAR FOR WHICH THE ACTUAL DATA APPLIES: Typed Name and Title: r Gerard G. Alberts. Principal En ' onmen +I Specialist Date source began or will begin operation: 2005 THIS NOTICE IS VALID FOR FIVE YEARS. A revised notice shall be filed prior to this expiration date, whenever a permit limitation must be modified, whenever control equipment is changed, and annually whenever a significant emission change occurs. For specific details see Resrulatlon 3. Part A. ' II.C.I. A $119.96 FILING FEE IS REQUIRED FOR EACH NOTICE FILED. Send cornniatpd FRRMe with Coat. tn• Colorado Dept. of Public Health & Environment APEN #_9_of_ 15_ Air Pollution Control Division 4300 Cherry Creek Drive South, APCD•SS-B 1 For information wCal1 _ Al .•,__ A__, �^ --^ - • • NON-CRITEffiA REPORTABLE AIR,LLUTANT EMISSION NOTICE ADDEIPUM Permit Number 020A0014 — HTR -3 Company Name: Plant Location: Person to Contact: E -Mail Address: Williams Production RMT Company (Instructions on reverse side) AIRS Number 045/0369*** Near Parachute, Colorado Gerard G. Alberts ierry , alberts@w,jlliatns . com County Garfield Zip Code 81635 Phone 303 572-3900 Fax 303 629-8275 Chemical Abstract Service mbcr ALL BELOW Chemical Name Reponing Bin Control Equipment/ Efficiency Emission Factor (include units) Emission Factor Source Requested Emissions (lbs/yr) Actual Emissions from tt Data Year (lbs/yr) DE MINIMS • Use this form for reporting Hazardous Air Pollutants, Ozone Depleting Compounds, and other Non -Criteria Reponable Pollutant Signatu or Responsi•lc • fficia ' not a vendor or consultant) Gerard G. Alberts Name of a Responsible Official (please print) Year For Which The Actual Data Applies: Date Principal Environmental Specialist Title AIRLLU 1 Al T EI'vIISSION NOTICE FIRM NAME Williams Production RMT Com an MAIL ADDRESS 1535 Aragahoe St„ Tower 3, Suite 1000 PLANT NAME & LOCATION PARACHUTE CREEK GAS PLANT N lti of NEVA Section 33. T6S. R96W PERMIT No.: 02GA0014 AIRS ID.:045/0355/ ** STATE: CQ ZIP; COUNTY: GARFIELD 80202. REQUEST PORTABLE SOURCE PERMIT HOME -BASE FOR PORTABLE SOURCE PERSON TO CONTACT REGARDING THIS INFORMATION Mr. erard G. Alberts TITLE Principal Environmental Specialist PHONE (303) 572-3900 $ errv.alberts@will.ams.com GENERAL DESCRIPTION OF THIS PLANTS FUNCTION Natural Gas Processin E-MAIL ADDRESS: A. GENERAL INFORMATION Normal Operation of This Source Process Seasonal Throughput (% of Annual) ADDITIONAL INFORMATION OR REMARKS: Flash Tank Routed to FLARE -3 and Still Vent Routed to TO -2 Controls. Hours/Day 24 DaysiWeek 7 Weeks/Year 52 Dec -Feb 25 Mar -May 25 Jun -Aug 25 Sep -Nov 25 Emissions Reported On Control Device APENs B STACK OR VENT INFORMATION Identify below which stack if plant has two or more: refer to attached sketch of plant layout) Height. ft Diameter ft Temperature "F Flow Rate ACFM Velocity ft/min Moisture Plant 1D No. for Stack AMINE -3 C. FUEL INFORMATION Design Input Rate Annual Fuel Consum.tion Fuel Heating Value: P ent b Wei ht Seasonal Fuel Use�(96 of Annual Use) Space Hti Descnplion of Combustion Unit (10. BTUihr) Kind of Fuel • equeste. eve Actua eve .or BTU/5c°' Sulfur Ash Dec -Feb Mar -May Jun -Aug Sep -Nov (% Ann.) MakelModel - - Serial No. D. PROCESS INFORMATION Raw Materials Used Raw Materials -Annual Consum•lion Design Process Rate Finished Product Finished Product -Annual Out•ut Description of Processing Unit Descnpi'aon_ Requested level - Data (Specify Units/Hour) Descnption Requested level ma (Data eve year level) PLANT 3 AMINE SWEETENING UNIT - 150 MMscffday Low CO2 Nat. Gas o • ode!: — — - ena 'a.: - �t E. POLLUTION CONTROL EQUIPMENT Overall ESTIMATED EMISSIONS ACTUAL ESTIMATION CHECK ALL BOXES THAT APPLY Pollutant Type of Control Equipment Collection Efficiency (TONS/YEAR) AT THROUGHPUTS REQUESTED ABOVE EMISSIONS (from data year) METHOD New or previously unreported source' i Requesting modification of existing permit t i Primary Secondary CONTROLLED UNCONTROLLED • Change in emissions. throughputs or equipment 1 Particulate NA NA Transfer of ownership (List owner in REMARKS section of box A.) t PM,o NA NA previous Previous APEN is expiring 1 SO. NA NA Request for Emission Reduction Credit t i NO. NA NA (Specify) `Complete APEN VOC Flash to Flare Still Vent to TO Flare 96% TO 99.9% l.7 FLASH c4.1 STILL 41.4 FLASH 29.4 STILL VENT all applicable portions of AMINECaIc t Complete ' Requested Level • values for permit limits s Complete all information above box A, and those remaining CO _- NA NA portions which reflect changes PLEASE USE APCD NON -CRITERIA POLLUTANT ADDENDUM FORM POLLUTANTS OR POLLUTANTS REPORTABLE AIR TO REPORT SUCH NOT LISTED ABO A CHECK HERE IF YOU WISH THE DIVISION TO CALCULATE YOUR ,//�` EMIS a EE ",EMI S1 a ESTIMATES" INSTRUCTIONS ON IIACK. ignature of Person Legally Authorized to Supply Data: - ii ,,1 DA (5 ....27jry L/ �S `SEAR FOR WHICH THE ACTUAL DATA APPLIES: ypcd Name and Title: Gerard G. Alberts, Princi. ,1 Envi •nmenta .. cialist 11 Date source began or will begin operation: 2405 ORM 04/4//// r CHIS NOTICE IS VALID FOR FIVE YEARS. A revised notice shall be filed prior o this expiration date, whenever a permit limitation must be modified, whenever ontrot equipment is changed. and annually whenever a significant emission change A ' 5119.96 FILING FEE IS REQUIRED OR EACH NOTICE FILED. _ _ b. A Colorado Dept. of Public Health & Environment APEN 0_10_01 _15_ - Air Pollution Control Division 4300 Cherry Creek Drive Smith APell.CC-A t tier tnrA....eliAA Pall • • • NON -CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM* ( on reverse side} Permit Number Company Name: Plant Location: Person to Contact: E -Mail Address: 02GA0014 — AMINE -3 AIRS Number 045/0365/*** Williams Production RMT Company Near Parachute, Colorado Gerard G. Alberts ierrv.alberts@williams.com County Garfield Zip Code 81635 Phone 303 572-3900 Fax 303 629-8275 Chemical Abstract Service Number Chemical Name Rcponing Bin Control Equipment/ efficiency Emission Factor (include. units) Emission Factor Source Requested Emissions (lbs/yr) Actual Emissions from — the Data Year (Ibsfyr) - ALL BELOW DE MINIMS • L • Use this form for reporting Hazardous Mr Pollutants, Ozone Depleting Compounds, and other Non -Criteria Reportable Pollu it Signature of . es o ible • fficia o a ndor or consultant) Gerard 0 lberts Year For Which The Actual Data c5 -o Date Principal Environmental Sp cialist Name of a Responsible Official (please print) Titre AIRIULLUTANT EMISSION NOTICE FIRM NAME Williams Production RMT Com an MAIL ADDRESS 1515 Arapahoe St.. Tower 3. Suite 1000 PERMIT No.: 02GA0014 AIRS ID. :045/0365/*** STATE: CQ ZIP. 80202 PLANT NAME & LOCATION PARACHUTE CREEK GAS PLANT N a .p(N % Section 33. T6S. R96W COUNTY: _GARFIELD REQUEST PORTABLE SOURCE PERMIT HOME -BASE FOR PORTABLE SOURCE PERSON TO CONTACT REGARDING THIS INFORMATION.,J' r, Gerard G. Alberts TITLE Principal 1;rrVir9flfnental Specialist PHONE 003)-572-3900 GENERAL DESCRIPTION OF THIS PLANTS FUNCTION Natural Gas Pracessing E-MAIL ADDRESS: f erry. alberts@williams . corn A GENERAL INFORMATION Normal Operation of This Source Process Seasonal Throughput (Te of Annual} ADDITIONAL INFORMATION OR REMARKS: HoursfDay 24 Days/Week 7 ' Weeks/Year 52 Dec -Feb 25 Mar -May 25 Jun -Aug 25 Sep -Nov 25 Thermal Oxidizer Receives AMINE --3 Still Vent VOC and Supplemental Fuel Also used for Waste Heat Recovery. B. STACK OR VENT INFORMATION (Identify below which stack if plant has two or more: refer to attached sketch of plant layout) -- Height 75 0 ft Diameter • 2.5 ft Temperature 1.600 `F Flow Rate Velocity ft/min Moisture % Plant ID No, for Stack TO -2 ..� .. - - — - C. FUEL INFORMATION Design npput Rate Annual Fuel Consumption Fuel Heating Value: Percent by Weight Seasonal Fuel Use (% of Annual Use) Space Ht- Descnption of Combustion Unit ( I Y" STU/hr) Kind of Fuel Burned Requested level Actual level (Data year level) (BTUIIb, BTUfgaI. or BTWscf) Sulfur Ash Dec•Fcb Mar -May i Jun -Aug Sep -Nov (% Ann.. Plant 3 Thermal Oxidizer 27.0 Nat Gas & Prrrrese ('i , 227.4 MMcrfNT Approx. 1,040 - Make/Model: - Serial No. - J D. PROCESS INFORMATION Raw Materials Used Raw Materials -Annual Consumption Design Process Rate Etnished Product Finished Product -Annual Output Descrpnon of Processing Unit Description Requested level Actual level (Data year level! (Specify 1)n/Hour) Description Requested level Actual level (Data year level) - - MakelModel: - 5enal No., v .+=111.....- -MNI- I.. moi..'— r i CHECK II New or previously unreported IE Requesting modification • Change in emissions, 4 Transfer of ownership previous owner Previous APEN is expiring 4 Request for Emission 1 (Specify) ALL BOXES THAT APPLY source' of existing permit t s throughputs or equipment t in REMARKS section of box A.) t I Reduction Credit 1 : E. POLLUTION CONTROL EQUIPMENT - - Overall ESTIMATED EMISSIONS (TONSIYEAR) AT THROUGHPUTS REQUESTED ABOVE _ ACTUAL EMISSIONS (from data year) ESTIMATION METHOD Pollutant Type of Control Equipment Collection Efficiency Primary - - Secondary CONTROLLED UNCONTROLLED Particulate - NA _ NA, PM in -+ NA NA.(fast O. - NA - - NA. - NO, NA 11.8 AP -42 ' Complete all applicable portions of APEN t Complete ' Requested Level' values for permit limits t Complete all information above box A, and those remaining which reflect changes VOC 99.9% NA 0.4 lwtanufcsurcr CO NA 9.9 AP -42 PLEASE USE APCD NON -CRITERIA REPORTABLE AIRportions POLLUTANT ADDENDUM FORM TO REPORT SUC POLLUTANTS OR POLLUTANTS NOT LISTED ABO ' CIiECK HERE II? YOU WISH THE DIVISION TO CALCULATE YOUR Elft S. 5 "EMISSION ESTIMATES" INSTRUCTIONS ON BACK. lrA . {5 �0 r7EAR FOR WHICH THE ACTUAL DATA APPLIES Signature of Person Legally Authorized to SupplyData: Typed Title: Gerard G. Alberts. Principal onmeatil Spectaltst Date source began or will begin operation: 2005 - THIS NOTICE IS VAL[U FOR FIVE YEARS. A resiled notice shall be tiled prior to this expiration date, whenever a permit limitation must be modified, whenever control equipment is 6chanl{ed, and annually V,henever a significant emission change occurs. For specific details see I ` •nik nfinn 1 Pori .ti 1 arra A SI19.96 FILING FEE IS REQUIRED FOR EACH NOTICE FILED. Ca 7 t , e�_- • ,_ e. Colorado Dept. of Public Health & Environment APEN NJ l_af_15_ Air Pollution Control Division 4300 Cherry Creek Dnvc South, APCD-SS-B I For Information. Call • NON -CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM* (Instructions on reverse side) Permit Number 02GA0014 — TO -2 AIRS Number 045/0365/*** Company Name: Williams Production. RMT Company Plant Location: Near Parachute, Colorado County Garfield _ Zip Code 81635 Person to Contact: Gerard G. Alberts Phone 303 572-3900 Fax 303 629-8275 E -Mail Address: 1 erre . alberts@will lams . corn Chemical Abstract Service Number ALL BELOW Chemical Name DE MINIMiS Reporting Control Equipment/ Bin Efficiency Emission Factor (include units) Emission Factor Source Requested Emissions (lbs/yr) Actual Emissions from th Data Year ribs/yr) • Use this form for reporting Hazard Depleting Compounds, and other Non -Criteria. Reportable Pollutant Year For Which The Actual to Applies: Signature ofi Resppnsi u le Official (n. t a vendor or consultant) Gerard G. Alberts 03 Date Principal Environmental Specialist Name of a Responsible Official (please print) Title AIROLLUTANT EMISSION NOTICE FIRM NAME_ Williams Production RMT Company MAIL ADDRESS J515 Arapahoe St.. Tower 3,l5 ,,ite l00(i PLANT NAME & LOCsATION PARACHOT CREEK QAS PLANT N `5 of NE 'A Section 33 T6S.R96W REQUEST PORTABLE SOURCE PERMIT HOME -BASE FOR PORTABLE SOURCE - PERMIT No.: 02GA0014 AIRS ID.:04510365/*** STATE: c__Q ZIP: 80202 COUNTY: GAJ FIELD PERSON TO CONTACT REGARDING THIS INFORMATION Mr. Gerard G. -Alberts TITLE PrincioalEnvironmental Specialist PHONE (303)-572-3900 GENERAL DESCRIPTION OF THIS PLANTS FUNCTION Natural Gas Processing E-MAIL ADDRESS: ferry. et1berts@wi11jams . com A. GENERAL INFORMATION Normal Operation of This Source Process Seasonal l T� pul (% of Annual) ADDITIONAL INFORMATION OR REMARKS: Rash Routed to FLARE -3. Still Vent Routed Through 120 deg. F Condenser to Hours/Day 24 Days/Week 7 Weeks/Year 52 Dee -Feb 25 Mar -May 25 Jun -Aug 25 Sep -Nov 25 FLARE -3. Emissions Reported On FLARE -3 APEN B STACK OR VENT INFORMATION (Iden (v below which stack if plant has two or more; refer to attached sketch of plant layout) Height ft Diameter ft Temperature °F Flow Rate ACF?N Velocity ft/min Moisture % Plant ID No. for Stack DEHY-4 C, FUEL INFORMATION Design nput Rate Annual Fuel ConsumSpace H Description (10° BTU/lir) Kinci of Fuel uest eve Actu eve (BTU/lb, BTU/gal, (% Ann Serial No. D. PROCESS INFORMATION Raw Materials Used Raw Matcnals•Annual Consumetion Design Process Rate Finished Product Finished Product -Annual Out. t Description of Processing Unit Description Requested level tua eve (Data vear level (S Units/Hour) Description Requested level Actua eve (Data year level PLANT 3 EG DEHYDRATION UNIT ,rcif 11 "' scf7dayy Camineled N.G. Dehydrated N.G. Makeimodel: -- Senal No.: - 0. CHECK • New or previously unreported • Requesting modification • Change in emissions. Transfer of ownership (List previous owner Previous APEN is expiring Request for Emission (Specify) ALL BOXES THAT APPLY source` of existing permit throughputs or equipment in REMARKS section I Reduction Credit 1 1 t 1 t of box A.) t 1E. POLLUTION CONTROL EQUIPMENT Ove all ESTIMATED EMISSIONS (TONS/YEAR) AT THROUGHPUTS REQUESTED ABOVE ACTUAL EMISSIONS (from data year) ESTIMATION METHOD 1 Pollutant l Type of Control Equipment - Collection Efficiency Primary Secondary CONTROLLED UNCONTROLLED Particulate NA Nq PM to NA NA, SO, NA NA. NO, NA NA ' Complete all applicable portions of APEN t Complete 'Requested Level' values for permit limits t Complete all information above box A, and those remaining portions which reflect changes VOC Process Fiore 96% 0.9 23.1 GRI GLYCaIc CO NA NA _ PLEASE USE APCD NON -CRITERIA REPORTABLE AIR POLLUTANT ADDENDUM FORM TO REPORT SUC POLLUTANTS OR POLLUTANTS NOT LISTED ABO CHE HERE IF YOU WISH THE DIVISION TO CALCULATE YOUR S S. S I " INSTRUCTIONS ON BACK !Signature of Person Legally Authorized to Supply Data: DA — 1 C YEAR FOR WHICH THE ACTUAL DATA APPLIES: �? ypcd Name and Title: Gerard G. Alberts. Princi..1 Environmen I S. ialist Dale source began or will begin option: 2005 THIS NOTICE IS VALID FOR FIVE YRARS. A revised notice shall be flied prior to this expiration date, whenever a permit limitation must be modified, whenever control equipment Is changed. and annually whenever a significant emission change occurs. For specific detail; see Reeulatinn ]. P.m A. , 11 r` i • S119.96 FILING FEE IS REQUIRED r OR EACH NOTICE FILED. .,k r..,...,, i Conti rnnnntrrrrt f".-...... .,. Colorado Dept. of Public Health & Environment APEN N_12_of_l5_ Air Pollution Control Division 4300 Ch Creek Drive South, APCD•SS•B I For Information, Call ., , . South, - • NON -CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM* Permit Number Company Name: Plant Location: Person to Contact: E -Mail Address: 02GA0014 — DEHY-4 Williams Production RMT Company (instructions on reverse side) AIRS Number 045/03651*** Near Parachute, Colorado Gerard G. Alberts iierrv,allarts@williams.com County Garfield Zip Code 81635 Phone 303 572-3900 Fax 303 629-8275 Chemical Abstract Service Number Chemical Name - Reporting Bin Control Equipment/ Efficiency Emission Factor (include units) Emission Factor Source Requested Emissions (Ibsr) _ Actual Emissions from th Data Year (Ibs/yr) NCRP EMISSIONS REPORTED UNDER FLARE -3 EMISSION POINT • Use this form for reporting Hazardous Air Pollutants, Ozone Depleting Compounds. and otherNon-Criteria Reportable Pollutant i. Signa e of z Responsible Of is not a vendor or consultant) Gerard G. Al4rts Name of a Responsible Official (please print) Year For Which The Actual Data Applies: 0) Date Principal Environmental Specialist Tine Ove all Collection Efficiency .° AIR OLLUTANT EMISSION NOTICE FIRM NAME Williams Production RMT Company MAIL ADDRESS 1515 Arapahoe St., Tower 3, Suite 1000 PLANT NAME & LOCATION I' PERMIT No.: 02GA0014 AIDS ID.:045f0365/*** STATE: _El ZIP: $0202 COUNTY: GARFIELD REQUEST PORTABLE SOURCE PERMIT HOME -BASE FOR PORTABLE SOURCE PERSON TO CONTACT REGARDING THIS INFORMATION Mr. Gerard G. Alberts TITLE Principal Environmental Specialist PHONE ^(303)-$72-3900 GENERAL DESCRIPTION OF THIS PLANTS FUNCTION Natural Gas Processing E -:'+i EL ADDRESS errv.alberl:s@williams.com A. GENERAL INFORMATION Normal Operation of This Source Process Seasonal Throughput (% of Annual) ADDITIONAL INFORMATION OR REMARKS: Receives Pilot[Purge/ESD Gas/DEHY-4 Flash/DEHY-4 Still Vent Hours/Day 24 Days/Week 7 Weeks/Year . 52 Dec -Feb 25 Mar-MayJun-Aug 25 25 Sep -Non 25 AMINE -3 Flash B. STACK OR VENT INFORMATION Identif below which stack if ,lant has two or more: elm' to attached sketch of .lant la out Height 75.0 Diameter 3.0 ft Temperature 800 `"F C. FUEL INFORMATION Description of Combustion Unit Plant 3 Process and Erne:gency Flare Make/,Model: Flow Rate Design npput Rate (1 06 8 TU/hr) Serial No. Unknown 165.0 Kind of Fuel Burned at as Prnr rss Gas Velocity ft/min Moisture Annual Fuel Consumption Requested level Actual level (Data year level) I) PROCESS INFORMATION Description of Processing Unit T+3akc7ModeI. - atenats Used Raw Matenals-Annual Consum.tion Description Requested level ctu, ve (Data year level) Plano ID No. for Stack FLARE -3 Fuel Heating Value: (BTU/Ib, BTU/gal, or B7U/sc() Approx. 1,+ 0 ign Proccss Rate (Specify Units/Hour) Percent by Weight easonal Fue] LIse ("e of Annual Use) Sulfu Ash Dec -Feb Mar -May un -Aug Scp-Nov Space H (% Ann Finished Product Description Finished Product-Annua Ou est Actua ley (Data year level Requested level E. POLLUTION CONTROL EQUIPMENT Pollutant Type of Control Equipment Secondary Particulate PM to ESTIMATED EMISSIONS [TONS/YEAR) AT THROUGHPUTS REQUESTED ABOVE - - CONTROLLED LTNCONTROLLED ACTUAL E,MiSSIONS (from data year) ESTIMATION METHOD CHECK ALL BOXES THAT APPLY 11 New or previously unreported source' IN Requesting modification of existing permit t IS Change in emissions, throughputs or equipment f Transfer of ownership (List previous owner in REMARKS section of box A.) t Previous APEN is expiring I SO, NA NA. Request For Emission Reduction Credit t i NO, NA l .5 AP -42 (Specify) OC NA 3.7 AMIIYECaklGLyCak ` Complete all applicable portions of APEN 1 Complete 'Requested Level' values for permit limits CO NA 8.1 AP -42 - t Complete all information above box A. and those remaining. portions which reflect changes PLEASE USE APCD NON -CRITERIA REPORTABLE AIR POLLUTANT ADDENDUM FORM TO REPORT SUCH POLLUTANTS OR POLLUTANTS NOT LISTED ABOV Signature of Person Legally Authorized to Supply Data: ped Name and Title: CHECK HERE IF YOU WISH THE DIVISION TO CALCULATE YOUR E IOSE ' "E ISSION ESTIMATES" INSTRUCTIONS ON BACK. Gerard G Alberts. Principal Environmen S" ialist THIS NOTICE IS VALID FOR FIVE YEARS. A revised'notice shall be filed prior to this expiration date, whenever a permit limitation must be modified, whenever control equipment is changed, and annually whenever a significant emission change occurs. For specific details see Regulation 3, Part A, ' I1.C.1. $119.96 FILING FEE IS QUIRED OR EACH NOTICE FILED. end completed forms with fees to: [ sQ "EAR FOR WHICH THE ACTUAL DATA APPLIES: Date source began or will begin operation: 2005 Colorado Dept. of Public Health & Environment APEN 13_of_ Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-131 For Information. Denver. Colorado 80246.1530 (303) 692.31 • • NON -CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM* (Instructions on reverse side) 02GA0014 — FLARE -3 AIRS Number 045103551*** Permit Number Company Name: Plant Location: Person to Contact: E -Mail Address: Williams Production RMT Company Near Parachute, Colorado Gerard G. Alberts i erre . alberts@wil l lams . coni County Garfield Zip Code 81635 Phone 303 572-3900 Fax 303 629-8275 Chemical Abstract Service Number Chemical Name Reporting Bin Control Equipment/ Efficiency Emission Factor (include units) Emission Factor source Requested Emissions fibs/yr) Actual Emissions from the Data Year (lbs/yr) 71-43-2 Benzene A Flash/Still 96% Flare 497 Ib/yr GLYCaIc 497 - p— p 1 Use this for .r reporting Hazard Signature ants, Ozo , *epletin Gerard Alberts Compounds. and other Non -Criteria Reportable Pollutant 7onsible Official not a vendor or consultant) Year For Which The Actual Data Applies: Date Principal Environmental Specialist Name ora Responsible Official (please print) Title • AItlitOLLUTANT EMISSION N�TIC� PERMIT No.: 02GA0014 AIRS ID. :Q45/O3365/*** �..,. FIRM NAME Williams Production RMT Com Jany MAIL ADDRESS l 15 Arapahoe Si. Tower 3, Suite 1000 STATE: CO ZIP: 80202 PLANT NAME & LOCATION PARACHUTE CREEK GAS,FLANT N Ih of NE IR Section 33 T6S R9f' COUNTY: GARFIELD REQUEST PORTABLE SOURCE PERMIT HOME -BASE FOR PORTABLE SOURCE -- PERSON TO CONTACT REGARDING THIS INFORMATION Mr. Gerard G. Alberts TITLE - Principal Environmental Specialist PHONE (30»572-3 GENERAL DESCRIPTION OF THIS PLANTS FUNCTION Natural Gas Processing EMAIL ADDRES errv.alberts@williams.cpm 900 A. GENERAL INFORMATION T Normal Operation of This Source ! Process Seasonal Throughput (% of Annual) ADDITIONAL INFORMATION OR REMARKS: Hours/Day 24 Days/Week 7 Weeks/Year 52 Dec -Feb 25 Mar -May 25 Jun -Aug 25 Sep -Nov 25 B. STACK OR VENT INFORMATION (Identify below which stack if plant has two or more: refer to attached sketch of plana layout) Height 15.0 Ft Diameter 0.1 ft Temperature Ambient 'F Flow Rate NA ACFM Velocity NA Wnun Moisture NA % Plant ID No. for Stack TK-SITK•6 C. FUEL INFORMATION _• Design input Rate Annual Fuel Consumption Fuel Heating Value: Percent by Weight Seasonal Fuel Use (% of Annual Use), Space (% Ar Description of Combustion Unit (IV BTU/hr) Kind of Fuel Burned Requested level Actual level (Data year level) (ETU/lb, BTU/gal, or BTU/scf) Sulfur Ash Dec -Feb Mar -May Jun -Aug Sep -Nov Make/Model: ' Serial No. _ _ _ D. PROCESS INFORMATION Raw Materials Used Raw Materials-Annua Consumption Design Process Rate Finished Product Finished Product•Annua Output Description of Processing Unit - Description Requested level Actual level (Data year level) (Specify Units/Hour) Description Requested level _ Actual level (Data year les- erPLANT PLANT3 CONDENSATE STORAGE TANKS 92,000 gallon/year 92,000 gal/yr Make/Model: - Sena! No.: – E. POLLUTION CONTROL EQUIPMENT Overall ESTIMATED EMISSIONS ACTUAL ESTIMATION CHECK ALL BOXES THAT APPLY Pollutant Type of Control Equipment Collection Efficiency (TONSIYEAR) AT THROUGHPUTS REQUESTED ABOVE EMISSIONS (from data year) METHOD I1 New or previously unreported source* • Requesting modification of existing permit t t Primary Secondary CONTROLLED UNCONTROLLED Change in emissions. throughputs or equipment t Particulate — NA NA. Transfer of ownership (List in REMARKS section of box A.) t PMaa NA NA previous owner Previous APEN is expiring. T SO. NA NA. Request for Emission Reduction Credit t t NO. - (Specify) NA NA ' Complete APEN VOC NA 20,4 E&PTANK2.t1 all applicable portions of t Complete ' Requested Level' values for permit limits CO NA NA 4 Complete all information above box A, and those remaining PLEASE USE APCD NON -CRITERIA REPORTABLE MR POLLUTANT ADDENDUM FORM TO REPORT SUCH POLLUTANTS OR POLLUTANTS NOT LISTED ABOVE CHECK HERE IF YOU WISH THE DIVISION TO CALCULATE YOUR EMISSI a - " E ' MI +: NSTRUCTIONS ON BACK, portions which reflect changes ignawure o Person Legally Authorized to Supply Data: �!4 l l r ry (� YEAR FOR WH]CH THE ACTUAL DATA APPLIES: yped Name and Title: Gerard G. Alberts, Princi, 1 Envi mental ecialist Dots source began or begin operation: 2005 HIS NOTICE IS VALID FOR FIVE YEARS. A revised notice shall be tiled prior o this expiration date, whenever a permit limitation must he modified, whenever ontrol equipment is changed, and annually whenever a significant emission hange occurs. For specific details see Regulation 3, Part A, . II.C.I. I A $119.96 FILING FEE IS REQUIRED FOR EACH NOTICE FILED, Send completed forms with fees to: Colorado Dept. of Public Health & Environment APEN 40_14_of_15_ Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-B1 For Information. Call Denver. Colnrartn AMA& t VIA r1A1' an-+ lien • • • NON -CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM* (Instructions on reverse side) Permit. Number 02GA0014 — TK-5IFK-6 Company Name: Plant Location:. Williams Production RMT Company AIRS Number 045/0365/*** Near Parachute, Colorado Person to Contact: Gerard G. Alberts E -Mail Address: i erre. alberts@wi 11 iamb . corn County Garfield Zip Code 81635 Phone 303 572- 3900 Fax 303 629-8275 Chemical Abstract Service Number ALL Chemical Name Reporting Bin Control Equipment/ Efficiency Emission Factor (include units) Emission Factor Source Requested Emissions (lbs/yr) Actual Emissions from the Data Year flbslyr) BELOW DE MINIMUS 41, Use this form for reporting Hazardous Air Pollutants. Ozone Depleting Compounds. and other Non -Criteria Reportable Pollutant Signatur o a '+ sponsi F le 0 li al (not a vert t r or consultant) Gerard G. Alberts Name of a Responsible Official (please print) Year For Which The Actual Data Applies: r Date Principal Environmental Specialist Title 411 • AIR POLLUTANT EMISSION NOTICE FIRM NAME Williams Production RMT Company MAIL ADDRESS 1515 Arapahoe St., Tower 3. Suite 1000 PLANT NAME & LOCATION PARACHUTE CREEK GAS PLANT N 1 of NE s/. Section;,. T6S. R96W PERMIT No.: 02GA0014 AIRS ID,:045/0365/* STATE: 10.192 COUNTY: GAPF1FE,D REQUEST PORTABLE SOURCE PERMIT HOME -BASE FOR PORTABLE SOURCE PERSON TO CONTACT REGARDING THIS INFORMATION r, Gerar G. Alber _TITLE Principal Environmental Specialist PHONE 5303)-572-3900 GENERAL DESCRIPTION OF THIS PLANTS FUNCTION Natural Gas Processing E-MAIL ADDRESS: lerry . al bert s@wi 11 Tams . corn A. GENERAL INFORMATION Normal Opera ion of This Source Process Seasonal Throughput (56 of Annual) ADDITIONAL INFORMATION OR REMARKS: Hours/Day 24 r Days/We I ck l 7 Weeks/Year 52 Dec -Feb 25 Mar -May 25 Jun -Aug 25 Sep -Nov 25 Plant 3 Fugitives B. STACK OR VENT INFORMATION (Identify below which stack if plant has two or more; refer to attached sketch of plant layout) - Height Ft Diameter ft Temperature °F Flow Rate ACFM , Velocity ft/min Moisture % Plant iD No. for Stack FUG -3 C. FUEL INFORMATION Design npput Rate Annual Fuel Consumption Fuel Heating Value: Percent by Weight Seasonal Fuel Usej% of Annual Use) Space. H' Description of Combustion Unit (IO° BTUIhr) Kind of Nei Burned Requested level Actual level (Data year level) (BTU/lb, BTUIgai, or BTiJlscf) - Sulfur Ash Dec -Feb Mar -May Jun -Aug Sep -Nov (% Ann _Make/Modfl'- - - - I Seriai No, _ D. PROCESS INFORMATION Raw Materials Used Raw Materials -Annual Consumption Design Process Rate Finished Product Finished Product-Annua Output Description of Processing Unit Description Requested level- , Actual level (Data year level) (Specify Units/Hour) Description _ Requested level Actual level (Data year level; PLANT 3 FUGITIVE VOC FROM EQUIPMENT LEAKS Make/Model: Sepal No.. • -t CHECK • New or previously unreported U Requesting modification • Change in emissions. Transfer of ownership (List previous owner Previous APEN is expiring Request for Emission (s if ALL BOXES THAT APPLY source of existing permit throughputs or equipment in REMARKS section I Reduction Credit t t t 1 t of box A.) t E POLLUTION CONTROL EQUIPMENT Overall ESTIMATE❑ EMISSIONS (TONS/YEAR) AT THROUGHPUTS REQUESTED ABOVE ACTUAL EMISSIONS (from data year) ESTIMATION METHOD Pollutant Type of Control Equipment Collection Efficiency Primary Secondary CONTROLLED UNCONTROLLED ' Particulate NA NA. P s7r4 NA NA. SO, NA NA. NO, NA ° Complete all applicable portions of APEN t Complete ' Requested Level' values for permit limits t Complete all information above box A, and those remaining Portions which reflect changes VOC LDAR 7$96 3l 12.4 AP 42 CO NA NA PLEASE USE APCD NON -CRITERIA REPORTABLE AIR POLLUTANT ADDENDUM FORM TO REPORT SUCH POLLUTANTS OR POLLUTANTS NOT LISTED ABO / CHECK HERE IF EM �* S. S YOU WISH THE DIVISION TO CALCULATE YOUR "E ION ES TES" INSTRUCTIONS ON BACK. — Signature of Person Legally Authorized to Supply Data: + - YEAR FOR WHICH THE ACTUAL DATA APPLIES: Typed Name and Title: - - Gerard G. Alberts. Principal Environmental - _ - Date source began or will begin operation: Specialist 2005 }warm m... '1E. NUMMI �.�Nra ,o - lub..1— - - Ili- - - — -s- A 1 THIS NOTICE IS VALID FOR FIVE YEARS. A revised notice shall be filed Prior to this expiration date, whenever a permit limitation must be modified, whenever control equippmens is changed, and annually whenever a significant emission change occurs. For specific details sec Regulation 3, Part A. " II,C.I. A $119.96 FILING FEE IS REQUIRED OR EACH NOTICE FILED. Send completed forms with fees to; Colorado Dept. of Public Health & Environment APEN ir_I5_of_15_ Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-B I For Information, Call Denver. Colorado 50246-1530 (301) 692.3150 • • NON -CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM* (Instructions on reverse side) 02GA0014 — FLARE -3 AIRS Number 045/0365/*** Permit Number Company Name: Plant Location: Person to Contact: E -Mail Address: Williams Production RMT Company Near Parachute, Colorado Gerard G. Alberts iierry,alberts@wllims.com County Garfield Zip Code 81635 Phone 303 572-3900 Fax 303 629-8275 Chemical Abstract Service Number Chemical Name Benzene Reporting Bin A Control Equipment/ Efficiency Flash/Still 96%497 Flare Emission Factor (include units) - lb/yr Emission Factor Source OLYCale Requested Emissions (lbs/yr) 497 Actual Emissions from the Data Year (lbs/tri 71-43-2 w.Use this form re. 'rung Hazardo it Pollutants, 0 Dep' ' Com .und Signature of , Re onsible Official (not a v ndcr or consult1 Gerard G. Alberts Name of a Responsible ©fiicial (please print) Reportable Pollutant Year For Which The Actual Data Applies: rr 4J Date Principal Environmental Specialist Title ATTACHMENT 2 Completed Form 1 and Form 1-A Notification of Initial MACT Applicability • Initial Notification Form [40 CFR 63.9(b)(2))1 Applicable Rule: 40 CFR part 63, subpart ZZZZ — National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (RICE MACT) Please read the rule for details on requirements and deadlines. Notification requirements are found in ' 63.6645 of subpart ZZZZ and ' 619 of the General Provisions as noted. Please note that you are not required to use this form and may submit the required information in a letter. However, all required information must be submitted by the following initial notification deadlines: • December 13, 2004 for sources whose startup occurs before August 16, 2004; OR • Not later than 120 days after startup, if startup occurs on or after August 16, 2004. Please print or type the following information for each source subject to the RICE MACT. 1. Name and Address of Facility Owner [40 CFR ' 63.9(b)(2)(i) and (ii)] Name of Facility: Parachute Creek Gas Plant Name of Owner/Operator: Williams Production RMT Company 1515 Arapahoe St., Tower 3, Suite 1000 Mailing Address: City: Denver County: Denver State: CO Zip Code: 80202 Physical Location (if different from mailing address) Street Address: 4289 County Road No. 215 City: Parachute County: Garfield State: CO Zip Code: 81635 Contact Person: Jerry Alberts Phone Number: Email: 303-606-4386 Jerry.alberts@Williams.com 2. Is the facility a Major Source [40 CFR §63.9(b)(2)(v))? Yes *(The facility is considered an area source and does not need to submit this X form) No* 2a. Do you intend to accept enforceable permit limits to reduce Yes* No emissions of hazardous air pollutants (HAP) to less than major source levels prior to the MACT compliance date(s) for X engines at this facility? *If ycs, please attach a description of the action(s) planned to achieve non -major status. NOTE: The description of action(s) planned to achieve non -major status is provided for information only and is not binding. If you take federally enforceable permit limits, prior to the subpart ZZZZ compliance date, to reduce total HAP emissions from your facility such that you are not longer a major source (as defined in 40 CFR ' 63.2), engines located at your facility will not be subject to the subpart (refer to the instructions). ' This form should be completed and submitted for new engines with a site rating greater than 500 horsepower (hp) that are located at major sources of HAP emissions. You art also required to submit this form for existing spark ignition 4 -stroke rich bum engines with a site rating greater than 500 HP that are located at major sources of HAP emissions. July 31, 2004 • 3. Relevant standard and compliance date [40 CFR ' 63.9(b)(2)(iii)] This facility operates RICE that are subject to 40 CFR part 63, subpart ZZZZ (check one): X Yes No Subpart ZZZZ requires you to submit an initial notification for new engines with a site rating greater than 500 horsepower (hp) that are located at major sources of HAP emissions. You are also required to submit an initial notification for existing spark ignition 4_ stroke rich burn engines with a site rating greater than 500 HP that are located at major sources of HAP emissions. Therefore, it is not necessary to list all engines located at a given facility. Complete the following table for each engine for which initial notification is required under 40 CFR part 63, subpart ZZZZ (attach additional copies of this page as needed). Engine ID Engine Description Site -Rated Horsepower (hp) Existing/New/ Reconstructeda Subpart ZZZZ Subcategoryt' Subpart ZZZZ Compliance Date Initial Notification Only?` Manufacturer Model ENG -17 Caterpillar G3612 TALE 3210 New 6 Upon Installation X Yes 0 No ENG -18 Caterpillar G3612 TALE 3210 New 6' Upon Installation X Yes 0 No ENG -19 Caterpillar G3612 TALE 3210 New 6' Upon Installation X Yes 0 No ENG -20 Caterpillar G3612 TALE 3210 New 6' Upon Installation X Yes 0 No ENG -21 Caterpillar 03612 TALE 3210 New 6' Upon Installation X Yes 0 No ENG -22 Caterpillar 03612 TALE 3210 New 6' Upon Installation X Yes 0 No ENG -23 Caterpillar 03612 TALE 3210 New 6' Upon Installation , X Yes 0 No ENG -24 Caterpillar G3612 TALE 3210 New 6' Upon Installation X Yes 0 No a Refer to the definition for existing, new, and reconstructed included in the instructions for this form h Use the subcategories included in the instructions for this form. If yes, attach rationale to explain why each engine had no additional requirements under subpart ZZZZ (e.g., engine operates as an emergency stationary RICE). 1 The eight proposed engines (ENG -17 -ENG -24) are all new 4 -stroke lean burn units not yet in operation; all engines must be in compliance with MACT applicable limits beginning at engine startup slated for the fall of 2006. 2 July 31, 2004 4. For the stationary RICE listed in question 3, provide a list of the HAP emitted [40 CFR §63.9(b)(2)(iv)l. 1. Benzene 7, 2. 3. 4. 5. Toluene Formaldehyde Acetaldehyde Acrolein 8. 9. 10. 11. 6. Formaldehyde 12. 5. Signature I certify that the information contained in this form to be accurate and true to the best of my knowledge. Authorized Signature Typed or Printed N Title of Signatory Please mail this completed form to both your State Air Pollution Control Office and your EPA Regional Office 3 July 31, 2004 • • Form 1 Initial Notification of MACT Applicability Company Name: Williams Production RMT Company Company Address: 1515 Arapahoe St. Tower 3, Suite 1000 Denver, CO 80202 Company Phone: (303) 572-3900 Company Fax: (303) 629-8255 Source Address (physical location) NE 1/s NE '/a Section 33, Township 6 South, Range 96 West Garfield County, Colorado 81901 Relevant Standard: 40 CFR SUBPART HH ONG MACT Compliance Date: UPON STARTUP Existing Construction/Operation Permit Number (optional):02GA0014-MODS Source Description: (Le., Nature, size, method of operation, design, operation design capacity, etc.) ETHYLENE GLYCOL NATURAL GAS DEHYDRATION SYSTEM, SOURCE ID DEHY-4. DESIGN RATE OF 300 MMSCFID GAS THROUGHPUT. FLASH TANK ROUTED TO FLARE -3 AND STILL VENT TO CONDENSER WITH CONDENSER OUTLET ROUTED TO FLARE -3 WITH 96% DESTRUCTION AND REMOVAL EFFICIENCY. Major or Area Source: EIC Major Source Area Source Major Source Planning to be Area Sources by: _n • Completed by: Date: Regulatory Citation: 40 CFR 63.9 (b)(2) Page 1 of 1 Form 1 • ATTACHMENT 3 Revised Emissions Inventory Spreadsheet and Supporting Calculations ri0AIFICATION Fuel Gas Healing Value r 1040 8tufscf Serial Maximum Horsepower Heal Heat Fuel Fuel Volumetric Exhaust Exhaust Slack Stack Exhaust Number Operating SIteRating Input Rene Use Use Flow Velocity Velocity Diameter Height Temp. Hou rs'Yr Hp MMOtufhr 9tulHp-hr scffhr AtMier r acfm Wm In Moe feet feet deg. F. NI +c] — 4 84716 8760 700 5.46 7000 5254 45.99 6100 3452 57.5 1.50 23.00 482 84702 8760 700 546 7800 5254 45.99 6100 3452 57.5 1.50 23.00 482 84685 8760 700 5.46 7800 5250 45.99 6100 3452 57.5 .50 23.00 482 84788 8760 336 2.62 7800 2520 22.08 2896 2709 45.2 1.17 23.00 435 84787 8760 336 2.62 7800 2520 22.08 2896 2709 45.2 1.17 23.00 435 84781 8760 336 2.62 7800 2520 22.08 2896 2709 45.2 1.17 23.00 435 84946 8760 700 5.46 7000 5250 45.99 6100 3452 57.5 1.50 23.00 482 84934 8760 700 5.46 7800 5250 45.99 6140 3452 57.5 1.50 23.00 482 3RC00908 8760 1145 9.16 8000 8808 77.16 7685 9785 1611 1.00 23.00 855 C Gy r 4. 10KE00264 8760 3210 21,70 6760 20865 182.78 23461 13276 221.3 1.50 28.00 858 f1KEf10265 8760 3210 21.70 6760 20865 182.78 23461 13276 221.3 1.50 28.00 858 6KEf13263 8760 3210 21,70 6760 20865 182.78 23461 13276 221.3 1.50 28.00 850 Unkrto.n 8760 3210 2170 6760 20865 182.78 23461 13276 221.3 1.50 28.00 858 _ t `en 67.5 4 000000000000000, 1 88888888 .5.5.5.5.5 00 m 00 ra N ra [a N N Nea 000000.0....!0 lin . .n ,n anco fa Iva N N P1 N ra ry h Pa a' fV fra 01 r r Nr r b r- r Ca 4,1 N H el fa ea N ....irl M1 l r1 rl c-, b •Q 4T r ev 01 lea 0 N N N P1 000 to ea m ao ad 5L N a ra ra ei H fy N 0 W C BO a Fa W .1 aa a0 r1 v1 n •/?h a? .04. ^P ^4 ^P v? v`1 +G 0 0 O 0 0 C 0 a $$$$$$$$ Ma W M) ^a? •Lr e 6 C e o O e FC re M e^a .--a N ri N ra o o 0 0 0 0 0 0AC en an , .1 r-..-1 en en 00822228 rr Oa. o0 as 00 ao ou 3 3i 3 3 3 3 3 3 5 r F 2 5 2 _-g ts2 x x i' Le b 47 4 IGEN-I.2 Electrical Generators C.iuriair 1316 TALE 1 Unknown 10000 1145 4.16 8000 8808 41.60 7685 _ 9785 - 163.1 1 00 12 25 833 O 4X445 8 8 0 0 S. pp 9• .� a as Yf f, ^C 4. p +[. L a9 4 7 $ G S — 5 4 y w w ai d 8. 8 0 o , G] °O N c -a - an as eh < 4 r• ` $ mn 7 m O z 5 0.. n9. x .. e X I Y Y. 8 8 0 0 —y N 14 cr ea z< 'z' Y ., I, S 0 2 S 0. V 1.1 s e it C c c 6 3 E c r " w Y E ) Ce c a— Cr "a u 1ENG-71 Rctrdue Recompre. Ali DPC 2804 LE ENG -02 Residue Recompres.. A3ax DPC 2804 LE ENG -03 Residue Recompreee Alas DPC 2804 LE ENG -04 Propane Refng. Alas DPC 2802 LE ENG -05 Propane Re frig. Ajax DPC 2802 LE ENG -06 Propane Rang. A)u DPC 2802 LE ENG -09 Residue RecommitRecommitAps OPC 2404 LE w SCO Cat ENG -10 Residue Recompretr. Apt OPC 28154 LE w SCOCai ENG -11 Residue Recompresr. Coo/villal. 7516 TALE w8CO O ENG• 17 Residue Recunlpress. Cslrrpd1e/ 3612 LE TA.I30 w SCO ENG -18 Residue Recompreu. Cstap4IIM 1612 LE TA. 130w SCO ENG -19 Residue Recompress. C.Iv7Mllsr 3412 LE TA.1311w 500 ENG -20 Residue Recompten. Cslv11l0i 3412 LE TA• 1.10 w SCO ENG -21 Residue RccOmpreit. Cuvjillar 3412 LE TA.1311 w SCO ENG -22 Residue Recumprest. C.Icrpulsr 3412 LE TA•130w SCO ENG•23 Residue Recomprm. Catalano 1412 LE TA.1.t0 w 500 ENG -24 Reildue Recompresa. Csrvplll.r 114 12 Le TA•I3O w SCO CHUTE CREEK GAS PLANT • JULY 2005 FLA111 JDIFICAT[ON Equipment Assigned Emiselon Unit ID No. Field Descripllon Service Serial Number Maximum Operating Hours/Yr Horsepower S1teRating Hp Heat Input MAfllturhr Fuel Gas Heating Value ■ Heal Fuel Rale Use 8Iu/Hp-hr scllhr 8040 Fuel Use MMsellyr Slu/wf Volumetric Exhaust Exhaust Stack Stack Flow Velocity Velocity Diameter Height actm f1/min ft/see Leel feet Exhaust Temp. deg. F. Plant 1 Anon, Sweetening Unit - -- - - — AMINE -1 Amine Sweetening Plant 1 Amine lis etening Unit 1 NA 8760 NA NA NA NA NA Emission Poinu are FLARE -1 and T0-1 Mont 2 Amine Sweetening Unit AN1lNE•2 Amine S.'eetenin: Plant 2 Amin 8wxetenfn Unit NA 8760 NA NA NA NA NA Emission Points are FLARE -2 and TO.1 Plant 3 A Sweetentng link - AM1NE-3 Amine Sweeten', Plant 3 Amine Sweelening Unit 1 NA 8760 NA NA NA NA PIA Emission Points are FLARE -3 and TO -2 Fust 1 Dehydratton OW — - DEHY-1 Gar Dehydration Plan) 1 EG Dehydration Unit 1 T-454 8760 NA NA NA NA NA Emission Point is FLARE -1 • Plant 2 Dehydration Unlit DEHY-2 Gas Dehydration Plant 2 60 Dehydration Unit DEHY-3 Gu Dehydration Plant 2 TEG Dehydration Unit NA NA 8760 8760 NA NA NA NA NA NA NA NA NA NA Emission Point is FLARE -2 Emission Point is FLARE -2 Plant 3 Dehydration Vitt, DENY -4 Gas Dehydration Plant 3 EG Dchydnation Unit 1 NA 8760 NA NA NA NA NA Emission Point is FLARE -3 Plant 1 Flare FLARE -1 Process Flare Plant 1 Process & Upset Flare 1 t}ISSUFAS 8760 NA 13.2 NA 245 2.15 NA NA NA 3.00 75.00 800 Plant 2 Flare - - FLARE -2 Process Flare Plant 2 Process & Upset flare j tr- nawn 8760 NA 28.3 NA 245 2.15 _ NA NA NA 3. 75,00 800 Plant 3 Flare FLARE -3 Process Flare Plant 3 Process & Upset Flare FUnknown 8760 NA 16.0 NA 245 2.15 NA NA NA 3.00 75.00 800 Plant f and Plans 2 Thermai O.aditer TO.1 VOCciNnypNicv arravery Pont i end mini 2 Thirniel Qrtdux I Unknown 8760 NA 18.0 NA 17308 151.62 NA NA NA 2.50 75.00 1600 Plant 3Thennai Oxidizer TO -2 Vneca,voinkc,i R *y PIInI 3 Thermal Oxidizer IlTnjtnowlt 8760 NA 27.0 NA 25962 227,42 NA NA NA 2.50 75-00 1600 ,, Plans 1 Tank: - _ - TK-I/1K-2 Condensate Storage Plant 1 Cond Storage Tanks f NA 8760 NA NA NA NA NA NA NA NA 0.17 15 Ambient Plant 2 Tanks TK-3/TK-4 Condensate Siang Plant 2 Cond. 5corav Tanks ! NA 8760 NA NA NIA NA NA NA NA NA 0 17 15 Ambient Plana J Tapirs TK-5/TK-6 Condenute Storage Plant 3 Cond Storage Tanks 1 NA 8760 NA NA NA NA NA NA NA NA 0 17 15 Ambient Plant 1 laadaur LOAD -1 Condensate Loadout Exempt Plant 1 Cond. Loadout LOAD -2 NGL Product Losdetui Exemeb Plant 1 NGL Loadout NA NA 12 1517 NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA Plant 2 laadaw: LOAD -3 Condensate Loadout Exempt Plant 2 Cond. Loadoui LOAD -4 NGL Product Loadout Exempt Plant 2 NGL Lcadoul NA , NA 22 3034 NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA Plant 3 Laadaut LOAD -5 Condensate Loadaut Excrrtpt Plant 3 Cond. Loadoui LOAD -6 NGL Product Loudoui Exempt Pians 3 NOL Loadout ' NA NA 22 3034 NIA NIA NA NA Nil NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA Pian! 1 FugaJvea 1110.1 Equipment Leaks__ PI an% 1 Fugitive VOC 1 NA 8760 NA NA NA NA NA NA NA NA NA NA NA Pian! 2 Fugitive: — FL'G•2 Equipment Leaks _ Plant 2 Fugitive VOC 1 NA 8760 NA NA NA NA NA NA NA NA NA NA NA Placa! 3 Fugitive: FUG -3 Equipment Leak' Plant 3 Fugitive VOC 1 NA 8760 NA NA NIA NA NA NA NA NA NA NA NA * AACHUTE CREEK GAS PLANT JULY 2005 Pt ..ODIFICATION Equipment Fldd ID No. Service Emission U011 Description gibhp•hr NOx Ib/hr ion/yr BPohp-hr CO ib/dr ton/yr BPohp-hr VOC Iii: ion/yr 1b1841111u Pest lo/rsr Ibiter 1onnrr Jb 41811Hu sox 16 hr 10n/yr r Pivot f Engines - - - ENG -OI Residue Recompreu. Ajax DPC 2804 LE 13 2.31 10.1 1.3 2.01 8.8 1.3 1.938.1 0.04831 0.26 1.2 0.00059 0.00 0.0 ENG -02 Residue Recompress- Ajax DPC 2804 LE 1.5 2.31 10.1 1.3 2.01 1.8 1.3 1.93 8.4 0.04831 0.26 1,2 0.00059 0.00 0.0 ENG -03 Residue Recomprms. Ajax DPC 2804 LE 1.5 2.31 10.1 1.3 2.01 1.1 1.3 1.93 L4 0.04831 0.26 1.2 0.00059 0.00 0.0 EN4-04 Propane Refits. Ajax OPC 28021.E 2.0 1.48 6.3 2.0 1.41 6.3 1.6 1.19 5.2 0.04831 0.13 0.6 0.00059 0.00 0.0 ENG -05 Propane Refrig. Aju DPC 2802 LE 2.0 1.48 63 2.0 1.48 6.3 1.6 1.19 3.2 0.04131 0.13 0.6 0.00059 0.00 0.0 ENG -06 Propane Refer". Ajax DPC 2802 LE 2.0 1.48 63 2.0 1.41 6.3 1.6 1.19 5.2 0.04831 0.13 0.6 0.00059 0.00 0.0 ENG -09 Residue Recompreu. Nis DPC 2804 LE w SCO Cat , 1.5 231 10.1 0.7 1.10 4.8 13 1.93 8.4 0.04831 0.26 1.2 0.00059 0.00 0.0 ENG -10 Residue Recampreu. Or DPC 2804 LE w SCO Car 1.5 2.31 10.1 0.7 1.10 4.$ 1.3 1.93 8.4 0.04831 0.26 1.2 0.00059 0.00 0.0 ENG -11 Res idea Recampreaa. Caterpillar 3316 TALE w SCO 1.3 3.79 16.6 0.13 0.34 1.5 0.10 0.25 1.1 0.00999 0.09 0.4 0.00059 0.01 0.0 Plant 2 Engine: ENG -13 Residue Recompresa. caara 1a 34u LE rA.130 w sto 0.7 4.95 21.7 0.18 1.24 3.4 0.1 0.69 3.0 0.00999 0.22 0.9 0.00059 0.01 0.1 ENG -14 ResidueRaamprus. CampelvMtlLSTA.tw.KO 0.7 4,95 21.7 0.18 1.24 5.4 0.1 0.69 3.0 0.00999 0.22 0.9 0.00059 0.01 0.1 ENG -15 Residue R compreee. Carreras 3411 Le TA•I b r 3Cr3 0.7 4.95 21.7 0.18 1.24 5.4 0.1 0.69 3.0 0.00999 0.22 0.9 0.00059 0.01 0.1 ENG -16 ResidueRecampress. Cm II..3ntlLETA.13rr.:C11 0.7 4.95 21.7 0.18 1.24 3.4 0.1 0.69 3.0 0.00999 0.22 0.9 0.00059 001 0.1 Plant 3 Engine: _ ENG -17 ResidueRocampreu. Cawrpair5a11LaTA•lanwSC0 0.7 4.95 21,7 0.18 1.24 5.4 0.1 0.69 3.0 0.00999 0.22 0.9 0.00059 0.01 0.1 ENG -18 Residue RUC minas. Crmxlur 3611 LE TA• 1.35 w scn 0.7 4.95 21,7 0.18 1.24 5.4 0.1 0.69 3.0 0.00999 0.22 0.9 0.00059 0.01 0.1 ENG•19 Residue Rec.mpren. Guava Y]4HILETA. l30wSCr1 0.7 4.95 21.7 0.18 1.24 5.4 0.1 0.69 3.0 0.00999 0.22 0.9 0.00059 0.01 0.1 ENG -20 Residue Recta mpress. Cvvplav3a13LETA430.sCo 0,7 4.95 21.7 0.18 1.24 5.4 0.1 0.69 3.0 0.00999 0.22 0.9 0.00059 0.01 0.1 ENG -21 Residue Recampress. Camilla, 3411 L8Th. l3o.$CIt 0.7 4.95 21.7 0.18 1.24 5.4 0.1 0.69 3.0 0.00999 0.22 0.9 0.00059 0.01 0.1 ENG•22 Residue Recomptets. comae 1411 LSTA•13aw:cn 0.7 4.95 21.7 0.18 1.24 5.4 0.1 0.69 3.0 0.00999 0.22 0.9 0.00059 0.01 0.1 ENG.23 Reaid ue Rumple -as. C.wpnv sill Lz 74. Lao . sen 0.7 4.95 21.7 0.18 1.24 5.4 0.1 0.69 3.0 0.00999 0.22 0.9 0.00059 0.01 0.1 ENG -24 Residue Recompress. camas,. 1413 Ls rA• ran. sco 0.7 4.95 21.7 0.18 1.24 5.4 0.1 0.69 3.0 0.00999 0.22 0.9 0.00059 0.01 0.1 Plant 1 Electrical Generatere GEN -I.2 Etamal Cnm.tert Caterpillar 3516 TALE I 1.7 4.29 21.5 1 2.00 5.05 25.2 0.50 1.26 6.3 ( 0.00999 0.09 0.5 0.00059 0.01 0.0 Plan' 1 Heaters 100.0 16//t4 Mid 84.0 lb/Maim' 5.5 Ib77v1Mrcf 7.6 Ib/MMscr 0.6 Ib/MMscf HTR.I Process Heater Plans 1 Hou 011 Heeler _ J NA 2.60 11,4 L NA 2.18 9.6 l NA 0.14 0.6 1 NA 0.20 0.9 1 NA 002 0.1 Ptanf 1 Hearer: HTR•2 Process Hester Plan! 2 Hat Gil Heater 1 NA 5 19 22 7 ! NA 4 36 19.1 J NA 0.29 1.3 4 NA 0.39 i 7 NA 0 03 0.1 Pfanr 3 Heater: H7R-3 Process Heater PIan13 Hot Gil Healer 1. NA 5.77 25.3 1 NA 4,85 21.2_ J NA 0.32 1.4 1 NA 0.44 1.9 1 - NA 0.03 0.2 NOx CO VOC PMIO/TSP SOx g/bhp-hr Ib/hr ton/yr 8/bhp-hr Ib/hr ton/yr g/bhp-hr Ib/hr ton/yr Ib/MMBtu lb/hr tors/yr Ib/MMBtu Ib/hr ton/yr Plant 1 Amine Sweetening Unit AMINE -1 Amine Sweetening Plant I Amine Sweetening Unit I NA NA NA ( NA NA NA 1 Reported Under FLARE -1 and TO -11 NA NA NA I NA NA NA Plant 2 Amine Sweetening Unit IAMINE.2 Amine Sweetening Plant 2 Amine Sweetening Unit NA NA NA 1 NA NA NA 1 Reported Under FLARE -2 and TO -II NA NA NA 1 NA NA NA Plant 3 Amine Sweeten/ng Unit 1AMINE-3 Amine Sweetening Plant 3 Amine Sweetening Unit NA NA NA I NA NA NA 'Reported Under FLARE -3 and TO -21 NA NA NA 1 NA NA NA C 3 a a q `e a [DENY -I Gm Dehydration Plant 1 EG Dehydration Unit 1 NA NA NA 1 NA NA NA 1 Reported Under FLARE -1 1 NA NA NA I NA NA NA 1 (Plant 1 Dehydration Unit 1 << Z z << Z Z << zz IPlont 3 Dehydration Unit < z < Z < z O o $ o < z t `e 4 FLARE -2 Process Flue Plant 2 Process& Upset Rare 1 NA 0.44 1.9 1 NA 2.40 10.5 1 NA 1.92 8.4 1 NA 0.00 0.0 1 NA 0.00 0.0 Plant 3 Flare 1 NA 0.00 0.0 o 0 $ o < Z o O $ 0 < Z -0 Id `e 0.. rITK-I/PK-2 Condensate Storage Plant I Cond Storage Tanks NA NA NA 1 NA NA NA I NA 2.33 10.2 1 NA NA NA 1 NA NA NA 1 (Plant 2 Tanks I TK -3/1-K-4 Condensate Storage Plant 2 Cond. Storage Tanks 1 NA NA NA 1 NA NA NA .1 NA 466 20.4 1 NA NA NA [ NA NA NA Plant 3 Tania < Z < Z < Z Z < z < z O N 43 v Z < Z < z < z < z z < z 1 m e; G N U a m ` o 0 u '�! � o 0 a b 07. . : `e F 4 << Z Z << ZZ << ZZ [Plant 2 Loadout << Z Z << Z Z << ZZ a bto 3li `c 4 << Z Z << Z Z << ZZ . C 0. IFUC•i Equipment Leaks Plant 1 Fugitive VOC NA NA NA 1 NA NA NA 1 NA 0.76 3.3 1 NA NA NA 1 NA NA NA I Plant 2 Fugitives FUG -2 Equipment Leaks Plant 2 Fugitive VOC NA NA NA 1 NA NA NA 1 NA 0.72 3.2 1 NA NA NA 1 NA NA NA Plant J Fugitives < ea Z- < Z < Z Z n < z < z na• e•n G Z < n Z N < z < Z < PIPI z» z < Z [I > LL Ey t v 5 t U l- } zz <<< zz <<< zz z z z NA 000 0.0 I NA 0.00 0.0 o o < z o ' 0 < z ZZ << zz << zz ZZ << zz << zz ZZ << zz << zz M (V la W g E EE C o"ea" Reported Under FLARE -3 1 n • a O 0 Z n ei .o0 O Z O O O < O O 0 O — CO 0 ro 0 — ZZ N NO O— o^,, 0 y— ZZ N `0 •0 0— a o -4— ZZ < < Z Z < < Z Z < < Z z < Z < z < Z NA 0.82 3.6 1 - co —• < z e .d — < z ? a n < z < < ZZ < < ZZ < < 2Z < < ZZ < < Z2 < < zz < < Z2 < < 2 Z < < ZZ < < Z Z zz < < zz DEHY-4 Gu Dehydration Plant 3 EG Dehydnation Unit I NA NA NA t `e 4 n o 0 < z '' ri is D As V O a u g m x a —,k < IFLARE-3 Process Flare Plant 3 Process & Upset Flare 1 NA 0.34 1.5 [Plant 1 and Plant 2 Thermal Oxidizer P n - < z v O E NC a F 0 > — � [Plant 3ThennalOxidizer TO -2 vnccawank« R«o.ar Plant 3 Thermal Oxidizer 1 NA 2.70 11.8 < < ZZ zz < < ZZ < < ZZ zz < < ZZ < < ZZ zz < < ZZ Equipment Field Emission Unit ID No. Servke Description DEHY-2 Gas Dehydration Plant 2 EG Dehydration Unit DENY -3 Gas Dehydration Plant 2 TEG Dehydration Unit LOAD -I Condensate Loadout Exempt Plant I Cond. Loadout LOAD -2 NGL Product Loadout Exempt Plant 1 NGL Loadout LOAD -3 Condensate Loadout Exempt Plant 2 Cond. Loadout LOAD -4 NGL Product Loadout Exempt Plant 2 NGL Loadout LOAD -5 Condensate Loadout Exempt Plant 3 Cond. Loadout LOAD -6 NGL Product Loadout Exempt Plant 3 NGL Loadout A e 3 h d 3 tk X 3 se S C V l W c i 0 DO a0 Ya M rV 44 7 7 0 ▪ .4 t4 ri 6 46 46 o- O 0 0 0 0 0 0 0 a O a a 0 0 0 0 0 ,pp p .0,7 M' M M C4 ry f'4 ry 0 0 0 0 O 0 0 0 o 0 0 0 0 0 0 00 0 M r+Y M M el M '0 �. •• 0002 CP ,5 000000000 oo0000000 riN N r vl x r rr 0 V1vlM, N NM M O O o 0400000 000000000 AA arlr,.1m mK, • i s- r- OOO^ta A4ZO 0 N N N o 0 0 -- 0 aB m m v@v� qr t �.1 7 Yw, P P P 7 i 3 r V~ • 0 O O O O 000040000 ---.n,r'1-- cn rV CY r m .1 m m A ry ✓ rA • fl NO 0 CO 0 0 0 0 0 0 0 00 au as'0h r ✓ 1 N ry 0 0 0 0 6 C. 0 0 0 cis u U rg+agcSo 3 H M rmi N N r(1 w w 1- 7777! nr. N r+ caoOO 0000 777 eV N 7777 rt.-sr-arc r H ry eV 0 0 0 0 0 0 o o O 0000000 eh h w h 0000 o o 0 0 7"?.!, VV..* 4, 4) .i 41 vi ✓i .l ✓l 0 v o 0 00 0 0 0 0 0 0 0 0 0 ap m v0 ery 90 �D 0000 Dodo r1n.nn 0606 0000 0000 b .G .O 0 o 0 o 0 r -r4 r- r- 7777 - 7747 0000 P d P o' vl� i vw 0000 60.6o 0 0• 0 0 0 0 0 0 6 a a 0 0 0 0 0 A n nton .a A n 00000000 0 0 o O 0 0 0 0 00000000 0000000p r- r- r- r- r- r r 7 7 7 7 7 7 7 7 o 0 0 a 0 0 0 0 h e vi vi of of n e o O o 0 0 0 O O O o 0 0 o 0 0 0 O O o 0 0000 M.1 0 0 0 0 0 0 0 Cr 0 0 0 0 0 0 0 0 !V N M ry H rte! H H 6666 66660666 10110 R A R S.R A Ki s. fyn 55 y11 - f M d gE 0 0 a 0 4 u Y acczz 3333 Gaza Z. ActAA 666 Z Z Z s 7 0 w 0 w k yggg � 6 6 E EEEEEEE u 0 d :t 0 szzoexctxot '0 o'a74 a _e'0 ry r+ N N rV 6 6 e5 0 0 6 0 0 z z z z z z z z w w w w w 0 01 01 a (74 t3 a 4 0 7 ry 0 O Caterpillar 3516 TALE Elcarlcat Qerrni n 01 0 Plana 1 Nearer 4 z Z 0 t z s Z C x 7 Plant 1 Hot Sail Heater Prices' Hester Plant 2 Neasere b 0 4 z Pians 2 Hoi (3i1 H Prowess Heater Plan( 3 Near'' O 0 4 7. z ILCHUTE CREEK GAS PLANT • JULY 2005 PL1110 A.JDIFICATION Equipment FIe1d ID No. Service Emission Unit Descrl . don Iain A Bin C Acetaldehyde to r I. r Acrotein ton/yr Ib/ r Benzene to ' r tdry Fornukiehyde ton/yr 1 • tors! Elhylbenxeae r l e/vr n•Hetane Toluene to r 1, to r Bs/ r Isomers of Xykne to r Ibl r Plant I Amine Swrttsning Unit AMINE• 1 Amine Sweetening PIant I Amine Sworlening Unit Re ed Under FLARE -I and TO- MO/It 2 Amine et Ong Unit - AMINE -2 Amine Sweetening Plant 2 Amine Sweetenin,g_Unii - Reported Under FLARE -2 and TD -1 - ?innt J Amine Swrsetneng Unit AMINE -3 Amine Sweetening Plant 3 Amine Swetiteng Unit f Reponed Under FLARE -3 and TO -2 Plane 1 Dehydratio Lena DENY -1 Gas Dehydration Plant 1 00 Dehydration Unit J Reported Under FLARE -1 Plant 2 Dehydration Unite DENY -2 Gas Dehydration DENY -3 Gas Dehydration Plant 2 EG Dehydration Unit Plant2 TEG Dehydration Unil Reported Under FLARE -2 Reported Under FLARE -2 Plan! 3 Dr ration Unix DEIFY •4 Gat Dehydration Plant 3 EG Dehydrtatlon Unit 1 Reported Under FLARE•3 Plant f Pk+n FLARE -I Process Place Plum 1 Process & Upset Flare 1 - NA NA NA NA 0.1 286.5 NA NA 0.0 5.3 0.0 13.1 0.0 80.6 0.0 49.1 Plant 3 Plan FLARE -2 Process Flare Plant 2 Process & Upset Flare 1 NA NA NA NA 01 167.9.4 NA NA 0.0 6.I 0.1 257.5 0.8 1526,0 0.1 291 7 Pians 3 Plan - - Pi ARE. 3 Process Flare Plant 3 Process & Upse1 flare 1 NA NA NA NA 0.2 496.7 NA NA 0.0 8.8 0.0 23.7 0.1 125.3 0.0 87.6 Plans 1 and Pktnt 2 Thermal Oxkfkrr TO -I vtrCCnwno.or tPPi n t ins Plan 2 Thenyl Oalaux J NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA Plane 3Thermo/ Oxidizer TO.2 vt}[cenuruinu.va Plant 3 Thermal Osidixer - J NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA Plant 1 Tanks- anksTK. TR.1fTK•2 Condensate Storage Plant 1 Cond. Storage Tanks 1 NA NA NA NA 0.1 131.4 NA NA 0.0 8.8 0.2 403.0 0.1 166.4 0.0 43 8 Peat 2 Tonkr - TX X-4 Condensate Storage PIant 2 Cond. Storage Tante 1 - NA NA NA NA 0.1 254 0 NA NA 0.0 8.8 0.4 805.9 0,2 332 9 0.0 87 6 Plant 3 Tanks TK•31TIE•6 Condensate Storage Plant 3 Cond. Storage Tanks 1 NA NA NA NA 0.1 254.0 NA NA 0.0 8.8 0.4 805.9 - 0.2 332.9 0.0 87.6 a Platte 1 Candour LOAD -1 Cwxlraaate I.(re,Ai LOAD.2 NOL Pr.wce t wftit Exempt Plast l Cond. Loadout Exemps Plant 1 NGL_ Laadous NA NA NA NA NA NA NA NA NA 0.0 NA 15.9 NA NA NA NA NA 0.0 NA 0.0 NA 0.0 NA 15.9 NA 0A NA 15 9 NA 0.0 NA 15.9 Plan! 2 Loadose LOAD -3 Condon=toenwt LOAD -4 NGL Pnaluet Lrad.rt Exempt Plant 2 Cond. Laadout 1._NANA Exempt Mani 2 NGL Loadaut NA NA NA NA NA NA NA 0.0 NA 31.9 NA NA NA NA NA 0.0 NA 0.0 NA 0.0 NA 31.9 NA 0.0 NA 31.9 NA 0.0 NA - 31 9_ i. none 3 Laadaul - LOAD -5 Cyneurris i L hydroLOAD-6 hydrotardcwt Exempt Plant 3 Cond. Loadout Exempt Plant 3 NGL Loadout I NA NA NA NA NA NA NA NA NA, 0.0 NA 31.9 NA NA NA NA NA 0.0 NA 0.0 NA 0.0 NA 31,9 NA 0.0 NA 31 9 NA 0.0 NA 31 9 Plane 1 Puginrex _ FUG -1 Equipment Leaks Plant 1 Edgily,. e VOC NA NA NA NA 0.0 11.6 NA NA 0.0 0.0 0.0 48 9 00 20.0 0.0 5 7 Plane 2 Pnetters FUG -2 Equipment Leaks Plant 2 Fugitlre VOC 1 NA NA NA NA 0.0 1 t.6 NA NA 0.0 0.0 0.0 48.9 0.0 20.0 0.0 5 7 �• PWne 3 Fxgftirrs FUG -3 Equipment Leaks Plant 3 Fugitive VOC 1 NA NA NA NA 0.0 10.6 NA NA 0.0 0.0 0.0 44.3 0.0 18 1 0.0 3.2 TOTAL tspyt _ 2.1 1.7 1.9 16.8 _ 0.9 2.5 1.5 0.1 TOTAL AGGREGATE HAP {lpy): HIGHEST SINGLE HAP flpy): 27.0 16.8 Formaldehyde - PARACHUTE CREEK GAS PLANT • 7/13/2005 JULY 2005 PLANT 3 MODIFICATION PARACHUTE CREEK GAS PLANT INLET GAS COMPOSITION Date of analysis: 04119/101 Analysis ID 36227260 Pollutant Molecular Volume Gas Weight Corrected 1 Weight Percent Weight Fraction Wt. Fraction (113/1b -mol) (%) (lb/lbmol) (%) (%) Methane 16.01 89.70% 14.3610 78.43% 82.17% i Ethane 30.02 5.54% 1.6631 9.08% 9.52% Total HC (Non-VOC) 95.24% 87.52% 91.69% Propane 44.03 1.47% 0.6472 3.54% 3.70% i -Butane 58.04 0.33% 0.1927 1.05% 1.10% n -Butane 58.04 0.31% 0.1805 0.99% L03% i -Pentane 72.05 0.14% 0.0973 0.53% 0.56% n -Pentane 72.05 0.11% 0.0764 0.42% 0.44% n -Hexane 86.06 0.04% 0.0361 0.20% 0.21% Other Hexanes 86.06 0.10% 0.0867 0.47% 0.50% Heptanes 100.07 0.11% 0.1088 0.59% 0.62% Octanes + 114.08 0.00% 0.0000 0.00% 0.00% Benzene 78.1 0.01% 0.0086 0.05% 0.05% Toluene 92.1 0.02% 0.0147 0.08% 0.08% Ethylbenzene 106.2 0.00% 0.0000 0.00% 0.00% Xylenes 106.2 0.00% 0.0042 0.02% 0.02% Total NMNE VOC 2.64% 7.94% 8.31% Carbon Dioxide 43.99 1.70% 0.7478 4.08% NA Nitrogen 28.02 0.11% 0.0305 0.17% NA Hydrogen Sulfide 34.06 0.00% 0.0000 0.00% NA Water 18 0.30% 0.0538 0.29% NA Helium 4.00 0.00% 0.0000 0.00% NA Totals 100.0% 18.3095 100.00% 100.00% 1 Weight Fraction corrected to remove Carbon Dioxide,Nitrogen, H25, and Helium content. EMISSIONS 0705 PLANT 1 AND 2 MOD + PLANT 3.xls • 1 7/14/2005 • • JULY 2005 PLANT 3 MODIFICATION Parachute Creek Gas Plant AP -42 HAP Emission Factors and Engine Emissions Acetaldehyde Acrolein Benzene Formaldehyde*Ethylbenzene n -Hexane Toluene Xylenes Emission Factor 2 -Stroke Lean Ib/MMBtu 0.00776 0.00778 0,00194 0.05520 0.00011 0.00045 0.00096 0.00027 Emission Factor 4 -Stroke Lean IbJMMBtu 0.00836 0.00514 0.00044 0.05280 0.00004 0.00111 0.00041 0.00018 MMBtuihr - - Emissions (1b/hr) Plant 1 Engines ENG -01 2 -stroke lean 5.46 0.04 0.04 0.01 0.46 0.00 0.00 0.01 0.00 ENG -02 2 -stroke lean 5.46 0.04 0.04 0.01 0.46 0.00 0.00 0.01 0.00 ENG -03 2 -stroke lean 5.46 0.04 0.04 0.01 0.46 0.00 0.00 0.01 0.00 ENG -04 2 -stroke lean 2.62 0.02 0.02 0.01 0.14 0.00 0.00 0.00 0.00 ENG -05 2 -stroke lean 2.62 0.02 0.02 0.01 0.14 0.00 0.00 0.00 0.00 ENG -06 2 -stroke lean 2.62 0.02 0.02 0.01 0.14 0.00 0.00 0.00 0.00 ENG -09 2 -stroke lean w SCO*'' 5.46 0.02 0.02 0.01 0.23 0.00 0.00 0.00 0.00 'ENG -10 2 -stroke lean w SCO** 5.46 0.02 0.02 0.01 0.23 0.00 0.00 0.00 0.00 ENG -1 1 4 -stroke lean w SCO**" 9.16 0.01 0.00 0.00 0.03 0.00 0.00 0.00 0.00 Plant 2 Engines ENG -13 4 -stroke lean w SCO**" 21.70 0.01 0.01 0.00 0.08 0.00 0.00 0.00 0.00 ENG -14 4 -stroke lean w SCO**' 21.70 0.01 0.01 0.00 0.08 0.00 0.00 0.00 0.00 ENG -15 4 -stroke lean w SCO*"" 21.70 0.01 0.01 0.00 0.08 0.00 0.00 0.00 0.00 ENG -16 4 -stroke lean w SCO"*" 21.70 _ 0.01 0.01 0.00 0.08 0.00 0.00 0.00 0.00 Plant 3 Engines - - ENG -17 4 -stroke lean w SCO**" 21.70 0.01 0.01 0.00 0.08 0.00 0.00 0.00 0.00 ENG -18 4 -stroke lean w SCO*** 21.70 0.01 0.01 0.00 0.08 0.00 0.00 0.00 0.00 ENG -19 4 -stroke lean w SCO**' 21.70 0.01 0.01 0.00 0.08 0.00 0.00 0.00 0.00 ENG -20 4 -stroke lean w SCO**' 21.70 0.01 0.01 0.00 0.08 0.00 0.00 0.00 0.00 ENG -21 4 -stroke lean w SCO**" 21.70 0.01 0.01 0.00 0.08 0.00 0.00 0.00 0.00 ENG -22 4 -stroke lean w SCO**" 21.70 0.01 0.01 0.00 0.08 0.00 0.00 0.00 0.00 ENG -23 4 -stroke lean w SCO**" 21.70 0.01 0.0I 0.00 0.08 0.00 0.00 0.00 0.00 ENG -24 4 -stroke lean w SCO**' 21.70 0.01 0.01 0.00 0.08 0.00 0.00 0.00 0.00 Electrical Generators GEN -1-2 4 -stroke lean 9.16 0.08 0.05 0.00 0.48 0.00 0.01 0.00 0.00 * Formaldehyde Emission Factor for Ajax 2804 LE Engines ENG -01, ENG -02, and ENG -03 from Manufacturer at 0.3 glbhp-hr ** Formaldehyde Emission Factor for Ajax 2804 LE with SCO Catalyst ENG -09 & ENG -1( 0.15 g/bhp-hr from Manfacturer Specification. Assume 50% reduction in all other HAP emissions through application of SCO control technology on 2 -stroke lean burn engines. ***Assume 93% reduction in VOC and HAP emissions through application of SCO control technology on 4 -stroke lean burn engines. EMISSIONS 0705 PLANT 1 AND 2 MOD + PLANT 3.sids ENGINE DERATING CALCULATION SHEET Engine Make/Model: Caterpillar G3612 TALE -130 Operating RPM: 1,000 RPM Maximum Rated Horsepower: 3, 550 hp Base Elevation for Max. hp: 500 ft above mean sea level Derating Factor: 3.0% per 1,500 ft elevation gain Site Elevation: 5,300 ft Site Rated Horsepower Calculation: Site hp = (Max. hp) x [ l -- (((Site Elevation — Base Elevation) x (311,500))/100)] Site hp = (3,550) x [1 — (((5,300— 500) x (3/1,500))/100)) Site hp = (3,550) x (0.904) = 3,210 hp FEATURES Shown with Optional Equipment • FULL RANGE OF ATTACHMENTS • Wide range of bolt -on system expansion attachments, factory designed and tested • UNMATCHED PRODUCT SUPPORT OFFERED THROUGH WORLDWIDE CATERPILLAR DEALER NETWORK • More than 1,500 dealer outlets • Caterpillar factory -trained dealer technicians service every aspect of your petroleum engine • 99.7% of parts orders filled within 24 hours — worldwide • Caterpillar parts and labor warranty • Preventive maintenance agreements available for "repair before failure" options • Scheduled Oil Sampling (S•0•Ssi program matches your oil sample against Caterpillar set standards to determine: - internal engine component condition - presence of unwanted fluids - presence of combustion by-products • SINGLE -SOURCE SUPPLIER • Caterpillar: - casts engine blocks, heads, cylinder liners, and flywheel housings - machines critical components - assembles complete engine Ownership of these manufacturing processes enables Caterpillar to produce high quality, dependable product. • Factory -designed systems built at Caterpillar ISO certified facilities Gas G3612 Petroleum 3195-3550 bhp 2383-2647 bkW Engine900-1000 rpm CATs ERPILLAR° ENGINE SPECIFICATIONS V-12, 4 -Stroke -Cycle Bore — in (mm) 11.8 (300) Stroke — in (mm) 11.8 (300) Displacement — cu in (L) . 15,528 (254.4) Aspiration Turbocharged and Aftercooled Capacity for Liquids — U.S. gal (L) Jacket Water Circuit' .. 177 (669) Aftercooler Circuit' 17 (64) Lube Oil System (refill) 272 (1030) Package Shipping Weight (Dry) — lb (kg) 55,300 (25 084) 'Engin* only • G3612 • Low emissions • Broad operating speed range and ability to burn a wide spectrum of gaseous fuels • Caterpillar Advanced Digital Engine Management (ADEM 111) control system with detonation -sensitive timing control for individual cylinders • Robust diesel strength design provides prolonged life and lower owning and operating costs. • TESTING • Prototype testing on every model: - proves computer design - verifies system torsional stability - functionality tests every model • Every Caterpillar engine is dynamometer tested under full load to ensure proper engine performance. ■ WEB SITE • For additional information on all your petroleum power requirements, visit www.cat-oi landgas.com. CE 1.[Iiiv0a1a 01 • • CATERPILLAR* G3612 GAS PETROLEUM ENGINE FACTORY INSTALLED STANDARD & OPTIONAL EQUIPMENT SYSTEM STANDARD OPTIONAL Air Inlet Air cleaner — standard -duty Inlet air adapter Heavy-duty air cleaner with precleaners Heavy-duty air cleaner with rain protection Charging System Charging alternators Control System Caterpillar ADEM Ill control system provides electronic governing integrated with air/fuel ratio control and individual cylinder ignition timing control Custom control system software is available for non-standard ratings. Software is field programmable using flash memory. Cooling System Jacket water pump Jacket water thermostats and housing Aftercooler pump Aftercooler water thermostats and housing Single -stage aftercoo1er Expansion tank Flexible connections Jacket water heater Exhaust System Dry wrapped exhaust rnanifolds Vertical outlet adapter Flexible bellows adapters Exhaust expander Weld flanges Flywheel/ Flywheel Housing SAE No. Go flywheel SAE No. 00 flywheel housing SAE standard rotation Fuel System Gas admission valves with electronically controlled fuel supply pressure Fuel filter Gas pressure regulator Flexible connection Low energy fuel system Corrosive gas fuel system Ignition System ADEM 111 control system senses individual cylinder detonation and controls individual cylinder timing CSA certification Instrumentation LCD display panel monitors engine parameters and displays diagnostic codes Remote data monitoring and speed control Compatible with Cat Electronic Technician (ET) and Data View Customer Communication Module (CCM) Display panel deletion is optional Lube System Crankcase breathers (top mounted) Oil cooler Oil filter Oil pan drain valve Air or electric motor -driven prelube Duplex oil filter LH or RH service Lube oil makeup system Mounting System Engine mounting feet (six total( Mounting plates (set of six) Power Take -Offs Front stub shafts Protection Electronic shutoff system with purge cycle Crankcase explosion relief valves Gas shutoff valve Starting System Air starting system Air pressure reducing valve Natural gas starting system General Paint, Caterpillar yellow Vibration dampers Engine barring device Damper guard rEHWO814 01 • • • G3612 GAS PETROLEUM ENGINE TECHNICAL DATA CATERPILLAR' G3612 Gas Petroleum Engine — 900-1000 rpm Engine Power @ 100% Load @ 75% Load bhp (bkW) bhp (bkW) 0M5312-00 3195 (2383) 2397 (1787) DM5310-00 3550 (2647) 2662 (1985) Engine Speed rpm 900 1000 SCAC Temperature cF ("C) 130 (54) 130 (54) Compression Ratio 9.0:1 9.0:1 Emissions' NO„ CO Total Hydrocarbons gfbhp-hr g/bhp-hr g/bhp-hr 0.70 2.50 5,85 0.70 2.50 6.15 Fuel Consumption @ 100% Load @ 75% Load Btu/bhp-hr (MJIbkW-hr) Btw'bhp-hr (MJ/bkW-hr) 6,570 (9.301 6,805 (9.63) 6,760 (9,57) 7,050 (9.98) Beat Balance Heat Rejection to Jacket Water • 100% Load @ 75% Load Heat Rejection to Aftercooler @ 100% Load @ 75% Load Heat Rejection to Exhaust • 100% Load @ 75% Load Btulmn (bkW) Btu/mn (bkW) Btufmn (bkW) Btufmn (bkW) Btufmn (bkW) Btufmn (bkW) 32,168 (566) 28,721 (505) 21,222 (373) 9,333 (164) 134,721 (2369) 107,091 (1883) 36,195 (636) 31,271 (5501 26,509 (466) 14,525 (255) 154,673 (2720) 123.759 (2176) Exhaust System Exhaust Gas Flow Rate @ 100% Load @ 75% Load Exhaust Stack Temperature • 100% Load @ 75% Load cfm (m'Imin) cfm (m'lmin) °F (°C) 4F (°C) 20,634 (584) 16,100 (456) 23,461 (664) 18,554 (525) 846 (452) 858 (459) 867 (464) 878 (470) Intake System Air Intet Flow Rate @ 100% Load @ 75% Load cfm (m'fmin) cfm (m'fmin) 8,527 (241) 6,542 (185) 9,598 (272) 7,477 (212) Gas Pressure psi (kPa) 'at 100% load and speed 43 (295) 43 (295) LEHWO814-01 CATERPILLAR' G3612 GAS PETROLEUM ENGINE GAS PETROLEUM ENGINE 186.42 DIMENSIONS Length in (mm) 186.42 (4735.1) 11Vidth in (mm) 93.68 (2379.5) Height in (mrn) 126.77 (3219.9) Shipping Weight Ib (kg) 55.300 (25 084) IralstY rlign.nsTio4ngru AirLst�."�tG'-XdD RATING DEFINITIONS AND CONDITIONS 93.68 (2379.5) Note: General configuration riot to be used for installation. See general dimension drawings for detail. Engine performance is obtained in accordance with SAE J1995. IS03046/1, BS5514/1, and DIN6271/1 standards. Transient response data is acquired from an engine/generator combination at normal operating temperature and in accordance with IS03046/1 standard ambient conditions. Also in accordance with SAE J1995, BS5514/1, and DIN6271/1 standard reference conditions. Conditions: Power for gas engines is based on fuel having an LHV of 905 Btu/cu ft (33.74 kJ/L) at 29.91 in. Hg (101 kPa) and 590 F (15° C). Fuel rate is based on a cubic meter at 29.61 in. Hg (100 kPa) and 60.1° F (15,6° C). Air flow is based on a cubic foot at 29.61 in. Hg (100 kPa) and 77* F (25° C). Exhaust flow is based on a cubic foot at 29.61 in. Hg (100 kPa) and stack temperature. TMI Reference No.: 05312-0(1, 0M5310-00 Materials and specifications are subject 10 change without notice. The International System of Units 151) is used in this publication. LEHW08Td-0119011 Prinled in U. SA. ®2001 Caterpillar All rights reserved. • PARACHUTE CREEK GAS PLANT • JULY 2005 PLANT 3 MODIFICATION Parachute Creek Gas Plant AP•42 HAP Emission Factors and Heater Emissions Acetaldehyde Benzene FormaldehydeEthylbenzenc n -Hexane Emission Factor Ib/MMscf NA 0.00210 0.07500 0.00011 1.80000 MMscflhr Emissions (lbThr) Toluene 0.00340 Xylenes NA Plant !Heaters 0.00 NA HTR -1 0.026 NA 0.00 0.00 0.00 0.05 Plant 2 Heaters 0.00 NA HTR -2 0.052 NA 0.00 0.00 0.00 0.09 Plant 3 Heaters - 0.00 NA HTR -3 0.058 NA 0.00 0.00 0.00 0.10 7/1312005 EMISSIONS 0705 PLANT 1 AND 2 MOD + PLANT lib • PARACHUTE CREEK GAS PLANT • DEHY-1 Still Vent Condenser Overhead To FLARE -1 96% DRE From GRI GLYCaIc Model Parachute Creek Gas Plant To FLARE -1 FLARE -1 Emissions Component (lb/hr) lbihr tons/yr Methane 0.498 0.020 0.1 Ethane 0.347 0.014 0.1 Propane 0.162 0.007 0.0 i -Butane 0.040 0.002 0.0 n -Butane 0.056 0.002 0.0 i -Pentane 0.032 0.001 0.0 n -Pentane 0.017 0.001 0.0 Cyclopentane 0.013 0.001 0.0 n -Hexane 0.014 0.001 0.0 Cyclohexane 0.066 0.003 0.0 Other Hexanes 0.032 0.001 0.0 Heptanes 0.015 0.001 0.0 Methylcyclohexane 0.030 0.001 0.0 Benzene 0.815 0.030 0.1 Toluene 0.230 0.009 0.0 Ethyl benzene 0.015 0.001 0.0 Xylenes 0.145 0.005 0.0 C8+ Heavies _ 0.000 0.000 0.0 Total Emissions 2.529 0.098 0.4 Total VQC Emissions 0.064 0.3 Total tpy VOC to FLARE -1: 7.4 Total scflhr to FLARE -1: 226 Total acfm: to FLARE -1: 4.20 JULY 2005 PLANT 3 MODIFICATION DEHY-1 Still Vent Condenser Overhead Vapor Heating Rate Parachute Creek Gas Plant HHV Vapor Flow Heat Rate Constituent (Btw7b) flbfhr) {BtuTr) Methane 23861 0.50 11887.6 Ethane 22304 0.35 7735.03 Propane 21646 0.16 3513.15 Isobutane 21242 0.04 853.93 n -Butane 21293 0.06 1192.41 Isopentane 21025 0.03 679.11 n -Pentane 21072 0.03 644.80 all -Hexanes 20928 0.11 2364.86 Heptanes 20285 0.04 908.77 Benzene 18172 0.82 14812.00 Toluene 18422 0.23 4229.69 Ethylbenzene 18658 0.01 278.00 Xylenes 18614 0.15 2699.03 C8+ Heavies 20747 0.00 6.22 Total All Constituents 2.53 51805 Heat Rate (MMBtuihr) = 0.05 Volumetric Flowrate (scfihr) _ 226 Heating Value (Btuiscf) = 229 Still Vent Condenser Ovhd is Constant Fuel to FLARE -1 Note: Still Vent Condenser Overhead Composition from GLYCaIc 7113/2005 EMISSIONS 0705 PLANT 1 AND 2 MOD + PLANT 3.xls • PARACHUTE CREEK GAS PLANT • DEHHY•1 Flash Tank Overhead To FLARE -1 Volurnetric Flow From GLYCaIc Stream Data Parachute Creek Gas Plant To FLARE -1- FLARE - 1 Emissions Component lb/hr Iblhr tons/yr Methane 7160 0.287 1.26 Ethane 3.270 0.131 0.57 Propane 0.648 0.026 0.11 i -Butane 0.169 0.007 0.03 n -Butane 0.178 0.007 0.03 t -Pentane 0.084 0.003 0.01 n -Pentane 0.043 0.002 0.01 n -Hexane 0.022 0.001 0.00 Other Hexanes 0.085 0.003 0.01 Heptanes 0.027 0.001 0.00 Benzene 0.060 0.002 0.01 Toluene 0.013 i 0.001 0.00 Ethylbenzene 0.001 0.000 0.00 Xylenes 0.005 0.000 0.00 C8+ Heavies 0.000 0.000 0.00 Total Emssions 11.765 0.471 2.1 Total VOC Emissions 0.05 0.2 Flash to FLARE -1 Volumetric Flow 384 scf/hr Total tpy VOC to FLARE -1 : 5.8 • JULY 2005 PLANT 3 MODIFICATION DEHY•1 Flash Tank Vapor Heating Rate Parachute Creek Gas Plant HHV Vapor Flow Heat Rate Constituent (Btu/lb) (1blhr) (Btu/hr) Methane 23861 7.16 170844.8 Ethane 22304 3.27 72934.08 Propane 21646 0,6480 14026.61 Isobutane 21242 0.1690 3589.90 n -Butane 21293 0.1780 3790.15 Isopentane 21025 0.0839 1764.00 n -Pentane 21072 0.0426 897.46 all -Hexanes 20928 0,1071 2241.39 Heptanes 20285 0.0274 555,81 Benzene 18172 0.0602 1093.95 Toluene 18422 0.0130 239.49 Ethylbenzene 18658 0.0008 14.96 Xylenes 18614 0.0049 91.77 C8+ Heavies 20747 0.0001 2.04 Total All Constituents 11.77 272086 Heat Rate (MMBtu/hr) = 0.27 Volumetric Flowrate (scf/hr) = 384 Heating Value (Btulscf) = 709 Flash Tank Vapor is Constant Fuel Input to FLARE -1 Note: Flash Tank Vapor Composition from GLYCaIc 7)1312005 EMISS1ONS 0705 PLANT 1 AND 2 MOD + PLANT 3.xls • PARACHUTE CREEK GAS PLANT • DEHY•2 Still Vent Condenser Overhead To FLARE -2 96% DRE From GRI GLYCaIc Model Parachute Creek Gas Plant To FLARE -2 FLARE -2 Emissions `Component (Ib/hr) lblhr tons/yr Methane 0.747 l 0.03 0.1 Ethane 0.5059 0.02 0.1 Propane 0.2215 0.01 0.0 i -Butane 0.054 0.00 0.0 n -Butane 0.0753 0.00 0.0 i -Pentane 0.0427 0.00 0.0 n -Pentane 0.0218 0.00 0,0 Cyclopentane 0,0118 0.00 0.0 n -Hexane 0.0192 0.00 0.0 Cyclohexane 0.0595 0.00 0.0 Other Hexanes 0.044 0.00 0.0 Heptanes 0.0202 0.00 0.0 Mcthylcyclohexane 0.0255 0.00 0.0 Benzene 1.0964 0.04 0.2 Toluene 0.3087 0.01 0.0 Ethylbenzene 0.0197 0.00 0.0 Xylenes 0.1906 0.01 0.0 C8+ Heavies 0.0003 0.00 0.0 Total Emissions 3.46 0.13 0.6 _ Total VOC Emissions 0.08 0.4 Total spy VOC to FLARE -2: 9.7 Total scf/hr to FLARE -2: 282 Total acfm: to FLARE -2: 5.24 • JULY 2005 PLANT 3 MODIFICATION DEHY•2 Still Vent Condenser Overhead Vapor Heating Rate Parachute Creek Gas Plant HHV Vapor Flow Heat Rate Constituent (Btu/lb) (Ib/hr) f$tu/hr) Methane 23861 0.75 17826.6 Ethane 22304 0.51 11283.59 Propane 21646 0.22 4794.59 Isobutane 21242 0.05 1147,07 n -Butane 21293 0.08 1603.36 Isopentane 21025 0.04 897.77 n -Pentane 21072 0.03 708.02 all -Hexanes 20928 0.12 2567.87 Heptanes 20285 0.05 927.02 Benzene 18172 1.10 19923.78 Toluene 18422 0.31 5686.87 Ethylbenzene 18658 0.02 367.56 Xylenes 18614 0.19 3547.83 C8+ Heavies 20747 0.00 6.22 Total Alt Constituents 3.46 71288 Heat Rate (MMBtulhr) 0.07 Volumetric Flowrate (sef/hr) 282 Heating Value (Btu/scl) 253 Still Vent Ovhd is Constant Fuel Input to FLARE -2 Note: Still Vent Overhead Composition from CLYCaIc 7/13/2005 EM/SSIONS 0705 PLANT 1 AND 2 MOD + PLANT 3.xts • PARACHUTE CREEK GAS PLANT • DEHY•2 Flash Tank Overhead To FLARE -2 Volumetric Flow From GLYCaIc. Stream Data Parachute Creek Gas Plant To FLARE -2 FLARE -2 Emissions Component Iblhr lb/hr tons/yr Methane - 10.291 0.412 1.8 Ethane 4.609 0.184 0.8 Propane 0.865 0.035 0.2 i -Butane 0.224 0.009 0.0 n -Butane 0.236 0.010 0.0 i -Pentane 0.110 0.004 0,0 n -Pentane 0.051 0.002 0.0 n -Hexane 0.029 0.001 0.0 Other Hexanes 0.107 0.004 0.0 Heptanes 0.032 0.001 0.0 Benzene 0.079 0.003 0.0 Toluene 0.017 0.001 0.0 Ethylbenzene 0.001 0.000 0.0 Xylenes 0.006 0.000 0.0 C8+ Heavies 0.000 0.000 0.0 Total Emssions 16.659 0.667 2.9 Total VOC Emissions 0.07 0.3 Flash to FLARE -2 Volumetric Flow 507 scf/hr Total tpy VOC to FLARE -2 : 7.7 • JULY 2005 PLANT 3 MODIFICATION DEHY-2 Flash Tank Vapor Heating Rate Parachute Creek Gas Plant HHV Vapor Flow Heat Rate Constituent fBtuJlb) (Iblhr) (Btulhr) Methane 23861 10.29 245558.3 Ethane 22304 4.61 102803.60 Propane 21646 0.8646 18715.13 Isobutane 21242 0.2241 4760.33 n -Butane 21293 0.2363 5031.54 Isopentane 21025 0.1104 2321.16 n -Pentane 21072 0.0514 1083.10 all -Hexanes 20928 0.1362 2850.39 Heptanes 20285 0.0321 651.15 Benzene 18172 0.0787 1430.14 Toluene 18422 0.0172 316.86 Ethylbenzene 18658 0.0010 18.66 Xylenes 18614 0.0064 119.13 C84- Heavies 20747 0.0001 2.07 Total All Constituents 16.66 385662 Heat Rate (MMBtufhr) = 039 Volumetric Flowrate (scffhr) = 507 Heating Value (Btulscf) = 761 Flash Tank Vapor is Constant Fuel Input to FLARE -2 Note: Flash Tank Vapor Composition from GLYCac 7(13/2005 EMISSIONS 0705 PLANT 1 AND 2 MOD + PLAINT 3.xis • PARACHUTE CREEK GAS PLANT • DEHY-3 Still Vent Condenser Overhead To FLARE -2 96% DRE From GRI GLYCaic Model Parachute Creek Gas Plant To FLARE -2 FLARE -2 Emissions Component (Ib/hr) lb/hr tons/yr Methane 2.7300 0.11 0.5 Ethane 2.6300 0.11 0.5 Propane 2.7300 0.11 0.5 i -Butane 1.27 0.05 0.2 n -Butane L65 0.07 0.3 i -Pentane 0,777 0,03 0.1 n -Pentane 0.806 0.03 0.1 Cyclopentane 0.48 0.02 0.1 n -Hexane 0.501 0,02 0.1 Cyclohexane 1.05 0.04 0.2 Other Hexanes 0.789 0,03 0.1 Heptanes 1.13 0.05 0.2 Methylcyclohexane 1.34 0.05 0.2 Benzene 3.5100 0.14 0.6 Toluene 3.96 0.16 0.7 Ethylbenzenc 0 0.00 0.0 Xylenes 0.633 0.03 0.1 C8+ Heavies _ 0.0157 0,00 0.0 Total Emissions 26.00 1.04 4.6 Total VOC Emissions 0.83 3.6 Total tpy VOC to FLARE -2: 90.4 Total scf/hr to FLARE -2: 333 Total acfm: to FLARE -2: 6.19 • JULY 200 PLANT 3 MODIFICATION DE1FY-3 Still Vent Condenser Overhead Vapor Heating Rate Parachute Creek Gas Plant HHV Vapor Flow Heat Rate Constituent (Btu/lb) (Ib/hr) (Btu/hr) Methane 23861 2.73 65140.5 Ethane 22304 2.63 58659.52 Propane 21646 2.73 59093.58 Isobutane 21242 1.27 26977.34 n -Butane 21293 1.65 35133.45 Isopentane 21025 0.78 16336.43 n -Pentane 21072 1,29 27098.59 all -Hexanes 20928 2,34 48971.52 Heptanes 20285 2.47 50103,95 Benzene 18172 3.51 63783.72 Toluene 18422 3.96 72951.12 Ethylbenzene 18658 0.00 0.00 Xylenes 18614 0.63 11782.66 C8+ Heavies 20747 0.02 325.73 Total All Constituents 26.00 536358 Heat Rate (MMBtu/hr) = 0.54 Volumetric Flowrate (scUhr) 333 Heating Value (Btu/scf) 1611 Still Vent Ovhd is Constant Fuel Input to FLARE -2 Note: Still Vent Overhead Composition from GLYCaIc 7/13/2005 EMISSIONS 0705 PLANT 1 AND 2 MOD + PLANT 3.xls • PARACHUTE CREEK GAS PLANT 7/13/2005 • DEHY•3 Flash Tank Overhead To FLARE -2 Volumetric Flow From GLYCalc Stream Data Parachute Creek Gas Plant To FLARE -2 FLARE -2 Emissions Component lb/hr lblhr tons/yr Methane 23.2473 0.930 4.1 Ethane 6.4755 0.259 1.1 Propane 3.007 0.120 0.5 i -Butane 0.955 0.038 0.2 n -Butane 0.968 0.039 0.2 's -Pentane 0.467 0.019 0.1 n -Pentane 0.463 0.019 0.1 n -Hexane 0.184 0.007 0.0 Other Hexanes 0.459 0.018 0.1 Heptanes 0.542 0.022 0.1 Benzene 0.057 0.002 0.0 Toluene 0.086 0.004 0.0 Ethylbenzene 0.000 0.000 0.0 Xylenes 0.017 0.001 0.0 C8+ Heavies 0.112 0.005 0.0 Tota] Emissions 37.039 1.482 6.5 Total VOC Emissions 0,29 1.3 Flash to FLARE -2 Volumetric Flow 738 scf/hr Total tpy VOC to FLARE -2 : 32.0 JULY 2005 PLANT 3 MODIFICATION DENY -3 Flash Tank Vapor Heating Rate Parachute Creek Gas Plant Constituent 'Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane all -Hexanes Heptanes Benzene Toluene Ethylbenzene Xylenes C8+ Heavies Total All Constituents Heat Rate (MMBtulhr) Volumetric Flowrate (scf/hr) Heating Value (Btulscf) HHV fBtu1b) 23861. 22304 21646 21242 21293 21025 21072 20928 20285 18172 18422 18658 18614 20747 Vapor Flow (lb/hr) 23.25 6.48 3.0067 0.9550 0.9678 0.4668 0,4627 0,6427 0.5420 0.0569 0.0864 0.0000 0.0170 0.1123 37.04 Flash Tank Vapor is Constant FueI Input to FLARE -2 Note: Flash Tank Vapor Composition from GLYCaIc Heat Rate (Btu/hr.) 554703.8 144429.55 65083.03 20286.11 20607.37 9814.47 9750.01 13450.43 10994.47 1033.99 1591.66 0.00 316.44 2329.89 854391 0.85 738 1158 EMISSIONS 0795 PLANT 1 AND 2 MOD + PLANT 3.xls • PARACHUTE CREEK GAS PLANT 7/13/2005 • DEHY-4 Still Vent Condenser Overhead To FLARE -3 96% DRE From GRI GLYCaIc Model Parachute. Creek Gas Plant To FLARE -3 FLARE -3 Emissions Component (lb/hr) Ib/hr tons/yr Methane 0.7980 0.03 0.1 Ethane 0.6410 0.03 0.1 Propane 0.3500 0.01 0.1 i -Butane 0.0946 0.00 0.0 n -Butane 0.1300 0.01 0.0 i -Pentane 0.0772 0.00 0.0 n -Pentane 0.0388 0.00 0.0 Cyclopentane 0.0265 0.00 0.0 n -Hexane 0.0328 0.00 0.0 Cyclohexane 0.1150 0.00 0.0 Other Hexanes 0.0762 0.00 0.0 Heptanes 0.0326 0.00 0.0 Methylcyclohexant 0.0575 0.00 0.0 Benzene 1.3400 0.05 0.2 Toluene 0.3420 0.01 0.1 Ethylbenzene 0.0255 0.00 0.0 Xylenes 0.2430 0.01 0.0 C8+ Heavies 0.0006 0.00 0.0 Total Emissions 4.42 0.18 0.8 Total VOC Emissions 0.12 0.5 Total spy VOC to FLARE -3 13.1 Total scf/hr to FLARE -3 351 Total acfm: to FLARE -3 6.53 • JULY 2005 PLANT 3 MODIFICATION DEHY-4 Still Vent Condenser Overhead Vapor Heating Rate' Parachute Creek Gas Plant HHV Vapor Flow Heat Rate Constituent j8tu/lb). (14/hr) (Stu/hr) Methane 23861 0.80 19041.1 Ethane 22304 0.64 14296.86 Propane 21646 0.35 7576.10 Isobutane 21242 0.09 2009.49 n -Butane 21293 0.13 2768.09 Isopentane 21025 0.08 1623.13 n -Pentane 21072 0.07 1376.00 all -Hexanes 20928 0.22 4687.87 Heptanes 20285 0.09 1827.68 Benzene 18172 1.34 24350.48 Toluene 18422 0.34 6300.32 Ethylbenzene 18658 0.03 475.78 Xylenes 18614 0.24 4523.20 C8+ Heavies 20747 0.00 11.91 Total All Constituents 4.42 90868 Heat Rate (MMBtu/hr) - 0.09 Volumetric Flowrate (scf/hr) = 351 Heating Value (Btu/scf) = 259 Still Vent Ovhd is Constant Fuel Input to FLARE -3 Note: Still Vent Overhead Composition from GLYCaIc EMISSIONS 0705 PLANT 1 AND 2 MOD + PLANT 3.7.1s • PARACHUTE CREEK GAS PLANT 7/13/2005 DEHY-4 Flash Tank Overhead To FLARE -3 Volumetric Flow From GLYCa1c Stream Data Parachute Creek Gas Plant To FLARE -3 FLARE -3 Emissions Component lb/hr IbThr tonsfyr Methane 9.037 0.362 1.6 Ethane 4.699 0.188 0.8 Propane 1.067 0.043 0.2 i -Butane 0.298 0.012 0.1 n -Butane 0.310 0.012 0.1 i -Pentane 0.147 0.006 0.0 n -Pentane 0.069 0.003 0.0 n -Hexane 0.036 0.001 0.0 Other Hexanes 0.136 0.005 0.0 Heptanes 0.040 i 0.002 0.0 Benzene 0.080 0.003 0.0 Toluene 0.015 0.001 0.0 Ethylbenzene 0.001 0.000 0,0 Xylenes 0.006 0.000 0.0 C8+ Heavies 0.000 0.000 0.0 Total Emssions 15.941 0.638 2.8 Total VOC Emissions 0.09 0.4 Flash w FLARE -3 Volumetric Flow 485 scf/hr Total tpy VOC to FLARE -3: 0.1 • JULY 2005 PLANT 3 MODIFICATION DEHY-4 Flash Tank Vapor Heating Rate Parachute Creek Gas Plant HHV Constituent (Btu/lb) (lb/hr) Methane 23861 9.04 Ethane 22304 4.70 Propane 21646 1.0665 Isobutane 21242 0.2982 n -Butane 21293 0.3097 Isopentane 21025 0.1472 n -Pentane 21072 0.0693 all -Hexanes 20928 0.1713 Heptanes 20285 0.0403 Benzene 18172 0.0798 Toluene 18422 0.0153 Ethylbenzene 18658 0.0011 Xylenes 18614 0,0064 C8+ Heavies 20747 0.0001 Total All Constituents 15,94 Heat Rate (MMBtulhr) Volumetric Flowrate (scf/hr) Heating Value (Btu/scf) Vapor Flow Heat Rate (Btufhr]�. 215627.1 104799.80 23085.46 6334.36 6594.44 3094.88 1460.29 3584.97 817.49 1450.13 281.86 20.52 119.13 2.07 367272 0.37 485 757 Flash Tank Vapor is Constant Fuel Input to FLARE -3 Note: Flash Tank Vapor Composition from GLYCa1c EMISSIONS 0705 PLANT 1 AND 2 MOD + PLANT 3.x15 • • Parachute Creek Gas Plant Composition of Commingled Inlet Gas and Sweetened Inlet Gas Inlet to Plant -3 EG Dehydration System DEHY-4 Component Inlet Gas (% Vol.) Sweet Gas (% Vol.) Comingled (% Vol.) Carbon Dioxide 3.048 1.530 2.289 Hydrogen Sulfide 0.000 0.000 0.000 Nitrogen/Oxygen/Water 0.070 0.188 0.129 Methane 88.933 90.218 89.576 Ethane 5.421 5.499 5.460 Propane 1.337 1.356 1.347 Isobutane 0.318 0.323 0.321 n -Butane 0.267 0.271 0.269 Isopentane 0.136 0.138 0.137 n -Pentane 0.082 0.089 0.086 Cyclopentane 0.006 0.000 0.003 n -Hexane 0.042 0.043 0.043 Cyclohexane 0.024 0.000 0.012 Other Hexanes 0.092 0.118 0.105 Heptanes 0.075 0.123 0.099 Methylcyclohexane 0.046 0.000 0.023 2,2,4-Trimethylpentane 0.000 0.000 0.000 Benzene 0.013 0.013 0.013 Toluene 0.022 0.022 0.022 Ethylbenzene 0.001 0.001 0.001 Xylenes 0.008 0.008 0.008 C8+ Heavies 0.059 0.060 0.060 Total All Components 100.000 100.000 100.000 NOTE: 150 MMscf/day of Inlet Gas and 150 MMscf/day of Sweet Gas Comprise EG Inlet Gas Page: 1 GRI-GLYCa1c VERSION 4.0 - AGGREGATE CALCULATIONS REPORT Case Name: PARACHUTE CREEK GAS PLANT EG UNIT File Name: U:\GAS PLANTS\PCGP\PLANT 3 MOD 07051P1ant3New300MMEG0705.ddf Date: July 13, 2005 DESCRIPTION:. Description: Plant 3 New 300 MMscf/day EG Unit Receives 150 MMscf/dsy Sweet Gas from Amine -3 Unit Comingled with 150 MMscf/day Raw Inlet Gas Flash Tank Ovhd to FLARE -3 @ 96% DRE, Still Vent to 120 F Cond./FLARE-3 @ 96% DRE Annual Hours of Operation: 8760.0 hours/yr EMISSIONS REPORTS: CONTROLLED REGENERATOR EMISSIONS Component lbs/hr lbs/day tons/yr Methane 0.0319 0.766 0.1399 Ethane 0.0256 0.615 0.1123 Propane 0.0140 0.336 0.0614 Isobutane 0.0038 0.091 0.0166 n -Butane 0.0052 0.125 0.0227 Isopentane 0.0031 0.074 0.0135 n -Pentane 0.0016 0.037 0.0068 Cyclopentane 0.0011 0.025 0.0046 n -Hexane 0.0013 0.032 0.0058 Cyclohexane 0.0046 0.110 0.0201 Other Hexanes 0.0030 0.073 0.0133 Heptanes 0.0013 0.031 0.0057 Methylcyclohexane 0.0023 0.055 0.0101 Benzene 0.0535 1.283 0.2341 Toluene 0.0137 0.328 0.0599 Ethylbenzene 0.0010 0.024 0.0045 Xylenes 0.0097 0.233 0.0426 C8+ Heavies <0.0001 0.001 0.0001 Total Emissions 0.1767 4.241 0.7740 Total Hydrocarbon Emissions 0.1767 4.241 0.7740 Total VOC Emissions 0.1191 2.859 0.5218 Total HAP Emissions 0.0792 1.900 0.3468 Total BTEX Emissions 0.0779 1.869 0.3411 UNCONTROLLED REGENERATOR EMISSIONS Component • lbs/hr lbs/day tons/yr Methane 0.7988 19.172 3.4988 Ethane 0.6415 15.396 2.8097 Propane 0.3507 8.418 1.5362 Isobutane 0.0947 2.272 0.4146 n -Butane 0.1298 3.116 0.5686 Page: 2 Isopentane 0.0772 1.852 0.3381 n -Pentane 0.0389 0.933 0.1702 Cyclopentane 0.0266 0.638 0.1164 n -Hexane 0.0328 0.788 0.1438 Cyclohexane 0.1149 2.757 0.5031 Other Hexanes 0.0762 1.828 0.3336 Heptanes 0.0326 0.782 0.1428 Methylcyclohexane 0.0575 1.380 0.2519 Benzene 1.4094 33.826 6.1732 Toluene 0.3574 8.578 1.5655 Ethylbenzene 0.0264 0.633 0.1156 Xylenes 0.2544 6.106 1.1144 C8+ Heavies 0.0006 0.014 0.0025 Total Emissions 4.5203 Total Hydrocarbon Emissions Total VOC Emissions Total HAP Emissions Total BTEX Emissions FLASH GAS EMISSIONS 4.5203 3.0800 2.0805 2..0477 108.488 19.7990 108.488 73.920 49.932 49.144 Component 19.7990 13.4905 9.1125 8.9687 lbs/hr lbs/day tons/yr Methane 0.3615 8.675 1.5832 Ethane 0.1879 4.511 0.8232 Propane 0.0427 1.024 0.1868 Isobutane 0.0119 0.286 0.0522 n -Butane 0.0124 0.297 0.0543 Isopentane 0.0059 0.141 0.0258 n -Pentane 0.0024 0.058 0.0107 Cyclopentane 0.0003 0.008 0.0015 n -Hexane 0.0014 0.034 0.0063 Cyclohexane 0.0010 0.025 0.0046 Other Hexanes 0.0044 0.105 0.0191 Heptanes 0.0010 0.024 0.0043 Methylcyclohexane 0.0006 0.015 0.0027 Benzene 0.0032 0.077 0.0140 Toluene 0.0006 0.015 0.0027 Ethylbenzene X0.0001 0.001 0.0002 Xylenes 0.0003 0.006 0.0011 C8+ Heavies <0.0001 <0.001 <0.0001 Total Emissions 0.6376 Total. Hydrocarbon Emissions Total VOC Emissions Total HAP Emissions Total BTEX Emissions FLASH TANK OFF GAS 0.6376 0.0882 0.0055 0.0041 15.303 2.7928 15.303 2.117 0.133 0.098 2.7928 0.3863 0.0242 0.0180 Component lbs/hr lbs/day tons/yr Methane 9.0368 216.884 39.5812 Ethane 4.6987 112.768 20.5802 Propane 1.0665 25.596 4.6712 • • Page: 3 Isobutane 0.2982 7.156 1.3059 n -Butane 0.3097 7.432 1.3563 Isopentane 0.1472 3.533 0.6447 n -Pentane 0.0609 1.461 0.2667 Cyclopentane 0.0084 0.201 0.0367 n -Hexane 0.0358 0.858 0.1566 Cyclohexane 0.0262 0.630 0.1149 Other Hexanes 0.1093 2.623 0.4787 Heptanes 0.0247 0.594 0.1083 Methylcyclohexane 0.0156 0.374 0.0683 Benzene 0.0798 1.915 0.3495 Toluene 0.0153 0.367 0.0671 Ethylbenzene 0.0011 0.025 0.0046 Xylenes 0.0064 0.155 0.0282 C8+ Heavies 0.0001 0.003 0.0006 Total Emissions 15.9406 Total Hydrocarbon Emissions Total VOC Emissions Total. HAP Emissions Total BTEX Emissions EQUIPMENT REPORTS: 15.9406 2.2051 0.1384 0.1026 CONDENSER AND COMBUSTION DEVICE 382.574 69.8198 382.574 52.923 3.320 2.462 69.8198 9.6584 0.6060 0.4494 Condenser Outlet Temperature: 120.00 deg. F Condenser Pressure: 12.20 psia Condenser Duty: 2.55e-002 MM BTU/hr Produced Water: 48.71 bbls/day Ambient Temperature: 0.00 deg. F Excess Oxygen: 0.00 % Combustion Efficiency: 96.00 % Supplemental Fuel Requirement: 2.55e-002 MM BTU/hr Component Emitted Destroyed Methane 4.00% 96.00% Ethane 4.00% 96.00% Propane 4.00% 96.00% Isobutane 4.00% 96.00% n -Butane 4.00% 96.00% Isopentane 4.00% 96.00% n -Pentane 4.00% 96.00% Cyclopentane 3.99% 96.01% n -Hexane 4.00% 96.00% Cyclohexane 3.99% 96.01% Other Hexanes 4.00% 96.00% Heptanes 4.00% 96.00% Methylcyclohexane 4.00% 96.00% Benzene 3.79% 96.21% Toluene 3.83% 96.17% Ethylbenzene 3.87% 96.13% Xylenes 3.82% 96.18% C8+ Heavies COLD SEPARATOR 4.00% 96.00 Page: 4 Cold Separator Temperature: Cold Separator Pressure: Dry Gas Flow Rate: Calculated Dry Gas Dew Point: Glycol Losses with Dry Gas: Wet Gas Water Content: Calculated Wet Gas Water Content: Calculated Lean Glycol Recirc. Ratio: Produced Liquid: Glycol Losses in Produced Liquids: FLASH TANK Component -20.0 deg. F 645.0 psig 300.0000 MMSCF/day 0.47 lbs. H2O/MMSCF 0.6286 lb/hr Saturated 60.24 lbs. H2O/MMSCF 1.45 gal/lb H2O 1.94e+003 bbls/day 7.2446 lb/hr Remaining Absorbed or in Dry Gas Condensed Water Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane Cyclopentane n -Hexane Cyclohexane Other Hexanes Heptanes Methylcyclohexane Benzene Toluene Ethylbenzene Xylenes C8+ Heavies 0.77%. 98.92% 99.90% 99.64% 98.84% 88.93% 77.06% 66.98% 40.65% 19.72% 23.1.8% 13.02% 10.24% 21.74% 2.40% 3.15% 10.30% 0.78% 1.12% 0.72% 99.23% 1.08% 0.10% 0.36% 1.16% 11.07% 22.94% 33.02% 59.35% 80.28% 76.82% 86.98% 89.76% 78.26% 97.60% 96.85% 89.70% 99.22% 98.88% 99.28% 0.39% 99.61% Flash Control: Flash Control Efficiency: Flash Temperature: Flash Pressure: Component Combustion device 96.00 % 120.0 deg. F 80.0 psig Left in Oil Removed in and Glycol Flash Gas Water Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane 99.99% 57.89% 6.08% 8.12% 12.01% 24.75% 24.10% 0.01% 42.11% 93.92% 91.88% 87.99% 75.25% 75.90% • • REGENERATOR Page: 5 n -Butane 29.54% 70.46% Isopentane 34.73% 65.27% n -Pentane 39.26% 60.74% Cyclopentane 76.14% 23.86% n -Hexane 48.14% 51.86% Cyclohexane 82.00% 18.00% Other Hexanes 41.66% 58.34% Heptanes 57.08% 42.92% Methylcyclohexane 79.53% 20.47% Benzene 94.91% 5.09% Toluene 96.22% 3.78% Ethylbenzene 96.54% 3.46% Xylenes 97.85% 2.15% C8+ Heavies 83.46% 16.54% No Stripping Gas used in regenerator. Component Remaining Distilled in Glycol Overhead Water 73.32% 26.68% Carbon Dioxide 0.00% 100.00% Nitrogen 0.00% 100.00% Methane 0.00% 100.00% Ethane 0.00% 100.00% Propane 0.00% 100.00% Isobutane 0.00% 100.00% n -Butane 0.00% 100.00% Isopentane 1.44% 98.56% n -Pentane 1.27% 98.73% Cyclopentane 0.66% 99.34% n -Hexane 1.04% 98.96% Cyclohexane 3.90% 96.10% Other Hexanes 2.40% 97.60% Heptanes 0.88% 99.12% Methylcyclohexane 5.03% 94.97% Benzene 5.27% 94.73% Toluene 8.21% 91.79% Ethylbenzene 10.77% 89.23% Xylenes 13.18% 86.82% C8+ Heavies STREAM REPORTS: 14.38% 85.62% WET GAS STREAM Temperature: Pressure: Flow Rate: 90.00 deg. F 664.70 psia 1.27e+007 scfh • Component Conc. Loading (vol%) (1b/hr) Water Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane Cyclopentane n -Hexane Cyclohexane Other Hexanes Heptanes 1.27e-001 2.29e+000 1.29e-001 8.95e+001 5.45e+000 1.35e+000 3.21e-001 2.69e-001 1.37e-001 8.59e-002 3.00e-003 4.29e-002 1.20e-002 1.05e-001 9.89e-002 7.63e+002 3.36e+004 1.21e+003 4.79e+005 5.48e+004 1.98e+004 6.22e+003 5.21e+003 3.30e+003 2.07e+003 7.02e+O01 1.24e+003 3.37e+002 3.02e+003 3.31e+0.03 Methylcyclohexane 2.30e-002 7.53e+002 Benzene 1.30e-002 3.39e+002 Toluene 2.20e-002 6.76e+002 Ethylbenzene 9.99e-004 3.54e+001 Xylenes 7.99e-003 2.83e+002 C8+ Heavies 5.99e-002 3.41e+003 Total Components 100.00 6.20e+005 DRY GAS STREAM Temperature: Pressure: Flow Rate: -20.00 deg. F 659.70 psia 1.25e+007 scfh Component Conc. (vol%) Water Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane Cyclopentane n -Hexane Cyclohexane Other Hexanes Heptanes Methylcyclohexane Benzene Toluene Ethylbenzene Xylenes 9.92e-004 2.29e+000 1.30e-001 9.04e+001 5.46e+000 1.21e+000 2.50e-001 1.82e-001 5.64e-002 1.72e-002 7.04e-004 5.67e-003 1.24e-003 2.31e--002 2.41e-003 7.34e-004 1.35e-003 1.73e-004 1.14e-005 5.80e-005 Loading (lb/hr) 5.88e+000 3.32e+004 1.20e+003 4.77e+005 5.41e+004 1.76e+004 4.80e+003 3.49e+003 1.34e+003 4.08e+002 1.63e+001 1.61e+002 3.45e+001 6.56e+002 7.95e+001 2.37e+001 3.49e+001 5.25e+000 3.98e-001 2.03e+000 C8+ Heavies 2.36e-004 1.32e+001 Page: 6 • • • LEAN GLYCOL STREAM Page: 7 Total Components 100.00 5.95e+005 Temperature: Flow Rate: 90.00 deg. F 1.80e+001 gpm Component EG Water Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane Cyclopentane n -Hexane Cyclohexane Other Hexanes Heptanes Methylcyclohexane Benzene Toluene Ethylbenzene Conc. Loading (wt%) (lb/hr) 8.00e+001 2.00e+001 5.37e-011 1.96e-014 3.37e-018 2.57e-008 5.89e-010 1.20e-010 1.11e-01.0 1.15e-005 5.12e-006 1.79e-006 3.52e-006 4.76e-005 1.91e-005 2.94e-006 3.11e-005 8.00e-004 3.26e-004 3.25e-005 7.83e+003 1.96e+003 5.26e-009 1.91e-012 3.30e-016 2.52e-006 5.77e-008 1.18e-008 1.09e-008 1.13e-003 5.O1e-004 1.76e-004 3.45e-004 4.66e-003 1.87e-003 2.88e-004 3.05e-003 7.84e-002 3.20e-002 3.19e-003 Xylenes 3.95e-004 3.86e-002 C8+ Heavies 9.85e-007 9.65e-005 Total Components 100.00 9.79e+003 RICH GLYCOL STREAM Temperature: Pressure: Flow Rate: 1.9 NOTE: Stream has -20.00 deg. F 659.70 psia 6e+001 gpm more than one phase. Component Conc. Loading (wt%) (1b/hr) EG Water Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane Cyclopentane n -Hexane 7.40e+001 7.83e+003 2.53e+001 2.67e+003 4.97e-001 5.26e+001 1.81e-004 1.91e-002 9.30e-002 9.84e+000 5.05e-002 5.34e+000 1.34e-002 1.42e+000 3.72e-003 3.93e-001 4.16e-003 4.39e-001 2.13e-003 2.25e-001 9.48e-004 1.00e-001 3.32e-004 3.51e-002 6.52e-004 6.89e-002 Page: 8 Cyclohexane 1.38e-003 1.46e-001 Other Hexanes 1.77e-003 1.87e-001. Heptanes 5.45e-004 5.76e-002 Methylcyclohexane 7.20e-004 7.61e-002 Benzene 1.48e-002 1.57e+000 Toluene 3.83e-003 4.05e-001 Ethylbenzene 2.90e-004 3.06e-002 Xylenes 2.83e-003 3.00e-001 C8+ Heavies 7.60e-006 8.04e-004 Total Components 100.00 1.06e+004 COLD SEPARATOR OIL STREAM Temperature: -20.00 deg. F Flow Rate: 5.66e+001 gpm Component Conc. Loading (wt%) (lb/hr) EG 3.01e-002 7.24e+000 Water 1.85e-001 4.45e+001 Carbon Dioxide 1.29e+000 3.11e+002 Nitrogen 5.06e-003 1.22e+000 Methane 7.13e+000 1.72e+003 Ethane 2.60e+000 6.27e+002 Propane 9.09e+000 2.19e+003 Isobutane 5.92e+000 1.43e+003 n -Butane 7.14e+000 1.72e+003 Isopentane 8.12e+000 1.96e+003 n --Pentane 6.89e+000 1.66e+003 Cyclopentane 2.23e-001 5.39e+0O1 n -Hexane 4.46e+000 1.07e+003 Cyclohexane 1.25e+000 3.02e+002 Other Hexanes 9.80e+000 2.36e+003 Heptanes 1.34e+001 3.23e+003 Methylcyclohexane 3.03e+000 7.29e+002 Benzene 1.25e+000 3.02e+002 Toluene 2.78e+000 6.70e+002 Ethylbenzene 1.45e-001 3.50e+001. Xylenes 1.17e+000 2.81e+002 C8+ Heavies 1.41e+001 3.40e+003 Total Components 100.00 2.41e+004 FLASH TANK OFF GAS STREAM Temperature: Pressure: Flow Rate: 120.00 deg. F 94.70 psia 4.85e+002 scfh Component Cone. Loading (vol%) (lb/hr) Water 1.04e+000 2.41e -Q01 Carbon Dioxide 3.94e+001 2.21e+001 Nitrogen 5.02e-002 1.80e-002 Methane 4.41e+001 9.04e+000 • Ethane 1.22e+001 4.70e+000 Propane 1.89e+000 1.07e+000 Isobutane 4.Ole-001 2.98e-001 n -Butane 4.17e-001 3.10e-001 Isopentane 1.60e-001 1.47e-001 n -Pentane 6.60e-002 6.09e-002 Cyclopentane 9.35e-003 B.38e-003 n -Hexane 3.25e-002 3.58e-002 Cyclohexane 2.44e-002 2.62e-002 Other Hexanes 9.92e•-002 1.09e-001 Heptanes 1.93e-002 2.47e-002 Methylcyclohexane 1.24e-002 1.56e-002 Benzene 7.99e-002 7.98e-002 Toluene 1.30e-002 1.53e-002 Ethylbenzene 7.80e-004 1.06e-003 Xylenes 4.75e-003 6.44e-003 C8+ Heavies 6.11e-005 1.33e-004 Total Components 100.00 3.83e+O01 FLASH TANK OIL STREAM Temperature: 120.00 deg. F Page: 9 The calculated flow rate is less than 0.000001 Nmol/hr. The stream flow rate and composition are not reported. FLASH TANK GLYCOL STREAM Temperature: 120.00 deg. F Flow Rate: 1.95e+001 gpm Component Conc. Loading (wt%) (lb/hr) (ppm) EG 7.43e+001 7.83e+003 743052. Water 2.54e+001 2.67e+003 253614. Carbon Dioxide 2.89e-001 3.04e+001 2890. Nitrogen 1.10e-005 1.16e-003 0. Methane 7.58e-003 7.99e-001 76. Ethane 6.09e--003 6.41e-001 61. Propane 3.33e-003 3.51e-001 33. Isobutane 8.99e-004 9.47e-002 9. n -Butane 1.23e-003 1.30e-001 12. Isopentane 7.43e-004 7.83e-002 7. n --Pentane 3.74e-004 3.94e-002 4. Cyclopentane 2.54e-004 2.67e-002 3. n -Hexane 3.15e-004 3.32e-002 3. Cyclohexane 1.13e-003 I.20e-001 11. Other Hexanes 7.41e-004 7.80e-002 7. Heptanes 3.12e-004 3.29e-002 3. Methylcyclohexane 5.75e-004 6.05e-002 6. Benzene 1.41e-002 1.49e+000 141. Toluene 3.70e-003 3.89e-001 37. Ethylbenzene 2.81e-004 2.96e-002 3. Xylenes 2.78e-003 2.93e-001 28. • • C8+ Heavies 6.37e-006 6.71e-004 Page: 10 0. Total Components 100.00 1.05e+004 1000002. FLASH GAS EMISSIONS Flow Rate: 1.23e+003 scfh Control Method: Combustion Device Control Efficiency_ 96.00 Component Conc. Loading (vol%) (lb/hr) Water 5.31e+001 3.11e+001 Carbon Dioxide 4.59e+001 6.56e+001 Nitrogen 1.98e-002 1.80e-002 Methane 6.94e-001 3.61e-001 Ethane 1.93e-001 1.88e-001 Propane 2.98e-002 4.27e-002 Isobutane 6.32e-003 1.19e-002 n -Butane 6.56e-003 1.24e-002 Isopentane 2.51e-003 5.89e-003 n -Pentane 1.04e-003 2.44e-003 Cyclopentane 1.47e-004 3.35e-004 n -Hexane 5.11e-004 1.43e-003 Cyclohexane 3.84e-004 1.05e-003 Other Hexanes 1.56e-003 4.37e-003 Heptanes 3.04e-004 9.89e-004 Methyleyclohexane 1.96e-004 6.23e-004 Benzene 1.26e-003 3.19e-003 Toluene 2.05e-004 6.12e-004 Ethylbenzene 1.23e-005 4.23e-005 Xylenes 7.47e-005 2.58e-004 C8+ Heavies 9.62e-007 5.32e-006 Total Components 100.00 9.73e+001 REGENERATOR OVERHEADS STREAM Temperature: Pressure: Flow Rate: 212.00 deg_ F 14.70 psia 1.53e+004 scfh Component Conc. Loading (vol%) (lb/hr) Water 9.80e+001 7.13e+002 Carbon Dioxide 1.71e+000 3.04e+001 Nitrogen 1.03e-004 1.16e-003 Methane 1.23e-001 7.99e-001 Ethane 5.28e-002 6.41e-001 Propane 1.97e-002 3.51e-001 Isobutane 4.03e-003 9.47e-002 n -Butane 5.53e-003 1.30e-001 Isopentane 2.65e-003 7.72e-002 n -Pentane 1.33e-003 3.89e-002 Cyclopentane 9.38e-004 2.66e-002 n --Hexane 9.44e-004 3.28e-002 Page: 11 Cyclohexane 3.38e-003 1.15e-001 Other Hexanes 2.19e-003 7.62e-002 Heptanes 8.06e-004 3.26e-002 Methylcyclohexane 1.45e-003 5.75e-002 Benzene 4.47e-002 1.41e+000 Toluene 9.61e-003 3.57e-001 Ethylbenzene 6.16e-004 2.64e-002 Xylenes 5.94e-003 2.54e-001 C8+ Heavies 8.35e-006 5.74e-004 Total Components 100.00 7.48e+002 CONDENSER PRODUCED WATER STREAM Temperature: 120.00 deg. F Flow Rate: 1.42e+000 gpm Component Conc. Loading (wt%) (lblhx) (ppm) Water 9.99e+001 7.10e+002 999320. Carbon Dioxide 5.36e-002 3.81e-001 536. Nitrogen 5.39e-008 3.83e-007 0. Methane 7.15e-005 5.08e-004 1. Ethane 6.56e-005 4.66e-004 1. Propane 3.71e-005 2.64e-004 0. Isobutane 5.47e-006 3.89e-005 0. n --Butane 9.96e-006 7.08e-005 0. Isopentane 4.18e-006 2.97e-005 0_ n -Pentane 2.27e-006 1.61e-005 0. Cyclopentane 1.09e-005 7.72e-005 0. n -Hexane 1.59e-006 1.13e-005 0_ Cyclohexane 3.13e-005 2.23e-004 0. Other Hexanes 2.97e-006 2.11e-005 0. Heptanes 8.78e-007 6.24e-006 0. Methylcyclohexane 7.51e-006 5.34e-005 0. Benzene 1.03e-002 7.30e-002 103. Toluene 2.17e-003 1.54e-002 22. Ethylbenzene 1.22e-004 8.69e-004 1_ Xylenes 1.61e-003 1.15e-002 16_ CB+ Heavies 9.89e-009 7.03e-008 0. Total Components 100.00 7.11e+002 1000000. CONDENSER RECOVERED OIL STREAM Temperature: 120.00 deg. F The calculated flow rate is less than 0.000001 Imollhr_ The stream flow rate and composition are not reported. CONDENSER VENT STREAM Temperature: Pressure: Flow Rate: 120.00 deg_ F 12.20 psia 3.51e+002 scfh • • Page: 12 Component Conc. Loading (vol%) (lb/hr) Water 1.40e+001 2.33e+000 Carbon Dioxide 7.39e+001 3.O1e+001 Nitrogen 4.49e-003 1.16e-003 Methane 5.38e+000 7.98e-001 Ethane 2.31e+000 6.41e-001 Propane 8.60e-001 3.50e-001 Isobutane 1.76e-001 9.46e-002 n -Butane 2.42e-001 1.30e-001 Isopentane 1.16e'001 7.72e-002 n -Pentane 5.82e-002 3.88e-002 Cyclopentane 4.09e-002 2.65e-002 n -Hexane 4.12e-002 3.28e-002 Cyclohexane 1.47e-001 1.15e-001 Other Hexanes 9.56e-002 7.62e-002 Heptanes 3.52e-002 3.26e-002 Methylcyclohexane 6.33e-002 5.75e-002 Benzene 1.85e+000 1.34e+000 Toluene 4.02e-001 3.42e-001 Ethylbenzene 2.60e-002 2.55e-002 Xylenes 2.48e-001 2.43e-001 C8+ Heavies 3.65e-004 5.74e-004 Total Components 100.00 3.68e+001 COMBUSTION DEVICE OFF GAS STREAM Temperature: Pressure: Flow Rate: 1000.00 deg. F 14.70 psia 1.70e+000 sc€h Component Conc. Loading (vol%) (1b/hr) • Methane 4.45e+001 3.19e-002 Ethane 1.91e+001 2.56e-002 Propane 7.11e+000 1.40e-002 Isobutane 1.46e+000 3.78e-003 n -Butane 2.00e+000 5.19e-003 Isopentane 9.57e-001 3.09e-003 n -Pentane 4.82e-001 1.55e-003 Cyclopentane 3.38e-001 1.06e-003 n -Hexane 3.41e-001 1.31e-003 Cyclohexane 1.22e+000 4.59e-003 Other Hexanes 7.91e-001 3.OSe-003 Heptanes 2.91e-001 1.30e-003 Methylcyclohexane 5.23e-001 2.30e-003 Benzene 1.53e+001 5.35e-002 Toluene 3.32e+000 1.37e-002 Ethylbenzene 2.15e-001 1.02e-003 Xylenes 2.05e+000 9.72e-003 C8+ Heavies 3.02e-003 2.30e-005 Total Components 100.00 1.77e-001 • PARACHUTE CREEK GAS PLANT AMINE -1 INLET GAS AMINE UNIT FLASH TANK EMISSIONS 55 MMSCFIDAY GAS FLOW AND 275 GPM AMINE FLOW FROM GRI AMINECaIc MODEL M.W. Flash Tank Overhead* Flash Gas Component lb/lbmok ib/hr tons/yr lbmol/hr Carbon Dioxide 44 1.833 8.0 0.0 Nitrogen 28 0.045 0.2 0.0 Water 18 1.530 6.7 0.1 Methane 16 60.725 266.0 3.8 Ethane 30 7.228 3L7 0.2 Propane 44 2.231 9.8 0,1 i -Butane 58 0,042 0.2 0.0 n -Butane 58 0.035 0.2 0.0 i -Pentane 72 0.032 0.1 0.0. n -Pentane 72 0.020 0.1 0.0 n -Hexane 86 0.097 0.4 0.0 Other Hexanes 86 0.125 0.5 0.0 Heptanes 100 0.054 0.2 0.0 Benzene 78.1 0.391 1.7 0.0 Toluene 92.1 0.522 2.3 0.0 Ethylbenzene 106.2 0.040 0.2 0.0 Xylenes 106.2 0.196 0.9 0.0 C8+ Heavies 114 0.040 0.2 0.0 Total 75.186 329.3 4.2 Flash Flow 1630 SCF/hr * Flash Tank Overhead Routed to FLARE -1 Uncontrolled Flash VOC = 16.8 tpy VOC 7/13/2005 • JULY 2005 PLANT 3 MODIFICATION AMINE -1 Amine Unit Flash Tank Vapor Heating Rate HHV Vapor Flow Heat Rate Constituent (Btu/ib) (1b/hr) (Btu/hr), Methane 23861 60.73 1448959.23 Ethane 22304 7.23 161213.31 Propane 21646 2.23 48292.23 Isobutane 21242 0.04 892.16 n -Butane 21293 0.04 745.26 Isopentane 21025 0.03 672.80 n -Pentane 21072 0.02 421.44 all -Hexanes 20928 0.22 4646.02 Heptanes 20285 0.05 1095.39 Benzene 18172 0.39 7105.25 Toluene 18422 0.52 9616.28 Ethylbenzene 18658 0.04 746.32 Xylenes 18614 0.20 3648.34 C8+ Heavies 20747 0.04 829.88 Total All Constituents 71.78 1688884 Heat Rate (MMBtu/hr) = 1.69 Volumetric Flowrate (scflhr) = 1630 Heating. Value (Btu/scf) = 1036 Flash Tank Vapor is Constant Fuel Input Stream to FLARE -1 Note: Flash Tank Vapor Composition from AMINECa1c EMISSIONS 0705 PLANT 1 AND 2 MOD + PLANT 3.xls • PARACHUTE CREEK GAS PLANT AMINE -2 INLET GAS AMINE UNIT FLASH TANK EMISSIONS 150 MMSCFIDAY GAS FLOW AND 720 GPM AMINE FLOW FROM GRI AMINECakc MODEL M.W. Flash Tank Overhead* Flash Gas Component lb/lbmol ib/hr tons/yr lbmoVhr Carbon Dioxide 44 5.731 25.1 0.1 Nitrogen 28 0.102 0.4 0.0 Water 18 3.686 16.1 0.2 Methane 16 158.019 692.1 9.9 Ethane 30 18.23 79.8 0.6 Propane 44 5.659 24.8 0.1 i -Butane 58 0.111 0.5 0,0 n -Butane 58 0.093 0.4 0.0 i -Pentane 72 0.084 0.4 0.0 n -Pentane 72 0.054 0.2 0.0 n -Hexane 86 0.255 1.1 0.0 Other Hexanes 86 0.315 1.4 0.0 Heptanes 100 0.144 0.6 0.0 Benzene 78.1 0.904 4.0 0.0 Toluene 92.1 1.270 5.6 0.0 Ethylbenzene 106.2 0.092 0.4 0.0 Xylenes 106.2 0.482 2.1 0.0 C8+ Heavies 114 0.000 0.0 0.0 Total 195.2.31 855.1 11.0 Flash Flow 4233 SCFIhr * F1ash. Tank Overhead Routed to FLARE -2 Uncontrolled Flash VOC = 41.4 tpy VOC 7/13/2005 JULY 2005 PLANT 3 MODIFICATION Amine AMINE -2 Unit Flash Tank Vapor Heating Rate Constituent Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane all -Hexanes Heptanes Benzene Toluene Ethylbenzene Xylenes C8+ Heavies Total All Constituents Heat Rate (MMBtulhr) Volumetric Flowrate (scffhr) Heating Value (Btulscf) HHV (Btu/lb) 23861 22304 21646 21242 21293 21025 21072 20928 20285 18172 18422 18658 18614 20747 Vapor Flow Heat Rate (lb/hr) (Btu/hr) 158.0190 3770491.36 18.2300 406601.92 5.6590 0.1110 0.0930 0.0840 0.0540 0.5700 0.1440 0.9040 1.2700 0.0920 0.4820 0.0000 185.71 122494.71 2357.86 1980.25 1766.10 1137.89 11928.96 2921.04 16427.49 23395.94 1716.54 8971.95 0,00 4372192 4.37 4233 1033 Flash Tank Vapor is Constant Fuel Input Stream to FLARE -2 Note: Flash Tank Vapor Composition from AMtNECalc EiV11SSIONS 0705 PLANT 1 AND 2 MOD + PLANT 3.xls • PARACHUTE CREEK GAS PLANT 7/13/2005 • • PLANT 1&2 AMINE STILL VENT THERMAL OXIDIZER EMISSIONS HEAT RATE: AMINE -1&2 18 MMBtu/hr Emission Factor: AP -42 NOx 100 lbfMMscf = 0.1 IbfMMBtu CO 84 Ib1MMscf = 0.084 lb/MIMBtu VOC 5.5 Ib1MMscf = 0.0055 lb/MMBtu MRW (Low NOx Factor: AP -42 Low NOx = 0.05 Ib/MMiBtu) NOx 40 lb/MMscf = 0.04 lb/MMBtu PM/PM10 7.6 IbfMMscf = 0.0076 lb/MMBtu AMINE -1&2 NOx (tpy) 7.9 CO (tpy) 6.6 VOC (tpy) 0.4 PM/PM I0 (tpy) 0.6 GAS FLOW CALCULATIONS Temp. Flow Flow (deg F) scfm acfm AMINE 1&2 1600 2971 11592 EMISSIONS 0705 PLANT I AND 2 MOD + PLANT 3.xls JULY 2005 PLANT 3 MODIFICATION • PARACHUTE CREEK GAS PLANT • AMINE -3 INLET GAS AMINE UNIT FLASH TANK EMISSIONS 150 MMSCFIDAY GAS FLOW AND 720 GPM AMINE FLOW FROM GRI AMINECaIc MODEL M.W. Flash Tank Overhead* Flash Gas Component Ib/lbmol lb/hr tons/yr Ibmol/hr Carbon Dioxide 44 5.731 25.1 0.1 Nitrogen 28 0.102 0.4 0.0 Water 18 3.686 16.1 0.2 Methane 16 158.019 692.1 9.9 Ethane 30 18.23 79.8 0.6 Propane 44 5.659 24.8 0.1 i -Butane 58 0.111 0.5 0.0 n -Butane 58 0.093 0.4 0.0 i -Pentane 72 0.084 0.4 0.0 n -Pentane 72 0.054 0.2 0.0 n -Hexane 86 0.255 1.1 0.0 Other Hexanes 86 0.315 1.4 0.0 Heptanes 100 0.144 0.6 0.0 Benzene 78.1 0.904 4.0 0.0 Toluene 92.1 1.270 5.6 0.0 Ethylbenzene 106.2 0.092 0.4 0.0 Xylenes 106.2 0.482 2.1 0.0 C8+ Heavies 114 0.000 0.0 0.0 Total 195.231 855.1 11.0 Flash Flow 4233 SCFIhr * Flash Tank Overhead Routed to FLARE -3 Uncontrolled Flash VOC = 41.4 tpy VOC 7/13/2005 • JULY 2005 PLANT 3 MODIFICATION Amine AMINE -3 Unit Flash Tank Vapor Heating Rate Constituent Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane all -Hexanes Heptanes Benzene Toluene Ethylbenzene Xylenes C8+ Heavies Total All Constituents Heat Rate (MMBtu/hr) Volumetric Flowrate (scf/hr) Heating Value (Btu/scf) HHV Vapor Flow (Btullb) 23861 22304 21646 21242 21293 21025 21072 20928 20285 18172 18422 18658 18614 20747 Heat Rate (lb/hr) (Btu/hr) 158.0190 3770491.36 18.2300 406601.92 5.6590 122494.71 0.1110 2357.86 0.0930 1980.25 0.0840 1766.10 0.0540 1137.89 0.5700 11928.96 0,1440 2921,04 0.9040 16427.49 1.2700 23395.94 0.0920 1716.54 0.4820 8971.95 0,0000 0.00 185.71 4372192 437 4233 1033 Flash Tank Vapor is Constant Fuel Input Stream to FLARE -3 Note: Flash Tank Vapor Composition from AMINECa1c EMISSIONS 0705 PLANT 1 AND 2 MOD + PLANT Saris • PARACHUTE CREEK GAS PLANT 7/13/2005 • PLANT -3 AMINE STILL VENT THERMAL OXIDIZER EMISSIONS HEAT RATE: AMINE -3 27 MMBtu/hr Emission Factor: AP -42 NOx 100 lbIMMscf = 0.1 lbJMMBtu CO 84 IbfMMscf = 0.084 IbfMMBtu VOC 5.5 Ib/MMscf = 0.0055 lbfMMBtu MRW (Low NOx Factor: AP -42 Low NOx = 0.05 IbfMMBtu) NOx 40 Ib/MMscf = 0.04 Ib/MMBtu PM/PM10 7.6 lb/MMscf = 0.0076 1b/MMBtu ,AMINE -3 NOx (tpy) 11.8 CO (tpy) 9.9 VOC (tpy) 0.4 PM/PM 10 (tpy) 0.6 GAS FLOW CALCULATIONS Temp. Flow Flow ide�F/scfm acfrn AMINE -3 1600 4457 17388 EMISSIONS 0705 PLANT 1 AND 2 MOD + PLANT 3.xls • JULY 2005 PLANT 3 MODIFICATION • YAKAcHU1'E CREEK GAS PLANT PARACHUTE CREEK GAS PLANT -- - FLARE -1 EMERGENCY & PROCESS FLARE EMISSIONS , Assumptions: Flare Pilot Flow: 100 scflhr Pilot Gas Heat Value: 1040 Biulscf Flare Purge Flow: 145 scf/hr Purge Gas Heat Value: 1040 Btu/scf Pilot/Purge Operating Hrs: 8760 hr/yr Pilot/Purge MMBtu/hr. 0.255 MMBtu/hr Pilot/Purge MMBtu/yr. -- 2232 MMBtu/yr ESD Event Gas Volume: 1953 scflevent Assumed ESD Events/Yr: 4 event/yr ESD Event Duration: 1 minute Heat Value of ESD Gas: 1400 Btulscf ESD Gas MMBtu/hr. 2.73 MMBtulhr ESD Gas MMBtulyr. 10.94 MMBttdyr Maximum Flare Rating: 165 MMBtu/hr AMINE -1 Flash Flow: 1630 scf/hr Est. Flash Gas Heat Value: 1036 Btu/scf AMINE -1 Operating firs: 8760 hr/yr AMINE -1 Flash MMBtuihr: 1.69 MMBtu/hr AMINE -1 Flash MMBtu/yr: 14795 MMBtulyr DEHY-1 Flash Gas VOC Emiss. from GRI GLYCaIc DENY- I Hash Flow: 384 scf/hr Esi Flash Gas Heat Value: 709 Btu/scf DEHY- I Operating Hrs: 8760 hr/yr DEH Y- I Flash M M Btu/hr: 0.27 MMBtu/hr DEHY-I Flash MMBtu/yr: 2383 MMBtu/yr DENY -11 Still Vent VOC Enuss. from GRI GLYCaIcc DEHY- I Still Vent Flow: 226 scf/hr Est_ Still Vent Heat Value: 229 Btu/scf DEHY-1 Operating Hrs: 8760 hrlyr DEHY- I Still Vent MMBtu/1 0.05 MMBtu/hr DEHY-1 Still Vent MMBtuh 454 MMBtu/yr Maximum Flare Rating: 165 MMBtu/hr Actual Flare Heat Input: 13 MMBtu/hr AP -42 Section 13.5 Industrial Flare Emission Factors Emission Factor (Ib/MMBIu} NOx CO VOC EjA SOx 0.068 0.37 0.14 0.00 0.00 Esitmated Emissions from Pilot/Purge Only (lb/yr) NOx CO yQc PM 50a 151.78 825.86 312.49 0.00 0.00 Estimated Emissions from ESD Only (Ib/yr) NOx CO VOC PM SOx 0.74 4.05 1.53 0.00 0.00 Estimated Emissions from AMTNE-1 Flash Gas Only (lb/yr) NOx CO VOC PlvM, 5 1006.03 5474.01 2071.25 0.00 0.00 Estimated Emissions From DEHY-1 Flash Gas Only (ib/yr) NOx CO VOC PM LO -x- 162.08 881.89 467.78 0.00 0.00 Estimated Emissions From DEHY-1 Still Vent Only (lb/yr) NOx CO VOC PLM 30.86 167.91 561.52 0.00 _0.00 Estimated Total Emissions All Sources (1b/yr) Ma. CO VOC SOx 1320.63 7185.80 3414.57 0.00 0.00 Estimated Total Emissions All Sources (toriyr) NOx CO VOC DA Sox 0.7 3.6 1.7 0.0 0.0 7/13/2005 END IONS 0705 m ANT 1 AND 2 MOA + PLANT 3.sls JULY 2005 PLANT 3 MODIFICATION • PARACHUTE CREEK GAS PLANT JULY 2005 PLANT 3 MODIFICATION DEMONSTRATION OF COMPLIANCE WITH FLARE DESIGN AND OPERATING REQUIREMENTS OF 40 CFR PART 60.18 PROCESS & EMERGENCY FLARE -I Compliance With Section (c)(1): Flares shall be designed for and operated with no visible emissions as determined by the methods specified in paragraph (f), except for periods not to exceed a total of 5 minutes during any 2 consecutive hours. RARE -I is designed and operated with no visible emissions. Flare design meets requirements sct forth in paragraph (f) as indicated below. Compliance With Section (c)(2): Flares shall be operated with a flame present at all times, as determined by the methods specified in paragraph (f). FLARE -I is operated with a flame present at all times, and is in compliance with requirements of paragraph (1) as indicated below. Compliance With Section (c)(3); An owner/operator has the choice of adhering to either the heat content specifications in paragraph (c)(3)(ii) of this section and the maximum tip velocity specifications in paragraph (c)(4) of this section, or adhering to the requirements in paragraph (cX3)(i) of this section. Williams has chosen to adhere to the heat content specifications in paragraph (cX3Xii) and the maximum tip velocity specifications in paragraph (c)(5) of this section, as presented below. Compliance With Section (e)(3)(ii): Flares shall be used only with the net heating value of the gas being combusted being 11.2 MJ/sem (300 Btu/scf) or greater if the flare is steam -assisted or air -assisted; or with the net heating value of the gas being combusted being 7.45 MJ/scm (200 Btu/ssci) or greater if the flare is nun -assisted. FLARE -1 is air -assisted and the net heating value of the gas being combusted is estimated to range between 900 and 1,000 Bluiscf, and FLARE -1 therefore is in compliance with the heat content specifications of section (cX3Xii). Compliance With Section (c){5): Air -assisted flares shall be designed and operated with an exit velocity 1Lts than the velocity Vmax, as determined by the method specified in paragraph (f)(6). FLARE -1 is air -assisted and is operated in compliance with the maximuin tip velocity specifications of section (c)(5), with an exit velocity less than. Vmax. as determined by the method specified in paragraph (Q(6). and as presented below. Compliance With Section (d). Owners or operators of flares used to comply with the provisions of this subpart shall monitor these control devices to ensure that they are operated and maintained in conformance with their designs. Williams monitors FLARE -1 to ensure that it is operated and maintained in conformance with its design. and therefore is in compliance with section (d). 7/13,2005 EMISSIONS 1)705 PLANT 1 AND 2 MOD ♦ PLANT 3.11s YAK/ . 111U 1 r Li(EEK GAS PLANT C_ ompiiance With Section (e): JULY 2005 PLANT 3 MODIFICATION Flares used to comply with provisions of this subpart shall be operated al all times when emissions may he vented to tbem. FLARE -1 is operated at all banes emissions arc vented to it, and therefore is in compliance with section (e). Compliance With Section (f)(1): Method 22 of Appendix A to this part shall be used to determine compliance of flares with the visible emission provisions of this subpart. Williams will conduct a visible emissions test of FLARE -1 in accordance with Method 22 to dernonstraie compliance with this section, Compliance With tiettion (f)(2): The presence of a flare pilot flame shall be monitored using a thermocouple or any other equivalent device to detect the presence of a flame_ FLARE -1 is equipped with two pilot flames, both of which arc equipped with a type "K" thermocouple for confirmation of a pilot flame, and FLARE -1 therefore is in compliance with section (0(2). Compliance With Section ()(3): The net healing value of the gas being combusted in a flare shall be calculated using the following equation. The net heating value of the gas being combusted in FLARE -1 was calculated in a manner consistent with the specified equation, and therefore is in compliance with section (f)(3). Compliance With Section (f)(4): The actual exit velocity of a flare shall be determined by dividing the volumetric flowrate (in units of standard temperature and pressure), as determined by Reference Methods 2, 2A, 2C, or 2D as appropriate; by the unobstructed (free) cross-sectional area of the flare lip. The actual velocity of FLARE -1 was determined by dividing the calculated volumetric flowrate based on operating specifications and computer model output data as appropriate, hy the free cross-sectional area of the flare tip, and as such, is in compliance with section (0(4). Compliance With Section (f)(6): The maximum permitted velocity, Vmax, for air -assisted flares shall be determined hy the following equation. Vmax = 8.706 + 0.7084 * Hl, where Vmax is in rises and lit is in MJlscm The maximum permitted velocity, Vmax, for FLARE -I was calculated using the specified equation, and Williams therefore is in compiance with section (0(6). 7/13/2005 EMISSIONS 0705 PLANT 1 ANI) 2 MOD * PLANT 3-ils • • YAKAL.t1U I l CK1Ii.K (AS [LAST JULY 2005 PLANT 3 MODIFICATION PARACHUTE CREEK GAS PLANT FLARE DESIGN VELOCITY SUMMARY FLARE ID NUMBER 1 FLARE OPERATING CONDITION - FEED GAS r FEED FLOW RATE (SCF/FIR) HEATING VALUE (BTU/SCF) FLARE DIAMETER (FT) ACT(JAL FLARE GAS TIP VELDCTTY (FT/SEC) CALCULATED MAXIMUM VELOCITY Vans (FT/SEC) REGULATORY MAXIMUM VELOCITY Valais (FT/SEC) FLARE TEP~ VE 1.QCITY LESS THAN MAXIMUM VELOCITY FLARE -1 ROUTINE AMINE FLASH 1630 1036 DENY -1 FLASH 384 709 DENY -I STILL 226 229 PRAT/PURGE\ 245 1040 COMBINED 2485 -_ 913 I.00 0.88 107 107 YES 1 _ (SCF/MIN) EMERGENCY INLET GAS 1953 1067 1.00 41 122 122 YES COMBINED ALL ABOVE 1994 1063 1.00 42 122 122 — YES ' Notes: Flare is Air -Assisted Heating Value = Sum of the Product of the Component Hua of Combustion and Mole Fraction, Divided by 385.3 scf/Tmok Actual Flan Tip Velocity is Calculated by Dividing Feed Gas Flow Rate by Cross -Sectional Area of Flare Tip Fur Air -Assisted Flares: Varna is Calculated as Follows: Vmax = (8.706 + 0.7064 " Heating Value) in meter/sec For SlesmAssisted and Non -Assisted Flares: Vmax is Calculated as Follows: log10(Vaa x) = (Hearing Value + 28.8)/31.7 in triter/sic For Feed Gases Greater Than 1.000 Bnslscf, Maximum Velocity is Esser of Calculated Vrrax or 400 ft/sec. For Fred Gases less Than 1.000 BS lsef. Maximum Velocity is Lesser of Cakulued Vrrsax or 6011/see. 7113/2005 EMISSIONS 0705 PLANT 1 AND 2 MOD + PLANT 3. xis • I. a ....1-101..11,1., .u ...a t fl u ef.., , 141111 1 PARACHUTE CREEK GAS PLANT FLARE -2 EMERGENCY & PROCESS FLARE EMISSIONS Assumptions: Flare Pilot How: 100 scf/hr Pilot Gas Heat Value: 1040 Blu/scf Flare Purge Row: 145 scf/hr Purge Gas Heat Value: 1040 Btu/scf Pilot/Purge Operating Hrs: 8760 hr/yr Pilot/Purge MMBtu/hr: 0.255 MMBtu/hr Pilot/Purge MMBtu/yr: 2232 MMB1u/yr ESD Event Gas Volume: 3906 scf/event Assumed ESD Events/Yr: 4 event/)T ESD Event Duration: 1 minute Heat Value of ESD Gas: 1400 litu/scf ESD Gas MMBtufhr: 5.47 MMBtuIhr ESD Gas MMBtuiyr: 21.87 MMllltu/yr Maximum Flare Rating: 165 MMBtu/hr AMINE -2 Flash Flow: 4233 scf/hr Est. Flash Gas Heat Value: 1033 Btu/scf AMINE -2 Operating Hrs: 8760 hr/yr AMINE -2 Flash MMBtuthr: 437 MMBtufir AMINE -2 Flash MMBtu/yr: 38300 MMBtu/yr DENY -2 Flash Gas VOC Emiss. from GRI GLYCakc DEH Y-2 Flash Flow: 507 scf/hr Est. Flash Gas Heat Value: 761 Bluiscf DENY -2 Operating Firs: 8760 hr/yr DEHY-2 Flash MMBtu/hr: 039 MMI3tulhr DEHY-2 Flash MMBtu/yr. 3378 MMBtu/yr DENY -2 Still Vent VOC Emiss. from GRI GLYCaIc DEITY -2 Still Vent Flow: 282 scf/hr Est. Still Vent Gas Heat Valu 253 Btu/scf DEHY-2 Operating }Its: 8760 hr/yr DEHY-2 Still Vent MMBIu/I 0.01 MMBtu/hr DEHY-2 Still Vent MMBtu/• 624 MMHIulyr DEIFY -3 Flash Gas VOC Emiss. from GRI GLYCaIc DENY -3 Flash Flow: 738 scf/hr Est. Flash Gas Heat Value: 1158 Btu/scf DEHY-3 Operating Hrs: 8760 hr/yr DEHY-3 Flash MMBIuJhr: 0.85 MMBndhr DENY -3 Flash MMBiu/yr: 7484 MMBtu/yr DEHY-3 Still Vent VOC Emiss. from GR1 GLYCaIc DEHY-3 Still Vent Flow: 333 scf/hr Est. Still Vent Gas Fleat Valu 1611 Btu/scf DEHY-3 Operating 1lrs: 8760 hrfyr DEHY-3 Still Vent MMBtu/1 0.54 MMBtu/hr DEFHY-3 Still Vent MMBtu/_ 4698 MMI3ttdyr Maximum Flare Rating: 165 MMI3tuihr Actual Flare Heat Input: 28.3 MMBtu/hr 7113/2005 EMISSIONS 0705 PLANT 1 AND 2 MOD + PLANT 3.:Js JUL]i MI5 PLANT 3 MODIFICATION PARACJfl)TE CREEK GAS PLANT PARACHUTE CREEK GAS PLANT /FLARE -2 EMERGENCY & PROCESS FLARE EMISSIONS AP -42 Section 13.5 Industrial Rare Emission Factors Emission Factor(IbIMMBtu) VOC pm SOx 0.068 0.37 0.14 0.00 0.00 Esitmated Emissions from Pilot/Purge Only (lb/yr) N, [tea CO VOC PM SOx 151.78 825.86 312.49 0,00 0.00 Estimated Emissions from ESD Only (lb/yr) NO; CO VOC PM SOx 1.49 8.09 3.06 0.00 0.00 Estimated Emissions from AMINE -2 Flash Gas Only (Ib/yr) ii) CO VOC M $Ox 1 2604.43 14171.15 5362.06 0.00 0.00 Estimated Emissions From DEHY-2 Flash. Gas Only Ob/yr) NON ycK, PM SON 229.73 1250.01 617.58 0.00 0.00 Estimated Emissions From DEHY-2 Still Vent Only (Ib/yr) NOr. C.Q IrcK PM SON 42.46 231.06 727.08 0.00 0.00 Estimated Emissions From DEHY-3 Flash Gas Only (lhlyr) NON VOC ELI SOS( 508.94 2769.25 2564.93 0.00 0.00 Estimated Emissions From DEHY-3 Still Vent Only (Ib/yr) 13121, CO VOC PM SON, 319.50 1738.44 7233.13 0.00 0.00 Estimated Total Emissions All Sources (lb/yr) 12 CO VOC PM LQA 3858.33 20993.86 16820.33 0.00 0.00 Estimated Total Emissions Pilot/Purge, ESD & Flash (ton/yr) NQx CO VOC E 02 1.9 103 8.4 0.0 0.0 711 v:oos EMISSIONS 0705 PLANT 1 AND I MOD+ PLANT 3.sls JULY 2005 PLANT 3 MODIFICATION • PARACHUTE CREEK GAS PLANT JULY 2005 PLANT 3 MODIFICATION DEMONSTRATION OF COMPLIANCE WITII FLARE DESIGN AND OPERATING REQUIREMENTS OF 40 CFR PART 60.18 PROCESS & EMERGENCY FLARE -2 Compliance With Section (c)(1): Flares shall be designed for and operated with no visible emissions as determined by the methods specified in paragraph (f), except for periods not to exceed a total of 5 minutes during any 2 consecutive hours. F1 ARE -2 is designed and operated with no visible emissions. Flare design meets requirements set forth in paragraph (1) as indicated below.. Compliance With Section (c)(2): Flares shall be operated with a flame present al all times, as determined by the methods specified in paragraph (1). FLARE -2 i5 operated with a flame present at all times, and is in compliance with requirements of paragraph (0 as indicate! below. Compliance With Section (c)(3): An owner/operator has the choice of adhering to either the heat content specifications in paragraph (c)(3)(ii) or this section and the maximum tip velocity specifications in paragraph (c)(4) or this section, or adhering to the requirements in paragraph (c)(3)(i) of this section. Williams has chosen to adhere to the heat content specifications in paragraph (c)(3Xii) and the maximum tip velocity specifications in paragraph (cX5) of this section, as presented below. Compliance With Section (c)(3)(ii): Flares shall be used only with the net heating value of the gas being combusted being 11.2 MJ/gem (300 BIu/scf) or greater if the flare is steam -assisted or air -assisted, or with the net heating value or the gas being combusted being 7.45 h1JIsco (200 Btu/sscf) or greater if the flare Ls non -assisted. FLARE -2 is air -assisted and the net heating value of the gas being combusted is approximately 1.022 Blu/scf, and FLARE -2 therefore is in compliance with the heat content specifications of section (cX3Xii)- Compliance With Section (c)(5): Air -assisted flares shall be designed and operated with an exit velocity less than the velocity Vmax, as determined by the method specified in paragraph (f)(6). FLARE -2 is air -assisted and is operated in compliance with the maximum tip velocity specifications of section (c)(5), with an exit velocity less than Vmax, as determined by the method specified in paragraph (0(6), and as presented below. 7/13/2005 EMISSIONS 0705 PLANT 1 ANI) 2 R1C/f1 + PLANT 3.x1s PARACIIUTE CREEK GAS PLANT JULY 2005 PLANT 3 MODIFICATION Compliance With Section (d): Owners or operators of flares used to comply with the provisions of this subpart shall monitor these control devices to ensure that they are operated and maintained in conformance with their designs. Williams monitors FLARE -2 to ensure that it is operated and maintained in conformance with its design, and therefore is in compliance with section (d). Compliance With Section (e): Flares used to comply with provisions of this subpart shall he operated at all times when emissions may be vented to them. FLAKE -2 is opetaled at all tithes emissions are vented to it, and therefore is in compliance with section (c). Compliance With Section (f)(l): Method 22 of Appendix A to this part shall be used to determine compliance of flares with the visible emission provisions of this subpart. Williams will conduct a visible emissions test of FLARE -2 in accordance with Method 22 to demonstrate compliance with this section. Compliance With Section (0(2); The presence of a flare pilot flame shall be monitored using a thermocouple or any other equivalent device to detect the presence of a flame. FLARE -2 is equipped with two pilot flames, both of which are equipped with a type "K" thermocouple for confirmation of a pilot flame, and FLARE -2 therefore is in compliance with section (0(2). Compliance With Section 0)(3): The net healing value of the gas being combusted in a flare shall be cat 'tailed using the following equation. The net heating value of the gas being combusted in FLARE -2 was calculated in a manner consistent with the specified cqualion, and therefore is in compliance with section (0(3). Compliancy With Section (0(4): The actual exit velocity of a flare shall be determined by dividing the volumetric flowrate (in units or standard temperature and pressure),, as determined by Reference Methods 2, 2A, 2C, or 21) as appropriate; by the unobstructed (free) cross-sectional area or the flare tip. The actual velocity or FLARE -2 was determined by dividing the calculated volumetric flowrate based on operating specifications and computer model output data as appropriate. by the free cross-sectional 7/13/2005 EMISSIONS 0705 PLANT 1 AND 2 MOD + PLANT lids • rrati../at.riu 1 r, 1.8C r 1,AN rLAN I area of the flare tip. and as such, is in compliance with section (0(4). Compliance With Section (7)(6): i7te maximum permitted velocity, Vmax, for air-assisled 'flares shall be determined by the following equation. Vmax = 8.706 r 0.7054 * fit, where 'Vmax is in rn/sec and 111 is in NU/sem JULY 2005 PLANT 3 NIODiF1CATION The maximum permitted velocity, Vmax, for FLARE -2 was calculated using the specified equation, and Williams therefore is in compiance with section (f)(6). PARACHUTE CREEK GAS PLANT FLARE DESIGN VELOCITY SUMMARY FLARE TO NUMBER FLARE OPERATING C'ONDrTlON FEED GAS FEED FLOW RATE (SCE/11R) HEATING VALUE (BTU/SCO HARE DIAMETER (YF) ACTUAL FLARE GAS TIP VELOCITY (FT/SEC) CALCULATED MAXIMUM VELOCITY Vaax (tT/SEC) REGULATORY MAXIMUM VELOCITY Vnax (FT/SEC) FLARE TIP VELOCITY LESST}IAN MAXIMUM VELOCITY AMINE -2 FLARE -2 ROUTINE FLASH 4233 1033 DF1-IY-2 FLASH 507 761 DENY -2 STIR VENT 282 253 DEHY-3 FLASH r)EHY-3 738 1158 STILL VENT 333 161 t PILOT/PURGE 245 1040 COMBINED 6338 1022 3.00 0.25 116 116 YES (SCF/MIN) • EMERGENCY INLET GAS 3906 1tFf7 300 9 122 122 TES COMBINED ALL AIIOVE 41)12 11165 3.00 9 122 122 YES Nares Flays is Air-Asis1ed Healing Value = Sum of [Fre Pre duel of the Componeni Hear of Combustion and Mole Fraction, Divided by 385.3 sef/Ibrrrok Actual Flare Tip Velocity is Cakulatcd'by Dividing Feed Gas Flow Rale by Cross -Sectional Area of Flare Tip For Air -Assisted Flares: Vmax is Cakulalsd as Follows: Vmax = (11.706. 0.7084 • }sealing Value) in «rter/sec For Stearn-Assisied and Non -Assisted Flarex: Vmax is Calculated as Follows: tog11.8Vnrtax) _ (Heating Value + 213 8)131.7 in meter/sec For Feed Gaza Greater Than 1,000 Bru/scf. Maximum Velocity is Lesser of Calculated Venal or 400 fl/sec For Feed Gases Less'fhan 1.000 Btu/sef, Maximum Velocity is Lesser of Calculated Vmax or 60 FI/ ec. 1 7/13/2006 EMISSIONS 0705 PLANT 1 AND 2 MOD + Pt.ANT 3.d • PARACHUTE CREEK GAS PLANT PARACHUTE CREEK GAS PLANT FLARE -3 EMERGENCY & PROCESS FLARE EMISSIONS Assumptions: Flare Pilot Flow: 100 scoter Pilot Gas Heat Value: 1040 Btulscf Flare Purge Flow: 145 sally Purge Gas Heat Value: 1040 Btu/scf Pilot/Purge Operating llrs: 8760 hr/yr Pilot/Purge MMBtu/hr: 0.255 MMBtuthr Pilot/Purge MMBtu/yr: 2232 MMBtu/yr ESD Event Gas Volume: 1953 sof/event Assumed ESD Events/Yr. 4 event/yr ESD Event Duration: I minute Heat Value of ESD Gas: 1400 Btu/scf ESD Gas MMBIu hr: 233 MMBtu nr ESD Gas MMBtu/yr: 1094 MMBtu/yr Maximum Flare Rating: 165 MMB1u/hr AMINE -3 Flash Row: 4233 scf/hr Est. Flash Gas Heat Value: 1033 Btu/scf AMINE -3 Operating Hrs: 8760 hr/yr AMINE -3 Flash MMBtuRhr: 4,37 MMBtu/hr _ AMINE -3 Rash MMBtu/yr: 38300 MMBtu/yr DEHY-4 Flash Gas VOC Emiss. from GRI GLYCaIc DEHY-4 Flash Flow: 485 scf/hr Est. Flash Gas Heal Value: 757 Btu/scf DEHY-4 Operating Hrs: 8760 hr/yr DEHY-4 Flash MMBtu/hr: 0.37 MMBtu/hr DEHY-4 Rash MMBtu/yr. 3217 MMBtuiyr DEHY-4 Still Vent VOC Emiss. from GR1 GLYCakc DEHY-4 Still Vent Flow: 351 scf/hr Est. Still Vent Heat Value: 259 Btu/scf DEH Y-4 Operating Hrs: 8760 he/yr DEHY-4 Still Vent MMBtu/1 0.09 MMBtu/hr DENY -4 Still Vent MMBtu1 796 MMBtu/yr Maximum Hare Rating: 165 MMBtu/hr Actual Flare Heat Input: 16 MMBIu/hr AP -42 Section 13.5 Industrial Flare Emission Factors Emission Factor (Ib/MMgtu) CO VOC PAM 50x 0.068 0.37 0.14 0.00 0.00 Esitmated Emissions from Pilot/Purge Only (1b/yr) NOx CO VOC PM SOx 151.78 825.86 312.49 0.00 0.00 Estimated Emissions from ESD Only (lb/yr) NOx CO VOC pm SOx 0.74 4.05 1.53 0.00 0.00 Estimated Emissions from AMINE -3 Hash Gas Only (Ib/yr) co VOC FM 50x 2604.43 14171.15 5362.06 0.00 0.00 Estimated Emissions From DOHY-4 Flash Gas Only (lb/yr) CO VOC PM SOx 218.78 1190.40 771.76 0.00 0.00 Estimated Emissions Frain DEHY-4 Still Vent Only (Iblyr) x CO VOC PM Sax 54.13 294.52 1044.19 0.00 0.00 Estimated Total Emissions All Sources (Ib/yr) NOx CO VOC 5Qx 2975,73 16191.46 7492,02 0.00 0.00 Estimated Total Emissions All Sources (ton/yr) NOx CO VOC EM 50x 1.5 8.! 3.7 0.0 0.0 7/13/2O0S EMISSIONS 0705 PLA NT I AND 2 MOD + PLANT 3.xls JULY 2005 PLANT 3 MODIFICATION • t'At(A1 u Li 1 P. CHEEK GAS PLANT JULY 2005 PLANT 3 MODIFICATION DEMONSTRATION OF COMPLIANCE WITH FLARE DESIGN AND OPERATING REQUIREMENTS OF 40 CFR PART 60.18 PROCESS & EMERGENCY FLARE -3 Compliance With Section (e)(1): Flares shall be designed for and operated with no visible emissions as determined by the methods specified in paragraph (I), except for periods not to exceed a total of 5 minutes during any 2 consecutive hours. FLARE -3 is designed and operated with no visible emissions. Flare design meets requirements set forth in paragraph (1) as indicated below. Compliance With Section (c)(2): Flares shall be operated with a flame present at all times, as determined by the methods specified in paragraph (1). HARE -3 is operated with a flame present at all times, and is in compliance with requirements of paragraph (f) as indicated below. Compliance With Section (c)(3): An owner/operator has the choke of adhering to either the heat content specifications in paragraph (c)(3)(ii) of this section and the maximum hp velocity specifications in paragraph (cX4) of this section, or adhering to the requirements in paragraph (c)(3)(i) of this section. Williams has chosen to adhere to the heat content specifications in paragraph (cX3Xii) and the maximum lip velocity specifications in paragraph (0(5) of this section, as presented below. Compliance With Sectionjc)(3)(ii): Flares shall be used only with the net heating value of the gas being combusted being 11.2 MJlscm {300 Btu/sell or greater if the flare is steam -assisted or air -assisted; or with the net heating value of the gas being combusted being 7.45 M Ilscrn (200 Btu/sscl) or greater if the flare is non -assisted. FLARE -3 is air -assisted and the net heating value of the gas Luing combusted is estimated tv range between 900 and !.00013tuiscf, and FLARE -3 therefore is in compliance with the heat content specifications of section (c)(3)(ii). Compliance With Section (c)(51: Air -assisted flares shall be designed and operated with an exit velocity less than the velocity Vmax, as determined by the method specified in paragraph (f)(6). FLARE -3 is air -assisted and is operated in compliance with the maximum tip velocity specifications of section (eX5), with an exit velocity less than Vmax, as determined by the method specified in paragraph (f)(6), and as presented below. Compliance With Section (d): Owners or operators of flares used to comply with the provisions of this subpart shall monitor these control devices to ensure that they are operated and maintained in conformance with their designs. Williams monitors FLARE -3 to ensure that it is operated and maintained in conformance with its design, and therefore is in compliance with section (d). ComplianceWith Section (e): Flares used to comply with provisions of this subpart shall be operated at all times when emissions may be vented to them. FLARE -3 is operated at all limes emissions are vented to it, and therefore is in compliance with section (e). Compliance With Section (f)(1): 7/13!2005 EMt,SStONS 0705 PLANT 1 AND 2 MOD+ PLANT 3.als • PARACHUTE CREEK GAS PLANT JULY 2005 PLANT 3 MODIFICATION Method 22 of Appendix A to this part shall be used to determine compliance of flares with the visible emission provisions of this subpart. Williams will conduct a visible emissions test of FLARE -3 in accordance with Method 22 to demonstrate compliance with this section. Compliance With Section (f)(2): The presence of a flare pilot flame shall he monitored using a thermocouple or any other equivalent device to detect the presence of a flame. FLARE -3 is equipped with two pilot flames, both of which are equipped with a type "K" thermocouple for confirmation of a pilot flame, and FLARE -3 therefore is in compliance with section (f)(2). Compliance With Section (f)(3): The net heating value of the gas being combusted in a flare shall be calculated using the following equation. The net heating value of the gas being combusted in FLARE -3 was calculated in a manner consistent with the specified equation, and therefore is in compliance with section (f)(3).. Compliance With Section (f)(4): The actual exit velocity of a flare shall be determined by dividing the volumetric flow rate (in units of standard temperature and pressure), as determined by Reference Methods 2, 2A, 2C, or 2D as appropriate; by the unobstructed (free) cross-sectional area of the flare tip. The actual velocity of FLARE -3 was determined by dividing the calculated volumetric flowrate based on operating specifications and computer model output data as appropriate. by the free cross-sectional area of the flare tip, and as such. is in compliance with section (f](4). Compliance With Section (f)(6): The maximum permitted velocity, Vmax, for air -assisted flares shall be determined by the following equation. Vmax 8.706+ 0.7084' Ht, where Vase is in misec and }ft is in 144JJscm The maximum permitted velocity, Vmax, for FLARE -3 was calculated using the specified equation, and Williams therefore is in compiance with section (Q(6). PARACHUTE CREEK GAS PLANT FLARE DESIGN VELOCITY SUMMARY FLARE ID NUMBER FLARE OPERATING CONDITION FLED GAS FEED FLOW RATE (SCFIHIR) HEATING VALUE (BTU/SCF) FLARE DIAMETER (FT) ACTUAL FLA'R'E GAS TIP VELOCTIY (FTJSEC) CALCULATED MAXIMUM VELOCITY Vilma (FT/SEC) REGULATORY MAXIMUM VELOCITY Vmax (FTISEC) FLARE TTP VELOCITY LESS THAN MAXIMUM VELOCITY FLARE -1 ROUTINE AMINE.) FLASH 4233 1033 DEHY-4 FLASF 485 757 DEHY-4 Still 351 259 PILOT/PURGE 245 1040 COMBINED 5314 957 190 188 III 111 YES (SCFIMLN) EMERGENCY INLET GAS 1953 1087 100 41 1 2 122 YF5 COMBINED ALL ABOVE 2042 1081 1.00 43 i22 i22 YES Notes: Hare is Air• Assisted Ikating Value = Sum of the Product of ter Congovern licar of Combustion and Mole I saction, Divided by 385 3 sctllbmak Actual Flare Tip Velocity is Calculated by L vtding Feed Gas F)nw Rare by Cruss•Scr. norsal Mea. of Flare Tip Fur Air -Assisted flares: V rnax is Calculated as Follows: V rrtax = (8 706 + 0-70$4 • tfrattng Value) in nnerrrlsec I or Stearn -Assisted and Non -Assisted Flours: Vmax rs Calculated as Follows: IoglO(Vtrlut) _ (Heating Value + 28 801.7 in rrrierrsec 1 ter Feed Gases Greater Than 1.000 Btuhcf. Maximum Velocity is Lesser of Calculated Vman or 400 fusee I of lied Gases less Than 1.000 Brisket. Maximum Vekxity is Lesser of Cakulated Vena.% or 60 fVscc. 7/13/2005 EMISSIONS 0705 PLANT 1 AMP 2 MOD 4- PLANT 3.trts PARACHUTE CREEK GAS PLANT TK-3/TK-4 E&P TANK2.0 CONDENSATE INPUT PARACHUTE CREEK GAS PLANT T R-I/PK-2 E&P TANKZ.0 CONDENSATE INPUT Annual Hrs of Operation Annual Hrs of Operation 8760 (<= 8760 hrfyr) Pressurized Condensate Analysis Pressurized Condensate Analysis AWRur 2t) 2003 Await 2o. 2003 Number of Tanks Number of Tanks 2 Liquid Liquid Condensate Flow Rale 3.00 bbtlday total Carni oneni Eh VoI.) Operating Hours/Year 365 hours/yr Hydrogen Sulfide 0.000 Inlet Separator Temperature 89 deg F Oxygen 0.000 Inlet Separator Pressure 721 psig Carbon Dioxide 2.438 Nitrogen Nitrogen 0.000 Sire Atmospheric Pressure 123 psia Methane 14.923 Ethane Ethane 6.704 Stable Oil API Gravity 55.5 deg. API Stable OilReid Vapor Press Stable Oil Reid Vapor Press 5 psia Propane 4.882 Isobutane Isobutane 2.213 E & P TANK V2.0 Model Output n•Buianc 2.600 !t([t 11122 Isopentane 2378 VOC. C3+ 233 10.2 Pentanes 2.491 Benzene 0.015 0.1 Toluene Toluene 0.019 0.1 Hexanes 7367 Ethylbenzene 0.001 4.0 Heptanes 16.404 Xylenes 0.005 0.0 Octanes 10.935 n -Hexane 0.046 0.2 Nonanes 7.217 Methane 1.096 4.8 Decanes+ 5.861 Ethane 0.923 4.0 Aggregate 1{AP Aggregate HAP 0.086 0.4 Benzene 1.090 Toluene Toluene 4.700 Ethylbensene Ethylbenzene 0.487 Xylenes Xylenes 4.118 it -Hexane n -Hexane 2.792 2,2,4-Trimethylpentant 2,2,4-Trimethylpentant 0.000 Total All Constituents Total All Constituents 100.000 PARACHUTE CREEK GAS PLANT TK-3/TK-4 E&P TANK2.0 CONDENSATE INPUT Annual Hrs of Operation 8760 (a= 8760 hr/yr) Pressurized Condensate Analysis AWRur 2t) 2003 Number of Tanks 2 Liquid Condensate Flow Rate 6.0 bbllday total Component f% Vo1.Z Operating Hours/Year 365 hours/yr Hydrogen Sulfide 0.000 Inlet Separator Temperature 89 deg F Oxygen 0.000 Inlet Separator Pressure 721 prig Carbon Dioxide 2.438 Nitrogen 0.000 Site Atmospheric Pressure 12.5 psia Methane 14.923 Ethane 6.704 Stable Oil APl Gravity 55.5 deg. API Stable OilReid Vapor Press 5 psia Propane 4.882 Isobutane 2.213 E & P TANK V2.0 Model Output n-Burane 2.600 III t ray Isopenlane 2.578 VOC, C3+ 4.661 20.4 Pentanes 2.491 Benzene 0.029 0.1 Toluene 0.038 0.2 Hexanes 7.567 Ethylbcnzene 0.001 0.0 Heptanes 16.404 Xylenes 0.010 0.0 Octanes 10.935 n -Hexane 0.092 0.4 Nonanes 7.217 Methane 2.192 9.6 Dr cartes+ 5.861 Ethane 1.845 8,I Aggregate 1{AP 0.170 0.7 Benzene I.090 Toluene 4.700 Ethylbensene 0.487 Xylenes 4.118 it -Hexane 2.792 2,2,4-Trimethylpentant 0.000 Total All Constituents 100.000 711312005 EMISSIONS 0705 .PLANT 1 AND 2 MOD + PLANT l.sb PARACHUTE CREEK GAS PLANT TK-511-1{•6 E&P TANK2.0 CONDENSATE INPUT Annual Hrs of Operation 8760 (c= 8760 hr/y) IPrrsxurized Condensate Analysis hogwr 20. 200.1 Number of Tanks 2 Liquid Condensate Flow Rate 6.0 hbl/day total 't riponent J96 Vat.) Operating Hours/Year 365 hours/yr Hydrogen Sulfide 0.000 Inlet Separator Temperature 89 deg E Oxygen 0.000 lnkt Separator Pressure 721 pig Carbon Dioxide 2.438 Nitrogen 0.000 Site Atmospheric Pressure 12.5 psia Methane 14.923 Ethane 6.704 Stable Oil API Gravity 55.5 deg. API Stable Oil Reid Vapor Press 5 psia Propane 4.882 Isobutane 2.213 E & P TANK_V2..0 Model Output n•Butane 2.600 1tv'hr lily Isopentame 2.578 VOC, C3+ 4.661 20.4 Pentanes 2.491 Benzene 0.029 0.1 Toluene 0.038 0.2 Hexanes 7.567, Ethylbenzene 0.001 0.0 Heptanes 16.404 Xylenes 0.010 0.0 Octanes €0.935 n-Hexane 0.092 0.4 Nonancs 7 217 Methane 2.192 9.6 Decanes+ 5.861 Ethane 1.845 8.1 Aggregate HAP 0.170 0.7 Benzene 1.090 Toluene 4.700 Ethylberszene 0.487 Xylenes 4.118 n-Hexane 2,792 2.2,4-Ttimethylpcntant 0.000 Total All Constituents 100.000 7FI312OO5 EMISSION S 0105 PLANT I AND 2 MUD + PLANT 3.ah • • • E&P TANK V2.0 Calculat on Report--- Developed by Db Robinson & Associates Ltd. 2005.07.15 • Project Setup information • Project File Flowsheet Selection Calculation Method Control Rfficiency Knows Separator Stream Entering Air Composition Filed Fume Well Name Well ID Date : U:\GAS PLANTS\PCGPiPLIIT! 3 MOD 0705\TK5 6 NO CONTROLS.ept • 011 Tank with Separator • RVP Distillation : 100.0% x High Presaure Oil : No : PARACHUTE CREEK CONDENSATE TANKS TIC-5/TIS-6 : PARACHUTE CREEK GS PLANT -3 : NO CONTROLS 2001.12.10 Data input Separator Pressure Separator Temperature Ambient Pressure Ambient Temperature C10+ SO C10+ MW High Pressure O11 Na. 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 • 650.0Oipaig] • 90.00(F3 x 12.80(psia3 70.00[T] : 0.7370 : 148.36 . r.wr.t..* Component B2S 02 CO2 N2 Cl C2 C3 i -c4 n -C4 i-05 n-05 C6 C7 C8 C9 c10+ Benzene Toluene E -Benzene Xylenes n -C6 224Trimetbylp - - Sales Oil mut % 0.0000 0.0000 2.4380 0.0000 14.9230 6.7040 4.8820 2.2130 2.6000 2.5780 2.4910 7.5670 16.4040 10.9350 7.2170 5.8610 1.0900 4.7000 0.4870 4.1180 2.7920 0.0000 Production Rate Days of Annual operation API Gravity Reid Vapor Pressure • 6(bbl/day] • 365 (days/year) 55.0 : 5.00(paia] Calculation Results - - Emission Stiammary r Item Uncontrolled [ton/yr] Uncontrolled (1b/hr] page 1 . EiP TANK V2.0 Calculation Report--- Developed by DB Robinson 4 Associates Ltd. 2005.07.15 Total SAFs Total HC VOCs, C2+ VOCs, C3+ 0.730 37.890 28.307 20.238 Uncontrolled Recovery Info.. Vapor 2.7600 HC Vapor 2.5500 GOR 460.00 Emission Composition 0.167 8.651 6.463 4.621 [MSCFD] (MSCFD] [SCF/bblI No Component Uncontrolled [ton/yr) 1 3179 0.000 2 02 0.000 3 CO2 4.295 4 N2 0.000 5 Cl 9.583 6 C2 8.068 7 C3 8.309 8 i -C4 3.152 9 n -C4 2.764 10 1-05 1.498 11 a-05 1.067 12 C6 1.371 13 C7 1.054 14 CO 0.228 15 C9 0.052 16 C10+ 0.015 17 Benzene 0.125 18 Toluene 0.161 19 8 -Benzene 0.006 20 Xylenes 0.041 21 n -C6 0.395 22 224Triaetbylp 0.000 Total 42.184 -- Stream Data No. Component Uncontrolled (lb/hr) 0.000 0.000 0.981 0.000 2.188 1.842 1.897 0.720 0.631 0.342 0.244 0.313 0.241 0.052 0.012 0.003 0.029 0.037 0.001 0.009 0.090 0.000 9.631 1 H2S 2 02 3 CO2 4 N2 5 C1 6 C2 7 C3 8 i -C4 9 n -C4 10 i-05 11 n-05 12 C6 13 C7 14 C8 15 C9 16 C10+ 17 Benzene 18 Toluene 19 E -Benzene 20 xylenes 21 n -C6 22 224Trimetbylp MW Stream Mole Ratio Heating Value Gas Gravity Bubble Pt. E 100F MW LP Oil mol % 34.80 0.0000 32.00 0.0000 44.01 2.4380 28.01 0.0000 16.04 14.9230 30.07 6.7040 44.10 4.8820 58.12 2.7130 58.12 2.6000 72.15 2.5780 72.15 2.4910 86.16 7.5670 100.20 16.4040 114.23 10.9350 128.28 7.2170 140.36 5.8610 78.11 1.0900 92.13 4.7000 106.17 0,4870 106.17 4.1180 86.18 2.7920 114.24 0.0000 78.52 1.0000 (BTU/SCF) (Gas/Air) [psia) 570.59 page 2 Flash 0i1 Sale Oil pmol % mol % 0.0000 0.0000 0.0000 0.0000 0.1352 0.0000 0.0000 0.0000 0.2681 0.0000 0.8091 0.0012 1.9431 0.2615 1.6686 1.2837 2.3352 2.1126 3.0550 3.0809 3.1149 3.1737 10.3570 10.7101 23.2232 24.1343 15.6426 16.2818 10.3530 10.7807 8.4151 8.7642 1.5155 1.5708 6.6967 6.9660 0.6978 0.7265 5.9029 6.1461 3.8670 4.0057 0.0000 0.0000 99.45 101.71 0.6962 0.6684 22.66 5.30 F1aeh Gan W4S Gas mol % raol % 0.0000 0.0000 7.7161 0.0000 48.5116 20.2151 11.6170 3.4607 3.2069 1.4847 1.0611 1.1723 0.7746 0.1452 0.0294 0.0071 0.1147 0.1237 0.0038 0.0271 0_3281 0.0000 30.56 0.3038 1593.13 1.05 0.0000 0.0000 3.3864 0.0000 6.7190 20.2445 42.4030 10.9306 7.6908 2.4329 1.6996 1.8629 1.3003 0.2623 0.0610 0.0155 0.1864 0.2159 0.0071 0.0515 0.5303 0.0000 45.24 0.0278 2487.14 1.56 Total Emissions mol % 0.0000 0.0000 7.3533 0.0000 45.0097 20.2176 14.1974 4.0866 3.5827 1.5641. 1.1146 1.2302 0.8187 0.1550 0.0321 0.0078 0.1207 0.1314 0.0040 0.0292 0.3451 0.0000 31.79 0.3316 1668.04 1.10 E&P TANK v2.0 Calculation Report Developed by DB Robinson F Aaa©ciatea Ltd. [vela] 142.35 12.12 5.03 RYP 100T 0.643 0.600 0.6B3 C. Grarity 0 1007 page 3 2005-07.15 PARACHUTE CREEK GAS PLANT LOAD -2 NGL PRODUCT LOADOUT VOC EMISSIONS Assumptions: Loading Rate: 950 bbl/day VOC Content 100 percent NGL Density: 5.5 lb/gal Turck Volume 7,500 gal/load Pumpng Rate: 160 gal/min 0.8 hour/load Loads/Day: 5.3 Loads/Yr 1942 Loading Time 1517 Liquid Hose Dimensions: Block Valve to Coupling: Liquid Hose Diameter: Calculated Volume: Calculated Volume: Mass Emission/Hose: Vapor Hose Dimensions: Block Valve to Coupling: Vapor Hose Diameter Calculated Volume: Calculated Density: Mass Emission/Hose: Total VOC Emission Per Load: Total VOC Emission Per Hour: Total VOC Emission Per Year: Total VOC Emission Per Year: hr./yr 1.17 2 0.03 0.19 1.05 0.67 1.25 0.01 0.49 0.00 feet inches ft3lhose gallon/hose lb/hose feet inches ft3lhose Iblft3 lb/hose 1.05 lb/load 1.05 lb/hr 1592.69 lb/yr 0.8 ton/yr Esimated HAP Emissions From Loadout 'Assumption: Each HAP present in Inlet Gas is Present in NGL Product at Concentration of 1 % by weight. HAP lb/yr ton/yr Benzene 15.93 0.01 Toluene 15.93 0.01 Xylenes 15.93 0.01 n -Hexane 15.93 0.01 7/1312005 EMISSIONS 0705 PLANT 1 AND 2 MOD i- PLANT 3.xls PARACHUTE CREED GAS PLANT LOAD -4 NGL PRODUCT LOADOUT VOC EMISSIONS Assumptions: Loading Rate: 1900 bb1/day VOC Content: 100 percent NGL Density: 5.5 lb/gal Turck Volum( 7,500 gallload Pumpng Rate: 160 gal/min 0.8 hour/load Loads/Day: 10.6 Loads/Yr 3884 Loading Time 3034 hr/yr Liquid Hose Dimensions: Block Valve to Coupling: Liquid Hose Diameter: Calculated Volume: Calculated Volume: Mass Emission/Hose: Vapor Hose Dimensions: Block Valve to Coupling: Vapor Hose Diameter: Calculated Volume: Calculated Density: Mass Emission/Hose: Total VOC Emission Per Load: Total VOC Emission Per Hour: Total VOC Emission Per Year: Total VOC Emission Per Year: 1.17 2 0.03 0.19 1.05 0.67 1.25 0.01 0.49 0.00 feet inches ft3/hose gallon/hose lb/hose feet inches ft3/hose lb/ft3 lb/hose 1.05 lb/load I.05 lb/hr 3185.38 lb/yr 1.6 ton/yr • Esimated HAP Emissions From Loadout Assumption: Each HAP present in Inlet Gas is Present in NGL Product at Concentration of 1 % by weight. HAP lb/yr ton/yr Benzene 31.85 0.02 Toluene 31.85 0.02 Xylenes 31.85 0.02 n -Hexane 31.85 0.02 7/1312005 EMISSIONS 0705 PLANT 1 AND 2 MOD + PLANT 3.x1. PARACHUTE CREEK GAS PLANT LOAD -6 NGL PRODUCT LOADOUT VOC EMISSIONS Assumptions: Loading Rate: 1900 bbUday VOC Content: 100 percent NGL Density: 5.5 lb/gal Turck Volum( 7,500 gal/load Pumpng Rate: 160 gal/min 0.8 hour/load Loads/Day: 10.6 Loads/Yr 3884 Loading Time 3034 Liquid Hose Dimensions: Block Valve to Coupling: Liquid Hose Diameter: Calculated Volume: Calculated Volume: Mass Emission/Hose: Vapor Hose Dimensions: Block Valve to Coupling: Vapor Hose Diameter: Calculated Volume: Calculated Density: Mass Emission/Hose: Total VOC Emission Per Load: Total VOC Emission Per Hour: Total VOC Emission Per Year: Total VOC Emission Per Year: hr/yr 1.17 2 0.03 0.19 1.05 0.67 1.25 0.01 0.49 0.00 feet inches ft3/hose gallon/hose lb/hose feet inches ft3/hose lb/ft3 lb/hose 1.05 lb/load 1.05 lb/hr 3185.38 lb/yr 1.6 ton/yr Esimated HAP Emissions From Loadout Assumption: Each 1 -IAP present in Inlet Gas is Present in NGL Product at Concentration of 1 % by weight. HAP lb/yr ton/yr Benzene 31.85 0.02 Toluene 31.85 0.02 Xylenes 31.85 0.02 n -Hexane 31.85 0.02 7/13120115 EMISSIONS 0705 PLANT 1 AND 2 MOD + PLANT 3.xls PARACHUTE CREEK GAS PLANT LOAD -I TK-1/TK-2 CONDENSATE LOADOUT VOC EMISSIONS USEPA Loadout Equation L= 12.46*S*P*MW/(T*(1-eff)) from AP -42 Section 4.4 Molecular Weight of Vapors, MW True Vapor Pressure. Pva @ T Temperature of Bulk Liquid Loaded, T Saturation Factor Efficiency of controlled loading (%) Annual throughput, v Loading losses, L @ tank L= 12.46 SPMW/T(1-eff) Annual losses @ tank, L*v Loading Frequency Truck Volume Loading Rate Loading Duration. Annual Hrs of Operation Hourly VOC During Loading 50.81 Ibllb-mol E&P TANK2.0 5 psia Estimated 80 F Estimated 540 R 0.6 Dedicated service 0.0% 46 1000 gallons 3.52 Ib/i000 gallons 161.76 l blyr 0.1 tpy 7 7500 75 100.0 11.67 13.86 trucks/yr gal/truck gal/min min/truck hrlyr Ibllsr (while loading) PARACHUTE CREEK GAS PLANT LOAD -3 TK-3/TK-4 CONDENSATE LOADOUT VOC EMISSIONS USEPA Loadout. Equation L= 12.46* S *P*MW/(T*(I-eff)) from AP -42 Section 4.4 Molecular Weight of Vapors, MW True Vapor Pressure, Pva @ T Temperature of Bulk Liquid Loaded, T Saturation Factor Efficiency of controlled loading (%) Annual throughput, v Loading losses, L @ tank. L= 12.46SPMW/T(1-eff) Annual losses @ tank, L*v Loading Frequency Truck Volume Loading Rate Loading Duration Annual Hrs of Operation Hourly VOC During Loading 50.81 5 80 540 0.6 0.0% 92 Ibflb-mol psia F R E&P TANK2.0 Estimated Estimated Dedicated service 1000 gallons 3.52 Ib11000 gallons 323.51 lb/yr 0.2 1py •13 7500 75 100.0 21.67 14.93 trucks/yr gal ruck gal/min min/truck hrlyr Iblhr (while loading) 7/13/2005 EMISSIONS 0705 PLANT 1 AND 2 MOD + PLANT 3.xls PARACHUTE CREEK GAS PLANT LOAD -5 TIC-5/IX-6 CONDENSATE LOADOUT VOC EMISSIONS USEPA Loadout Equation L=12.46•S•P•MW/(T•(1-eff)) from AP -42 Section 4.4 Molecular Weight of Vapors, MW True Vapor Pressure, Pva @ T Temperature of Bulk Liquid Loaded, T Saturation Factor Efficiency of controlled loading (%) Annual throughput, v Loading losses, L 0 tank L= 12.46SPMW/T(1-eff) Annual losses 0 tank, L* , Loading Frequency Truck Volume Loading Rate (Loading Duration Annual Hrs of Operation Hourly VOC During Loading 50.81 5 80 540 0.6 0.0% 92 Ibllb-mol psia F R E&P TANK2.0 Estimated Estimated Dedicated service 1000 gallons 3.52 lb/1000 gallons 323.51 Iblyr 0-2 tpy 13 7500 75 100.0 21.67 14.93 trucks/yr gal/truck gal/min min/truck hr/yr Ib/hr (while loading) 7/1312005 EMISSIONS 0705 £LANT 1 AND 2 MOD + PLANT 3_xls • PARACHUTE CREEK GAS PLANT 7113/7005 • JULY 2005 PLANT 3 MODIFICATION Parachute Creek Gas Plant FUG -I Fugitive VOC Detail Sheet Component Counts Based on Typical Process Unit Counts 8760 Hours Per Year Equipment Emission Source Percent Hours of Control Total HC Total HC Total VOC Type Factor` Count VOC Operation Factor Emission Emission Emission (Ib/hr/source) (Percent) Rate (Iblhr) Rate (toy) Rau (tPY) Valves-Gas/Vapor 0.009920 587 8.31% 8760 75.00% 1.46 6.4 0.5 Valves -Light Liquids 0.005510 238 100,00% 8760 75.00% 0.33 1.4 1.4 Relief Valves 0.019401 58 8.31% 8760 75.00% 0.28 1.2 0.1 Compressor Seals 0.019401 43 8.31% 8760 75.00% 0.21 0.9 0.1 Pump Seals -Light. Liquids 0,028660 19 100.00% 8760 75.00% 0.14 0.6 0.6 Flanges-Gas/Vapor 0.000860 513 8.31% 8760 75.00% 0.11 0.5 0.0 Flanges -Light Liquids 0,000243 224 100.00% 8760 75.00% 0.01 0.1 0.1 Connectors • Gas/Vapor 0.000440 1835 8.31% 8760 75.00% 0.20 0.9 0.1 Connectors - Light Liquids 0.000460 848 100,00% 8760 75.00% 0.10 0.4 0.4 Totals - - - 2.83 _ 12.4 _ 3,3 ' Oil and Gas Production Operations squiprncnt leak emission factors (from OAQPS 11'N BBS). EPA453/R•95.017, Tabk 24 _ Valves Valves Relief Compressor Pump Flanges Flanges Connectors Connectors Process Unit _ Gas/Vapor Liquid Valves - Seals Seals Gas/Vapor Liquid Gas/Vapor Liquid Compressor Skid (9) 360 45 18 36 0 270 18 1080 152 Separator (1) 6 4 2 0 0 8 2 120 30 Storage Tank (5) 20 30 10 0 10 25 50 75 150 Dehydration Unit (1) 75 20 4 0 4 20 50 50 150 lAmine Unit (1) 15 60 4 0 4 20 50 50 150 Refrigeration Skid (I) 40 35 6 6 0 50 20 120 80 Demethanizcr (1) 40 35 6 0 0 50 20 120 80 CO2 Separation Skid (1) 15 5 4 1 1 40 10 100 40 Flare (2)' 16 4 4 0 0 30 4 120 16 Total Component Counts 587 238 58 43 19 513 224 1835 848 - 'Includes DEHY-1 Dedicated Flare Hazardous Alr Pollutant F ugittve Emission Cemoonen) YLL !viz mom Benzene 0.05% 11.64 0.01 Toluene 0.08% 19.97 0.01 Ethylbenzene 0.00% 0.00 0.00 Xylenes 0.02% 5.74 0.00 n -Hexane 0.20% 48.87 0.02 EMISSIONS 0705 PLANT 1 AND 2 MOD +PLANT 3.xli • PARACHUTE CREEK GAS PLANT 7/13/2005 • JULY 2005 PLANT 3 MODIFICATION EMISSIONS 0705 PLANT 1 0402 MOD r PLANT 3.x►s Parachute Creek Gas Plant FUG -2 Fugitive VOC Detail Sheet Component Counts Based on Typical Process Unit Counts 8760 Hours Per Year - - - Equipment Emission Source Percent Hours of Control Total HC Total HC Total VOC Type Factor' Count VOC Operation Factor Emission Emission Emission (lbihr/source) (Percent) Rate (lb/hr) Rate (tpy) Rate (tpy) Valves-Gas/Vapor 0.009920 447 8.31% 8760 75.00% 1.11 4.9 0,4 Valves -Light Liquids 0.005310 228 100.00% 8760 75.00% 0.31 1.4 1.4 Relief Valves 0.019401 48 8.31% 8760 75.00% 0.23 1.0 0.1 Compressor Seals 0.019401 22 8.31% 8760 75.00% 0.11 0.5 0.0 Pump Seals -Light Liquids 0.028660 22 100.00% 8760 75.00% 0.16 0.7 0.7 Flanges-Gas/Vapor 0.000860 343 8.31% 8760 75.00% 0.07 0.3 0.0 Flanges -Light Liquids 0.000243 254 100.00% 8760 75.00% 0.02 0.1 0.1 Connectors - Gas/Vapor 0.000440 1 185 8.31% 8760 75.00% 0.13 0.6 0.0 Connectors - Light Liquids 0.000460 838 100.00% 8760 75.00% 0.10 0.4 0.4 Totals - 2.24 9.8 _ 3.2 * Oil and Gas Production Operations equipment kak emission factors (from OAQPS TTN BBS). EPA -453/R -95-0i7, Tabk 2-4 Valves Valves Relief Compressor Pump Flanges Flanges Connectors Connectors Process Unit Gas/Vapor Liquid Valves Seals Seals Gas/Vapor Liquid Gas/Vapor Liquid Compressor Skid (4) 160 20 8 16 0 120 8 480 32 Separator (1) 6 4 2 0 0 8 2 120 30 Storage Tank (5) 20 30 10 0 10 25 50 75 150 Dehydration Unit (2) 150 40 8 0 8 40 100 100 300 Amine Unit (1) 15 60 4 0 4 20 50 50 150 Refrigeration Skid (1) 40 35 6 6 0 50 20 120 80 Demethanizer (1) 40 35 6 0 0 50 20 120 80 Flare (2)• 16 4 4 0 0 30 4 120 16 Total Component Counts _ _ 447 228 48 - 22 22 343 254 1185 838 ' includes Thermal Oxidizer TO -1 Hazardous Alr Pollutant Fugitive Emissions Comoonent Ea 1 toyer Benzene 0.05% 9.19 0.00 Toluene 0.08% 15.76 0.01 Ethylbenzene 0.00% 0.00 0.00 Xylenes 0.02% 4.53 0.00 n -Hexane 0.20% 38.57 0.02. EMISSIONS 0705 PLANT 1 0402 MOD r PLANT 3.x►s • PARACHUTE CREEK GAS PLANT 7/14a005 • JULY 2005 PLANT 3 MODIFICATION EMISSIONS 0705 PLANT I AND 2 MOD + PLANT 3.41 Parachute Creek Geis Plant FUG -3 Fugitive VOC Detail Sheet Component Counts Based on Typical Process Unit Counts 8760 Hours Per Year Equipment Emission Source Percent Hours of Control Total HC Total HC Total VOC Type Factors Count VOC Operation Factor Emission Emission Emission (Ib/hr/source) (Percent) Rate (lblhr) Rate (tpy) Rate (tpy) Valves-GasNapor 0.009920 532 8.31% 8760 75.00% 1.32 5.8 0.5 Valves -Light Liquids 0.005510 228 100.00% 8760 75.00% 0.31 1.4 1.4 Relief Valves 0.019401 52 8.31% 8760 75.00% 0.25 1.1 0.1 Compressor Seals 0.019401 38 8.31% 8760 75.00% 0.18 0.8 0,1 Pump Seals -Light Liquids 0.028660 18 100.00% 8760 75.00% 0.13 0.6 0.6 Flanges-CGasNapor 0.000860 443 8.31% 8760 75.00% 0.10 0.4 0.0 Flanges -Light Liquids 0.000243 212 100.00% 8760 75.00% 0.01 0.1 0.1 Connectors - Gas/Vapor 0.000440 1615 8.31% 8760 75.00% 0.18 0.8 0.1 Connectors - Light Liquids 0.0004-60 720 100.00% 8760 75.00% 0.08 0.4 0.4 Totals - - - - 2.57 11.2 3.1 • Oil and Gas Produc;ion Operations equiprreni leak emission factors (tom OAQPS TTN BBS). EPA-4S]IR-95-067. Table 2-4 Valves Valves Relief Compressor Pump Flanges Flanges Connectors Connectors Process Unit _ Gas/Vapor Liquid Valves Seals Seals Gas/Vapor Liquid Gas/Vapor Liquid Compressor Skid (8) 320 40 16 32 0 240 16 960 64 Separator (1) 6 4 2 0 0 8 2 120 30 Storage Tank (5) 20 30 10 0 10 25 50 75 150 Dehydration Unit (1) 75 20 4 0 4 20 50 50 150 Amine Unit (1) 15 60 4 0 4 20 50 50 150 Refrigeration Skid (1) 40 35 6 6 0 50 20 120 80 Demethhanizer (1) 40 35 6 0 0 50 20 120 80 Flare (2)' 16 4 4 0 0 30 4 120 16 To Component Counts 532 228 52 38 18 443 212 1615 720 ' Includes Thermal Oxidizer TO -2 Hazardous Air Pollutant Fugitive Emissions Como©nenl 1.2/11 lblvr 19.0ia Benzene 0.05% ' 10.55 0.01 Toluene 0.08% 18.10 0.01 Ethylbenzene 0.00% 0.00 0.00 Xylenes 0.02% 5.21 0.00 n -Hexane 0.20% 44.29 0.02 EMISSIONS 0705 PLANT I AND 2 MOD + PLANT 3.41 ATTACHMENT 4 ISCST3 Air Dispersion Modeling Analysis ISCST3 Air Dispersion Modeling Analysis Williams Energy Services — Parachute Creek Gas Plant III Modification Williams is applying for a construction permit modification at the Parachute Creek Gas Plant (PCGP), located about 3.5 miles northwest of the town of Parachute in the Grand Valley of western Colorado. This permit modification involves the installation of a third gas plant (Plant 3) at Parachute Creek. In particular, Williams' proposes the addition of eight 3210 hp Caterpillar 3612 LE -TA 130 engines (ENG -17, ENG -18, ENG -19, ENG - 20, ENG -21, ENG -22, ENG -23 and ENG -24), each to be equipped with an oxidation catalyst and AFR, one 60 MMBTU/hr hot oil heater (HTR -3), one amine treater (AMINE -3) with emissions controlled by a thermal oxidizer (TO -2), a TEG dehy with condenser (DENY -4) and still vent controls, as well as an additional upset flare (FLARE - 3). As part of this application, Williams seeks to demonstrate compliance with both the Colorado Ambient Air Quality Standards (CAAQS) and the National Ambient Air Quality Standards (NAAQS) for both NO2 and CO at the PCGP. The analysis herein documents the dispersion modeling of all existing PCGP sources, proposed new sources, and all relevant background sources for the criteria pollutants NO2 and CO. MODELING OVERVIEW The general modeling approach will be to conduct an NO2 and CO analysis using ISCST3. First, a significant impact analysis (SIA) will be performed to account for emissions from all existing PCGP engines at Plant 1 and Plant 2 as well as all of the proposed new engines, heater and thermal oxidizer at Plant 3 that will be authorized under this permit modification. Figure 1 indicates that the PCGP annual NO2 impacts are significant. Thus, a cumulative impact analysis of NO* emissions from the PCGP, all surrounding background sources, and an ambient background is required to verify compliance with the annual NAAQS. CO facility only impacts were modeled and are not significant. As a result, NAAQS modeling will not be performed for the 1 -hr and 8 -hr NAAQS for CO. The relevant NAAQS and significance thresholds are listed below: • NO2 o Annual averaging period • 1 pg/m3 significance level ▪ 100 p g/m3 NAAQS/CAAQS * CO o 1 -hr averaging period • 2000 pg/m3 significance level • 40,000 pg/m3 NAAQS/CAAQS o 8 -hour averagingperiod • 500 pg/m3 significance level • 10,000 p film NAAQS/CAAQS Ambient NO2 and CO impacts from the Parachute Creek Gas Plant modification were modeled in accordance with Colorado Modeling Guidelines and EPA's Guideline on Air Quality Models. In particular, correction of modeled concentrations to standard atmospheric conditions before comparison to the NAAQS is not required in Colorado. • • Table 1: Parachute Creek Gas Plant - Modeled Stack Parameters Plant I11 Modification Emission Unit Descri .tion UTMX (m) UTMY (m) Emission Rate (: s) Ht.(m) D(m) Vs (m/s) T (K) NOx CO tLi 1 Ai ,. I1 L y� ♦ -:r .- �, sr 1 � rye. me d xa_s s s : Y Lia -. a+�i� :. rR .1M. , kr{ , �} �. rm w: ...y r i:}m• r } h .yr t •.3. �3 •, 3. • - un ; ENG -01 700 h k A ax DPC 2804LE 748664 4374687 0.292 0.253 7.01 0.46 17.5 523.1 ENG -02 700 h . A ax DPC 2804LE 748670.5 4374683 _ 0.292 0.253 7.01 0.46 ® 523.1 ENG -03 700 hi A ax DPC 2804LE 748677 4374679 0.292 0.253 7.01 0.46 17.5 523.1 ENG -04 336 h. A ax DPC 2802LE 748646 4374700 0.187 0.187 7.01 036 13.78 497 ENG -05 336 h. A ax APC 2802LE 748651.5 4374696 0.187 0.187 7.01 0.36 13.78 497 ENG -06 336 h. A ax DPC 2802LE 748657 4374692 0.187 0.187 7.01 0.36 13.78 497 GEN -1 1145 h • Cater. illar 3516TALE 748559 4374740 0.278 0.318 3.73 0.3 49,7 730.4 GEN -2 1145 hp Cater.11lar 35I6TALE 748563 4374744 0.278 0.318 3.73 0.3 49.7 730.4 ENG -09 700 h i A ax DPC 2804LE 748655 4374658 0.292 0.136 7.01 0.46 17.5 523.1 ENG -10 700 h. A ax DPC 2804LE 748661 4374655 0.292 0.136 7.01 0.46 17.5 ENG -11 1145 h Cater•illar 3516TALE wISCO 748649 4374662 0.477 0.041 7.01 03 49.7 730.4 HTR -1 27 MMBtufhr Hot 011 Heater 748597 4374729 0.328 0.275 6.1 0.91 6.04 533.1 FLARE -1 Exlstln: PracessfU.set Flare 748619 =MI 0.018 0.098 22.8 0.91 0.03 699.8 ;InnT 1 ill i men k>^: z . :. ,s;. r.., .: � , ��.• } S7�cr � •cs gala-L.Ja-41fs �[c'^ _1: n Lj Jam_ .k'r ENG -13 3210h. CAT 3612 LE TA -130 w/SCO 748717 4374759 0.624 0.161 8.53 0.46 67.3 732 ENG -14 3210h. CAT 3612 LE TA -130 w/SCO 748727 4374753 0.624 0.161 8.53 0.46 67,3 732 ENG -15 3210h. CAT 3612 LE TA -130 wISCO 748737 4374747 0.624 0.161 8.53 0.46 67.3 732 ENG -16 3210h• CAT 3612 LE TA -130 wISCO 748702 0.624 0.161 8.53 0.46 67.3 732 HTR -2 54 MMBtulhr Hot Oil Heater 748662 4374809 0.653 0.549 6.1 0.91 12.1 TO -1 Thermal Oxidizer (AMINE-I/AMINE-2) 748670 4374790 0.227 0.190 22.8 0.76 12 1144 FLARE -2 Plant 2 ProcessfU.set Flare 748630 4374524 0.035 0.19 -.k 22.8 0.91 0.03 699.8 �7F'r�1�t�jr' 3J']544^Y,1i:9a�sru�6aL:. T,..ki -i5x�c r3r s�.v.6.eu:J Ale-�ri r 1W`..,. Yin �..: n r ia x ENG-17 3210h. CAT 3612 LE TA -130 w/SCO 748446 0.624 0,161 8.53 0.46 67.3 732 ENG -18 3210h. CAT 3612 LE TA -130 w/SCO 748440 4374834 0.624 0.161 8.53 0.46 67.3 732 ENG -19 3210h. CAT 3612 LE TA -130 w/SCO 748434 4374846 0.624 0.161 MIZM 0.46 67.3 732 ENG -20 3210h. CAT 3612 LE TA -130 w/SCO 748428 4374858 0.624 0.161 MEM 0.46 67.3 732 ENG -21 3210h. CAT 3612 LE TA -130 w/SCO 4374870 0.624 0.161 8.53 0.46 67.3 732 ENG -22 3210h. CAT 3612 LE TA -130 w!SCO 748416 4374880 0.624 0.161 NNW 0.46 67.3 732 ENG -23 3210h. CAT 3612 LE TA -130 wISCO 748410 4374890 0.624 0.161 8.53 0.46 67,3 732 ENG -24 3210h • CAT 3612 LE TA -130 wISCO 748404 4374900 0.624 0,161 8.53 0.46 67.3 732 HTR -3 60 MMBte/hr Hot. Oil Heater 748490 4374861 0.727 0.611 6.1 0.91 111130= 533.1 TO -2 Thermal Oxidizer for AMINE -3 748500 4374840 0.340 0.286 22.8 0.91 12.5 1144 FLARE -3 Plant 3 Process/U. set Flare 748474 4374932 0.035 0.19 22.8 0.91 0.03 699.8 • TO -1 is the emission point for AMINE -1 and AMINE -2 • All modeling procedures and project specific details were addressed in a modeling protocol reviewed and approved by the CDPHE Air Pollution Control Division in March 2005 for a similar project. The modeling analysis herein will follow the same protocol. However, the revised emission estimates and equipment associated with Plant 3 have been incorporated into this modeling analysis. SOURCES The existing and proposed sources included in this modeling analysis for the Parachute Creek Gas Plant are listed in the attached Table 1. Emission rates and stack parameters were provided by the facility and are also indicated in the appropriate forms attached as part of this permit modification. USGS digitized terrain data were used to develop source base elevations. The USGS data from the Parachute 7.5' quad were downloaded in Digital Elevation Model (DEM) format and PCGP source elevations determined from this file by using the AERMAP terrain processor. Source base elevations for all applicable background sources were not provided in the background inventory provided by the APCD. Instead, USGS digitized terrain data from Grand Junction -East and Leadville-West 1* DEMs were downloaded. from www.webgis.com and source base elevations for the background sources were determined using AERMAP. All source locations and elevations were determined using the NAD27 coordinate system and associated NAD27 DEMs for consistency. All background sources were provided by APCD in NAD 27 format. There were some missing stack parameters in the background source data. A conservative estimate based on similar units at that particular facility or within the background inventory was used to fill the holes in the missing data required for modeling the sources. For missing Williams' background source data, Williams provided the true stack parameters from recent field data that were then incorporated into the model. In addition, stack parameters and emission rates for the nearby American Soda facility were provided separately from the inventory by Doris Jung of the APCD. In addition to the background source inventory, an ambient background concentration from distant sources is also added to the modeled results. Nancy Chick of the APCD provided background source concentrations for NO2 and CO. The annual background NO2 concentration of 0.004 ppm (7.5 pglm3) comes from monitoring data near Durango. RECEPTORS Fence line receptors were selected at 50 -meter intervals along the property boundary of the new Plant 3 location as well as the existing plant boundary while nested grid receptors were used beyond the fence line. A cartesian grid with 100 -meter spacing was used out to 1 krn beyond the fence line and another with 250 -meter spacing was used to capture receptors from 1 km out to 3 km. Finally, an outer Cartesian grid with 500 -meter spacing was used out to a distance of 10 km from the facility fence line in all directions. Some additional 500 -meter spaced receptors were added along the eastern side of the outermost grid in order to capture the entire significant impact area. As a result, the final modeling grid extends east of the facility by about 13 km. • • • Receptor elevations were also determined using 7.5' DEMs in NAD27 format obtained from the WebGis website. The terrain data was processed using AERMAP such that an interpolated elevation from DEM points surrounding each receptor was assigned to that receptor.. METEOROLOGICAL DATA The one-year met data set collected in 1989 at the Unocal site was used for modeling, per email correspondence with Chuck Machovek of the APCD. It is a complete and model - ready data set representative of meteorological conditions in similar terrain of like elevation surrounding the Parachute Creek Gas Plant. Given the terrain surrounding the PCGP, the facility is subject to a well defined, bi-modal wind pattern unique to the Grand Valley. The Unocal facility was located in the same valley in close proximity to the PCGP and is clearly the most representative met data available for this region. BUILDING DOWN WASH The existing engine stack heights and proposed installation heights on the new engines associated with Plant 3 as well as the engines at. Plant 2 are all listed at 28 feet. All tanks are located at least five diameters away from any stack at the facility and each stack is approximately three feet above its associated compressor building. The proposed compressor building at Plant 3 will be 24' and may promote downwash of stack effluent. Both of the existing and proposed hot oil heater stacks are listed at 20 feet in height and surrounding buildings may cause downwash of effluent from these units as well. Thus, a BPIP analysis was performed for the PCGP and building downwash included in the final modeling analysis herein. MODELING RESULTS The PCGP sources in Table 1 were modeled to determine compliance with the following standards: Annual NO2 NAAQS and CAAQS NO2 annual modeling results are presented in Table 2. A 75% ozone correction was applied to all annual NOx modeling results in accordance with EPA's Ambient Ratio Method (ARM) and as discussed in the Colorado Modeling Guidelines, as a way to estimate ambient NO2 concentrations from modeled NOx emission rates. These results include impacts from all appropriate background sources and ambient background concentrations as provided by the APCD. Figure 2 depicts the modeled annual NO2 ambient air concentrations resulting from emissions from the PCGP and surrounding sources. The modeled maximum NO2 concentration of 87.3 pg/m3 occurs in slightly rising terrain just east-southeast of the PCGP and is in compliance with the annual NO2 NAAQS of 100 }tglm3. 11 Table 2: Parachute Creek Gas Plant and Background Source Ambient Impacts Pollutant Avg, Period Location Maximum Ambient Concentrations Modeled ug/m3 Calc. ug/m3 Bkgrnd ug/m3 Total ug/m3 Std. ug/m3 UTMX UTMY NO2 Annual 749404 4374502 , 106.4 79.8 7.5 87.3 100.0 Electronic copies of all ISCST3 modeling files and downwash analyses will be emailed to Chuck Machovek of the Colorado Air Pollution Control Division. r • • • August 9, 2005 Mr. Ram Seetharam Colorado Department of Public Health & Environment Air Pollution Control Division Construction Permit Section, APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Re: Modification to Permit No: 020A0014, Modification -7 Revised NCRP APEN Reporting Parachute Creek Gas Plant, Garfield County, Colorado Facility ID: 045/0365/999 Dear Ram: W• hams. EXPLORATION & PRODUCTION Tower 3. Suite 1000 1515 Arapahoe Street Denver. CO 80202 3031572-3900 3031629-8282 fax In response to your recent request, Williams Production RMT Company (Williams) has revised the attached APENs to account for Non -Criteria Reportable pollutants on the appropriate source unit APENs for the two amine units and three dehydration units. We have now listed both uncontrolled and controlled HAP emissions for these sources, when uncontrolled HAP emissions exceed the Scenario A bin reporting threshold limits. We have also revised the APENs for the two process and ernergency flares, removing the NCRP emissions associated with the amine sweetening and dehydration units that were previously reported on the NCRP HAP Addenda of the flare APENs. The revised completed APENs for these sources are attached. A revised Facility -Wide emission inventory spreadsheet also is attached. Please replace the APENs originally submitted with the revised APENs provided herein. If you need further information or have any technical questions regarding this submittal, please call me at (303) 606-4386. Sincerely, Williams Production RMT Company Gerard G. Alberts Principal Environmental Specialist attachment • 0 0 AUGUST 2005 PLANT 1 AND • 9, 6 I. pQ' Y l- ei' 9999999499 $ 0 0 0 0 0 0 0 0 0 m eq OD M re Y 4 0 0 0 0¢ 0 0 0 0 00 000 0 C70 C? 0 0 b 'O re .7 14 N /y Y K Y re N re r6. 000000000 66600006.0 +.1 eZ0 60 N N 0 0C! ry 0.0 N n N "11. C C C ,j s e �c s Lq Y B2G>: - -5 4 0. n N M VL n h Vi Vj N NI N Ci N 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 nib 71et ra33• ) A A 1- nA on I0 rrs gg0'o.o'qGv- N N N 0 0 Ci 0 m m m M..1 r+ 0 0 6 O 0 000000 C? C. CT 0 0 0 eV rV eV eb b le xri In r ee /+ N 0 006006660 11 rr rr N N n 'P. 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C X Z ( E Z I a. o E X rr r oQo —. a Z < ( Z Z C t Z Z t t Z X ( ( Z Z t d. Z Z ( E Z Z Equipment Feld Emission Link ID No. Service Description 1i1 4 ENG.01 Residue Recompreu. Ajax DPC 2104 LE ENG -02 Residue Recompress, Ajax DPC 2804 LE ENO 433 Residue Rreampress. Ajax DPC 2804 LE ENG -04 Propane Rang. Aju DPC 2802 LE ENG.05 Prepare Refng, Ajax DPC 2802 LE ENG -06 Propane Refng, Ajax DPC 2802 LE ENO -09 Residue Rccompdeu. Ajax DPC 2804 LE w SCO Cal ENO - 10 Residue Recompreas. Ajax DPC 28114 LE w SCO Can ENG• 1 I Residue Recompress. Caterpillar 3516 TALE w SCO Pkril2 Engines ENG. 13 Residue Rot impress. Cw42716,001148 TA -130 . SCrr ENG.14 Residue Recomposes. comaw All LETA•13a. 5Cn ENO.15 Residue Recompress. cstavuirsolaLBTA. iw.sco ENG. 16 Residue laecomprcu. Cwarmur 3011 Le TA -110 wSC6 Oi . GYq W 4. r2 : M S u) r+ \ .._ U a � 4 S O o u C EL y X — re � S 0 G y a w lin un11 Ainlne Sweetening 11rdi 1 AMINE -1 Arnim Sweetening Plan) 1 Anne Sweetening Unit Plants Amine Sweetening demi IAMINE-2 Amine Sweetening Plant 2 Amine Sweetening Unit I Planet Dehydration Una t� E: a o' ^ - Y D erIll C 9 M 4 DENY -2 Gu Dehydration Plan 2 EG Dehydration Unit DENY -3 Gu Dehydration Plant 2 TEG Dehydration Unit t i r 1L •� Q. _ q Ii ro C!1 {� [s. 4. [FLARE•2 Process Flare Plant 2 Process & Upset Fere 1 .1 O -.84i Z a 4. 4. h L .0 F" r' 3 1 e 14 L I'TR.I/TK-2 Condensale Stange Plant 1 Cond. Tanks ¢ i= n 4 jTK-PTK 4 Caridensele Storage Pian 2 Cond Tanks 7 @ap J r 4 LOAD.1 Condensate Loadout Exempt Kant 1 Cored. Loadout LOAD -2 NGL Produce Loadoul NGL Produce Laadoui 6n +} 0- LOAD -3 Condensate Loadout Exempt Pians 2 Cond. Loadout LOAD -4 NGL Produtr Loadout NGL Product Loadout (Maar 1 Fugitives I } - a. - - yy . r q r1 (TJ _ ',w re y�y . 0 121 N tt t Fuel Gas Heating Value • 1040 8fulsef Serial Maximum Horsepower Heat Heat Fuel Fuel Volumetric Exhaust Exhaust Stack Stack Exhaust Number Operating SKr/Rating Input Rate Use Use Flow Velocity Velocity Diameter Height Temp. HourstVr Hp MMltukr ltu/Hp-hr scfihr MMicfryr ecfm Wen in fMet feet teat deg. F. 1 54716 8760 700 5.46 7800 3230 45.99 6100 3452 57.5 1.50 23.00 482 84702 8760 700 5.46 7800 5250 45.99 6103 3452 57.5 1.50 23.00 482 84685 8760 700 5.46 7800 3250 43.99 6100 3452 57.3 1.50 23.00 482 84758 8760 336 2.62 7800 2520 22.08 2896 2709 45.2 1.17 23.00 435 84787 8760 336 2.62 7800 2320 22.08 2896 2709 45.2 1.17 23.00 435 54781 8760 336 2.62 7800 2520 22.08 2896 2709 43.2 1.17 23.00 435 84946 8760 700 5.46 7100 5250 45.99 6100 3432 57.3 1.50 23.00 482 54934 8760 700 5.46 7800 3250 45.99 6100 3452 57.5 1.50 23.00 482 Unknown 8760 1145 9.16 8000 8808 77.16 7685 9755 163.1 1.00 23.00 855 a,04m04 8888 ai 00 00 m N N N N 2r+7 q 2 N N N H r- ,C ,D r- N N M n r+, r4M rnn r� N h1 ra N CO OF 04 09 (( m" --m,m NNnN +o,o roe 0 0 0 0.no r r r r RI e, e, es o cs7c> 222$ rrrr 00r' W 0 10. D n : ryCc - 8 2 m+ w f' - - - Ic.- r 1 �,. S cm _, m ,., r N Z ^�' ( m NA 8760 NA 54.0 NA 51923 45-4.85 16823 2310 _ 39.7 3.0 20.00 500 I NA 8760 NA NA NA NA NA Emission Points are FLARE -1 and TO -1 NA 8760 NA NA NA NA NA Emission Point are FLARE -2 and TO.1 T-959 8760 NA. NA NA NA NA Errusaion Paint is FLARE -I M N mw i1j(j1- ! ! d 1 C . O C 2, 2 2 2 1 2 (( ZZ 2 $2 00 w Z Z _ 8 g $ �r Z •[ ` 2 v r, ry 2 ^o 2 2 W r `Unknown 5760 NA 0.3 NA 245 2.15 NA NA NA 3.00 75.00 5O0 I 8 n r 2 .<C Z 2 Z 14.4 m �. r - 2 c — ( $ rm / � E r - 43 Z Z 2 z r 2 2 2 C 2 C r- m 2 v < .., " C3 Z. ( Z t Z t Z 2 2 < 2 Z 3 rn 2 NA 12 NA NA NA NA NA NA NA NA NA NA NA NA 1517 NA NA NA NA NA NA NA NA NA NA NA I (< Z Z << Z Z Z Z C C Z Z '2 2 Z Z <( 22 Z Z 2 2 r Q 22 2 2( rvC4 Z Z ( Z. < Z Z C 2 2 2 C 2 2 2 < 2 C t m 2 < Z '2 2 < 2 C Z ( 2 Z 2 <. 2 2 t' ro Z c s E Q W= =art g 4 fir < e cr 1.1 V t I,J K 4 4 ENG -01 Residue Recompress. Ajax DPC 2804 LE ENG -02 Residue Recompress. Ajax DPC 2804 LE ENG -03 Residue Reeampreu. Ajax DPC 2804 LE ENG -04 Propane Rerrig. Ajax DPC 2802 LE ENO -05 Propane Refrig. Ajax DPC 2802 LE ENO.06 Propane Rettig. Ajax DPC 2902 LE ENG -09 Residue Recomposes. Aja DPC 2861 LE w SCO Cat ENG.10 Residue R compress. Ajax DPC 2P434 LE w SCO Cyt ENG. I I Residue ReCOm. rein, Csiamatar 1116 TALE w SCO .. 0 W '2 5 4 ENG - 13 Residuc Ree ompreu. Caterpillar 3312 LE TA -130 w SCO ENO.14 Residue Reecmpreuu. Cattrptlie' 36121.3 TA.l30 w SCO ENG -15 Residue Rut)mprels. Cato -pats/ 3312 LE TA -130 w SC ENG - 16 Reiidue Recompress. Caneniou }ht 2 LE TA -130 w SCO 2 4 n Y W C s 4 IGEN-1.2 Electrical Generators Cuerptuar 331hTALE 1 Y C C 4F4 4 z w .a 0. p�• S_4_ 2i Y 2 i !VTR./ NOM! Hearer Hot Oil Heater S35 : . in < 4 sss 4 D to 'E c 3 (� E — E m 2 y a Q — '- (,4._ : - A t ( S AMINE•2 Amine Sweetening Plant 2 Amine Sweetening Unit Plans $ Dehydration Unit - GC D © 4 '` a a 73V.7. O .i o 0 n Z .0 - G 2` 0,,4ww!vs 0_4 c qq O O tl.. c t" m ri N 5 a. a . r v 8 a a t 0 L7 r ,, 2 Y 0 Ciii4. N M y D' �!. 0 d , — 5' Zr- x R y t 4 -- C C ,,__,ii 0. 4 4 a 4. y D 4 x : r .1 a yy g 3 r .{ it t `a $' . r', 4 b C- aha 4 i _4 ry FG E 7 n s yy y V �+ W c— H 4 Y : 5 E. 0 vn w c 5c F At 1¢ `c 4 ITK-3rrK-4 Condensate Storage Plant 2 Cond Tanks S d . s i 4 (LOAD -1 Condensate Loadout Exempt Platt 1 Cond. Laadout LOAD -2 NGL Produce Loadaut Exempt Plant 1 NGL Loadow i 0 e33 1 r a 4 LOAD.3 Condensate Laadout Exempt Plant 2 Cond. Loadoui LOAD -4 NGL Product Loadout Exempt Plant 2 NGL L.osdaul. y m [q. c 3 4 3 a.N rri a '. g fin, 0 W C d 'M4 it 8 0 a. d' i y n, • • NON -CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM* (Instructions on re►crse side) Company Name: Plant Location: Person to Contact: E -Mail Address: Permit Number 02GA0014 — FLARE -2 Williams Production RMT Company AIRS Number 045/0365/029 Near Parachute, Colorado Gerard G. Alberts lerrv.alberts@wijliams.00m County Garfield Phone 303 572-3900 Zip Code 81635 Fax 303 629-8275 Chemical Abstract Service Number Chemical Name Reporting Bin Control Equiprnem/ Efficiency Emission Factor (include units) Emission Factor Source Requested Emissions (Ibslyr) Actual Emissions from the Data Year (tbslyr) Uncontrolled Emissions of All HAPs Are Below De Minimis Threshold y , - Use this fo nr reporting Hazardou r •oIl ants, C pleting Compounds, and other Non•Criteria Reportable Pollutant Signature a R:sponsible 0 icia a a ve dor o consultant) Gerard G. Albert ar For Which Thkikettrat-Data Applies: --S 0 Name of a Responsible Official (please print) Date Principal Environmental Specialist Title AIR. POLLUTANT EMISSION NOTICE FIRM NAME Williams Production RMT Corny PERMIT No,: 02GA0014 AIRS ID„445/0365/Q29 MAIL ADDRESS 1515 Arapahoe St.. Tower 3, Suite 1000 STATE:. CO. - ZIP: PLANT NAME & LOCATION_ PARACHUTE CREEK GAS PLANT N yi of NE rA Sermon 33. T6S. g9¢W COUNTY: GARFIELD REQUEST PORTABLE SOURCE PERMIT HOME -BASE FOR PORTABLE SOURCE PERSON TO CONTACT REGARDING mis INFORMATION Mr, Gerard G. Alberts 80202 TITLE Principal Environmental Specialist PHONE i�3_)-572-390Q GENERAL DESCRIPTION OF THIS PLANTS FUNCTION Natural Gas Processing E-MAIL ADDRESS: ferry, alberts@wi 11 iarns . corn A. GENERAL INFORMATION Normal Operation of Thts 5.,,ur4e Process Seasonal Throughput (% of Annual) ADDITIONAL INFORMATION OR REMIARKS. Hours/Day 24 Days/ eek 7 Weeks/Year 52 Dec -Feb 25 Mar -May 25 Jun -Aug 25 Sep -Nov 25 B. STACK OK VENT INFORMATION (Identify below which stack if plant has two or more; refer to attached sketch of plant layout) _ Height 75.0 ft Diameter 3.0 ft Temperature 800 °F Flow Rate Velocity ft/min Moisture Plant ID No. for Stack FLARE -2 C. FUEL INFORMATION Destgn Input Rate Annual Fuel Consumption Fuel Heating Value:' Percent by Weight Seasonal Fuel Use (% of Annual Use) Space F (% Anr Description of Combustion Unit (10” BTU(hr) Kind of Fuel Burned Requested level Actual level (Data year level) (BTUfIb, BTU/gal, or BTU/scf) Sulfur ( Ash Dec -Feb Mar -May Jun -Aug Sep -Nov New Skid Process and Emergency Flare 165.0 Nat Gas & Prones fins Approx. 1.100 1 Make/Model: Plant 2 Process & Emergency Flare Serial No, 1319SUFAS D. PROCESS INFORMATION Raw Matenals Used Raw Materials-Annua Consumption ; Design Process Rate Finished Product Finished Product -Annus Output Description of Processing Unit Description Requested level Actual level (Data year level) (Specify Units/Hour) Description Requested level Actual level (Data year leve _ — " MakefModel: - Sena] No.: E POLLUTION CONTROL EQUIPMENT Overall ESTIMATED EMISSIONS ACTUAL ESTIMATION CHECK New or previously unreported U Requesting modification r Change in emissions, Transfer of ownership previous owner Previous APEN is expiring Request for Emission (Specify) ALL BOXES THAT APPLY Sources of existing permit throughputs or equipment in REMARKS section I Reduction Credit t t t t t of box A.) t Pollutant Type of Control Equipment Collection Efficiency (TONS/YEAR) AT THROUGHPUTS REQUESTED ABOVE EM 155 IONS (from data year) METHOD Primary Secondary CONTROLLED UNCONTROLLED Particulate NA NA. Pot q NA NA.(List _ SO, _ NA NA. _ NO. _ NA 1.9 AP -42 ' Complete all applicable portions of APEN t Complete ' Requested Level' values for permit limits $ Complete all information above box A, and those remaining portions which reflect changes - VOC NA 0.2 AM1lVECaiclfSLyC�k CO NA 10.5 AP -42 PLEASE USE APCD NON -CRITERIA REPORTABLE AIR POLLUTANT ADDENDUM DORM TO REPORT SUCH POLLUTANTS OR POLLUTANTS NOT LISTED ABOVE:_ CHECK HEYOU WISH THE DIVISION TO CALCULATE YOUR EMISSIO E ', IIi�+ 11` MATES" Itis ' ' ONS ON BACK. Signature of Person Legally Authorized to Supply Data:r J U ) ''] r YEAR FOR WHICH THE ACTUAL DATA APPLIES. Typed Name and Title: Gerard G. Alberts, Principal Envi ental 5 isof -cialist Date source began or will begin operation: April 2005 fH1S NOTICE l5 VALID FOR FIVE YEARS. A revised notice shal be filed prior to this expiration are.µ henever a pernnt limitation must he modified, when control equipment is changed, and annually µ hetres er a signlricant emisa on change occurs. For specific details see Regulation 3, Part A, A $119.96 FILING FEE IS REQUIRED FOR EACH NOTICE FILED. Send CClrrlrllllerl films with route M: Colorado Dept. of Public Health &Environment APENr 1 l_of Pollution Control Division 4300 Cherry Creek Drive South, APCD•SS-B i For Information, • • NON -CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM* (Instructions on reverse side) Company Name; Plant Location: Person to Contact: E -Mail Address: Permit Number 02GA0014 — FLARE -1 AIRS Number 04510365/015 Williams Production RMT Company Near Parachute, Colorado Gerard G. Alberts ierrv.alberts@williams.corn County Garfield Zip Code 81635 Phone 303 572-3900 Fax 303 629-8275 Chemical Abstract Service Numberr Chemical Name Reporting Bin Control Equipment/ Efficiency Emission Factor (include units) Emission Factor Source Requested Emissions (lbslyr) Actual Emissions rr Data Year (lbs/ Uncontrolled Emissions of All HAPs Are Below De Minimis Threshold - - _ Use this farm for rc ing Hazardous Air467,5 P ads. '- 0 I 1.r f�J1 Signature of a ' espon ib Official (not vendor or c: nsultant) other Non -Criteria Reportable Pollutant Gerard G. Alberts Ye For Whichl Data Applies: f41.-- -ei Princi • al Environmental S • ialist Date Name of a Responsible Official (please print Title • AIR POLLUTANT EMISSION NOTICE FIRM NAME Williams Production RMT Company 4111/ PERMIT No.: 02GA0014 AIRS ID.:045/0365/Q 15 MAIL ADDRESS 1515 Arapahoe St., Tower 3, Suite 1000 STATE: CO ZIP: 80202 PLANT NAME & LOCATION PARACHUTE CREEK GATS PLANT N ih of NE'/. Section 33. T Sr -f{ fLW COUNTY: GARFiELD REQUEST PORTABLE SOURCE PERMIT HOME -BASE FOR PORTABLE SOURCE PERSON TO CONTACT REGARDING THIS INFORMATION Mr. Gerard G. Alberts TITLE Principal Environmental Specialist PHONE (303)-572-3900 E-MAIL ADDRESS: ierrv. a1bertsQwi11iams . corn GENERAL DESCRIPTION OF THIS PLANTS FUNCTION Natural Gas Processin. A. GENERAL INFORMATION Normal Opera on of This Source Process Seasonal Throughput (% of Annual) ADDITIONAL INFORMATION OR REMARKS: Receives Pilot/Purge/ESDGasfDEHY-1 Flash/OEHY-I Stili VeniAM1NE-1 Flash Hours/Day 24 Days/Week 7 Weeks/Year 52 Dec -Feb 25 Mar -May 25 Jun -Aug 25 Sep -Nov 25 B. STACK OR VENT !NFORMATSON (Identify below which stack if plant has two or more: refer to attached sketch of plant layout) Height 75.0 ft Diameter 3.0 ft Temperature 800 "F Flow Rate Velocity ft/min Moisture % T Plant ID No. for Stack FLARE -1 C. FUEL INFORMATION Design inpput Rate Annual Fuel Consumption Fuel Heating Value: Percent by Weight Seasonal Fuel Use (% of Annual Use) Space F (% Ant Description of Combustion Unit (I0° BTU/hr) Kind of Fuel Burned Requested level Actual level (Data year level) (BTUIIb. BTU/gal, or BTUfscf) Sulfur Ash Dec -Feb Mar -May Jun -Aug + Sep -Nov New Skid Process and Emergency Flare 165.0 Nat Gas & Prriress Coe Approx. 1,100 - MakeiModei: Plant I Process & Emergency Rare , Senal No. 13I9SUFAS - D. PROCESS INFORMATION Raw Materials Used Raw Materials -Annus Consumption , Design Process Rate Finished Product Finished Product-Annua Output Description of Processing_Unit Description Requested level Actual level {Data year level) (Specify Units/Hour.) Descnption Requested level Actual level (Data year leve Makenviodel: — Senai No.: — CHECK New or previously unreported ■ Requesting modification in Change in emissions, Transfer of ownership (list previous owner Previous APEN is expiring Request for Emission ALL BOXES THAT APPLY source* of existing permit throughputs or equipment in REMARKS section Z Reduction Credit t I t t 1 of box A.) t E. POLLUTION CONTROL EQUIPMENT Overall ESTIMATED EMISSIONS (TONS/YEAR) AT THROUGHPUTS REQUESTED ABOVE ACTUAL EMISSIONS (from data year) ESTIMATION METHOD Pollutant Type of Control Equipment Collection Efficiency Pnmary Secondary CONTROLLED UNCONTROLLED Particulate NA NA. PM in NA NA. SO, NA NA. NO, NA 0.7 AP-42(Specify) . Complete all applicable portions of APEN t Complete ' Requested Level ` values for permit limits t Complete all information above box A. and those remaining which reflect changes VOC NA 0.2 AMINEC■lelGLYCaIc CO NA 3.6 AP -42 PLEASE USE USE AF'CD NON -CRITERIA REPORTABLE AIRportions POLLUTANT ADDENDUM FORM TO REPORT SUCH POLLUTANTS OR POLLUTANTS NOT LISTED ABO CHECK HERE IF YOU WISH EMISS a EE " • k e• THE DIVISION CALCULATE YOUR FST1 INSTRUCTIO ' ON BACK. ignature of Person Legally Authorized to Suppiy Data: �'1 i�g ��j YEAR FOR WHICH THE ACTUAL DATA AP` - PL yped Name and Title: } F ' tr Gerard G. Alberts. Princi al Enviro ental 'Mist Date source began or will begin operation: October 2002 HIS NOTICE IS VALID FOR FIVE YEARS. A revised notice shall be filed prior to this expiration .1 ate, whenever a permit limitation most be modified, whenever control equipment Is change and - nnually whenever a significant emission change occurs. For specific details see Regulation 3, Part A, .... A 5119.96 FILING FEE IS REQUIRED 'FOR EACH NOTICE FILED. $end completed forms with fees to: Colorado Dept. of Public Health & Environment APEN It IO of_ Air Pollution Control Division lic Creek Drive South, APCD-SS-B I For information, ...___.__ r �_ eA.,."VIA ,A ,n,. &a, -„ NON -CRITERIA REPORTABLE AIR OLUTANT EMISSION NOTICE ADDEN uM* (Instructions on reverse side) Permit Number Company Name: Plant Location: Person to Contact:: E -Mail Address: 02GA0014 — DEHY-3 Williams Production RMT Company AIRS Number 04510365/*** Near Parachute, Colorado Gerard G. Alberts ieuy,albertst@wil1dams.com County Garfield Zip Code 81635 Phone 303 572-3900 Fax 303 629-8275 ti Chem cal Abstract Service Number Chemical Name ,-- Reporting Bin Control Equipment/ Efficiency Emission Factor (include units) Emission Factor Source Requested Emissions (1bsfyr) Actual Emissions From th Data Year (Ibsfyr) 71-43-2 Benzene A Flare 96% 31,246 Ib/yr Uncontrolled 1,252 lb/yr Controlled CLYCaIc 1,252 108-88-3 Toluene C Flare 96% 1 35,4461b/yr ' Uncontrolled 1,420 lb/yr Controlled CLYCaIc 1,420 133-02-07 ,, Xylenes C Flare 96% 5,694 lb/yr Uncontrolled 228 Ib/yr Controlled GLYCaic 228 1 10.54-3 n -Hexane C Flare 96% 6,000 lb/yr Uncontrolled 2401 b/yr Controlled CLYCaIc 240 Uncontrolled Emissions of All Other HAPs Are Below De Minimis Threshold 4 * Use this (orm for reporting Hazardous Air Pollutants, Ozone Depleting Compounds, and other Non -Criteria Reportable Pollutant Signature of . Resp nsible Official ( +t a vendor or co sultans) Gerard G. Alberts Year For Which The Actual Data Applies: Date Principal Environmental Specialist • FIRM NAME Williams Production RMT Company MAIL ADDRESS 1515 Arapahoe St.. Tower 3. Suite 1000 STATE: CO ZIP; , 0202 PLANT NAME & LOCATION _PARACHUTE CREEK GAS PLANT N ii of NE IA Section 33. T6S. R9W COUNTY. GARFIELD REQUEST PORTABLE SOURCE PERMIT HOME -BASE FOR PORTABLE SOURCE PERSON TO CONTACT REGARDING THIS INFORMATION Mr. Gerard G. Alberts TITLE Principal Environmental Specialist PHONE (303')-572-3900 GENERAL DESCRIPTION OF THIS PLANT'S FUNCTION Natural Gas Processing E-MAIL ADDRESS -errv..a.lberts@williams.com A. GENERAL INFORw+AisoN Normal Operation of This Source — Process Seasonal Throughput (% of Annual) ADDITIONAL,. INFORMATION OR REMARKS: J Flash Gas Routed to FLARE -2, Still Vent Routed Through 120 deg. F Condenser to FLARE -2. No Hours/Day 24 Days/W 7 eeks/Ycar 52 Dec -Feb 25 Mar -May 25 - Jun -Aug 25 _ Sep -Nov 25 Direct Emissions to Atmosphere. B STACK OR VENT INFORMATION (Identify below which stack if plant has two or more; refer to attached sketch of plant lavout) - Height it Diameter ft 1 Temperature °F Flow Rate ACFM Velocity ft/min Moisture Plant ED No. for Stack DEHY-3 C. FUEL INFORMATION De -sign Input Rate Annual Fuel Consumption Fuel Heating Value: Percent by Weight Sea_sonaf Fuel Use ('I of Annual Use) Space Htg Description of Combustion Unit (10' BTU/hr) Kind of Fuel Burned Requested level Actual level (Data year level) (BTUiib, BTU/gal, , or BTU/scf) Sulfur Ash Dec•Fcb Mar -May. Jun -Aug Sep -Nov (% Ann.) Make/Model: - Serial No. D. PROCESS INFORMATION Raw Materials Used Raw :Materials -Annual Consumption Design Process Rate Finished Product Finished Product•Annual Output Description of Processing Unit Description Requested level Actual level ( Data yrtrr level) (Specify Units/Hour) Description Requested levet Actual 1evcI Data year ley, PLANT 2 TEG GAS DEHYDRATION UNIT - — $0 MMscflday Dehydrated N.G. hlaJ&Model: Sena' No.; E. POLLUTION CONTROL EQUIPMENT Overall ESTIMATED EMISSIONS ACTUAL ESTIMATION CHECK ALL BOXES THAT APPLY Pollutant Type of Control Equipment Collection Efficiency (TANS/YEAR) AT THROUGHPUTS REQUESTED ABOVE _ EMISSIONS (from data year) METHOD ■ New or previously unreported source* • Requesting modification of existing permit t 1 Primary Secondary CONTROLLED UNCONTROLLED Change in emissions, throughputs or equipment $ Particulate NA NA. Transfer of ownership (List owner in REMARKS section of box A.) t PM, NA NA. - — previous Previous APEN is expiring I SO, NA NA. Request for Emission Reduction Credit t i NO, - (Specify) NA NA � Complete APEN VOC Process Flare 96,0 S64.9 122.5 GRI GLYCaIc all applicable portions of t Complete 'Requested Level' values for permit limits CO NA NA $ Complete all information above box A, and those remaining PLEASE USE APCD NON -CRITERIA REPORTABLE AIR POLLUTANT ADDENDUM DORM TO REPORT SUC POLLUTANTS OR POLLUTANTS NOT LISTED A13 r, C K HERE IF YOU • ONr 5 WISH THE DIVISION TO CALCULATE YOUR MISSION ESTIMATES" INSTRUCTIONS N BACK. portions which reflect changes ignature of Person Legally Authonred to Supply Data. / ] DA YEAR FOR WHICH THE ACTUAL DATA APPLIES: Typed Name and Title: Gerard G. Alberts, Principal Environmental Specialist tt• Date source began or will begin operation; Third luarter 2005 THIS NOTICE IS VALID FOR FIVE YEARS. A revised notice shall be filed prior to this expiration date, whenever a permit limitation must be modified, whenever control equipment is changed, and annually whenever a significant emission change occurs. For specific details see Regulation 3, Part A, ' II.C,1. _ A $119.96 FILING FEE IS REQUIRED FOR EACH NOTICE FILED, Send completed forms with fees to: Colorado Dept. of Public Health Air Pollution Control Division 4300 Cherry Creek Drive South. Denver. Colorado 80246-1530 & Environment APEN rie9_of_12_ APCD-SS-B I For Information, Call (303) 692.3150 * • NON -CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDE • Permit Number Company Name: Plant Location: Person to Contact: E -Mail Address: (instructions on reverse side) 02GA0014 -- DEHY-2 Williams Production RMT Company Near Parachute, Colorado AIRS Number 045/0365/028 Gerard G. Alberts ierrv.alberts@williams-com County Garfield Zip Code 81635 Phone 303 572-3900 Fax 303 629-8275 Chemical Abstract Service Number Chemical Name Reponing Bin Control Equipment/ Efficiency Emission Factor (include units) Emission FsctorRequested Source Emissions - (Ib yr) Actual Emissions from tk Data Year (Ibs/yr) 71-43-2 Benzene A Flare96% 10,294 Ib/yr Uncontrolled 378 l b/yr Controlled GLYCa1c 378 108-88-3 Toluene C Flare 96% 2,855 Ib/yr Uncontrolled 106 lb/yr Controlled GLYCaIc 106 133-02-07 Xylenes C Flare 96% ,726 lb/yr Uncontrolled 64 lb/yr Controlled GLYCaIc 1 64 Uncontrolled Emissions of All Other HAPs Are Below De Minimis Threshold Use this form for reporting Hazardous Air Pollutants, Ozone Depleting Compounds, and other Non -Criteria Reportable Pollutant Signat of = Responsible 0 icial (not a vendor or consultant) Gerard G. A berts Name of a Responsible Official (please print) ATR P01.T .T TT A NT PMT.c.c TfnN.T MTfT C Year For Which The Actual Data Applies: Date Principal Environmental S cialist Title Al• OLLUTANT EMISSION NOTICE FIRM NAME Williams Production RMT Company MAIL ADDRESS 1515 Arapahoe St., Tower 3, Suite 1000 PERMIT No.: 020A0014 AIRS ID.:045/0365/028 PLANT NAME & LOCATION PARACHUTE CREEK GAS PLANT N lhgf trE'4 Section 33 T6S R96W STATE: CO ZIP: 80202 COUNTY: GARFIELD REQUEST PORTABLE SOURCE PERMIT HOME -BASE FOR PORTABLE SOURCE PERSON TO CONTACT REGARDING THIS INFORMATION^Mr. Gerard G. Alberts GENERAL DESCRIPTION OF TUTS PLANTS FUNCTION Natural Gas Processing E-MAIL ADDRESS: ler ry. a 1 be s @w± 11 isms . corn TITLE Principal Environmental Specialist PHONE (303)-572-3900 A. GENERAL INFORMATION Normal Operation of This Source Hours/Day 24 DayslWcck 7 eekslYcar 52 Process Seasonal Throughput (%v of Annual) Dec -Feb 25 Mar -M 25 Jun -Aug 25 ep•Nov 25 ADDITIONAL INFORMATION OR REMARKS: Flash Routed to FLARE -2. Still Vent Routed Through 120 deg. F Condenser to FLARE -2, No Direct Emissions to Atmosphere. B. STACK OR VENT INFORMATION (Identify below which stack if .lint has two or more: refer to attached sketch of dant lasoutl Height Diameter Temperature ft ft °F C. FUEL INFORMATION Description of Combustion Unit Flow Rare ACFM Velocity ft/mire Moisture Design Input Rate (I0' BTU/hr) Kind of Fuel Burned Annual Fuel Consumption Requested level Actual lewd (Data year level) Make/Model: Serial No D. PROCESS INFORMATION Description of Processing Unit Raw Materials Used PLANT 2 EG DEHYDRATION UNIT Make/Madel: Serial No.: E POLLUTION CONTROL EQUIPMENT Pollutant Type of Control Equipment Prima Secondary Particulate Plant ID No. for Stack DENY -2 Fuel Heating Value:. (BTU/Ib. BTU/gal, or BTU/scf) Percent by Weigh Sulfur Ash Seasonal Fuel Use (% of Annual Use) Dec -Feb Mar -May Jun -Aug Sep -Nov Space (% A Raw Materials-Annua Consum Rtit:+n Actual level Desai •tion Requested level (Data year level) Ovcrai l Collection Efficiency ESTIMATED EMISSIONS (TONS/YEAR) AT THROUGHPUTS REQUESTED ABOVE CONTROLLED UNCONTROLLED NA NA Design Process Ratc i Units/Hour) IvilvIscf/day ACTUAL EMISSIONS (from data year) Finished Product Descripuon Finished Product-Annua Ou Dehydrated N.G. ESTIMATION METHOD P'E'I i o NA NA. 50 NA NA. NO, NA NA VOC Process Flare 96% 0.7 17.4 GRI GLYCaIc CO NA NA PLEASE USE APCD NON•CRITERIA REPORTABLE A!R CHEC ' RE 1F YOU WISH THE DIVISION TO CALCULATE YOUR POLLUTANT ADDENDUM FORM TO REPORT SUC POLLUTANTS OR POLLUTANTS NOT LISTED AB a�-. E ‚. i S1; 1SSION E STIM = a ' INSTRUCTIONSwriirtri4 Pr Signature o Person Legally Authorized to Supply Data: Taped Name and Title: Gerard G. Alberts, Pnnctpal iiivironm ntal Soccialist DA B CK. ■ t • Actua eve R-• uested level Data year ie+ CHECK ALL BOXES THAT APPLY New or previously unreported source' Requesting modification of existing permit f t Change in emissions. throughputs or equipment t Transfer of ownership (List previous owner in REMARKS section of box A. t Previous APEN is expiring It Request for Emission Reduction Credit t t (Specify) - - Complete all applicable portions of APEN Complete ' Requested Levelvalues for permit limits Complete all information above box A. and those remaining portions which reflect changes YEAR FOR WHICH THE ACTUAL DATA APPLIES Date source began or will begin operation: April 2005 THIS NOTICE 03"It;:E rS VA LID FOR FIVE YEARS. A revised police shall be filed prior to this expiration date, whenever a permit limitation must be modified, whenever control equipment is changed, and annually whenever a significant emission • A $119.96 FILING FEE IS REQUIRED Colorado Dept. of Public Health & Environment FOR EACH NOTICE FILED. Air Pollution Control Division 4300 Chcrr‘ Creek Drive South, APCD-SS-B 1 APEN a S_of_12� For Information,^Cal1 NUN -CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM (instructions on reverse side) AIRS Number 045/0365/010 Permit Number Company Name: Plant Location: Person to Contact: E -Mail Address: 02GA0014 -- DEHY-1 Williams Production RMT Company Near Parachute, Colorado Gerard G. Alberts i erre. alberts$williatt+s . com County Garfield Zip Code 81635 Phone 303 572- 3900 Fax 303 629-8275 Chemical Abstract Service Number Name Reporting Bin Control Equipment) Efficiency Emission Factor (include units) ' Emission Factor Source Requested Emissions (lbs/yr) Actual Emissions from Data Year ((b yr) 71-43-2 Benzene A Flare 96% 7,668 lb/yr Uncontrolled 286 lblyr Controlled GLYCaIc 286 108-88-3 Toluene C Flare 96% 2,125 lb/yr Uncontrolled 81 lb/yr Controlled GLYCaIc 81 Uncontrolled Emissions of All Other HAPs Are Below De Minimis Threshold Use this form for reporting Hazardous Potluruts. ©.ne Depleting Compounds. and other Non -Criteria Reportable Pollutant Year For Which The Actual Data Applies: Signal a of Responsible • ficial of a vendor or consultant) Gerard G. Alberts Date Principal Environmental Specialist Name of a Responsible Official (please print) Tide • AIR POLLUTANT EMISSION NOTICE FIRM NAME Williams Production RMT Companv MAIL ADDRESS 1515 Arapahoe SL, Tower 3 Suite 1000 STATE: CO ZIP: 80202 • PERMIT No.: 02GA0014 AIRS ID.:045/03651010 PLANT NAME & LOCxAT1ON PARACHUTE CREEK GAS PLANT N16 of NE 'A Section 1),T6S. 8 COUNTY: GARFIELD REQUEST PORTABLE SOURCE PERMIT HOME -BASE FOR PORTABLE SOURCE PERSON TO CONTACT REGARDING THIS INFORMATION.JvIr. Gerard G. Alberts - TITLE Principal Environmental Specialist PHONE _(303)-572- 900_ GENERAL DESCRIPTION OF THIS PLANTS FUNCTION Natural Gas Processing E-MAIL. ADDRESS: 7 errs, albertsCawilliams . corn A. GENERAL INFORMATION Normal Operation of This Source Process Seasonal Throughput (% of Annual) ADDITIONAL INFORMATION OR REMARKS: Flash Routed to FLARE- I , Still Vent Routed Through 120 deg. F Condenser to Hours/Day 24 Days/Week 7 Weeks/Year 52 Dec -Feb 25 Mar -May 25 Jun -Aug 25 Sep -Nov 2.5 FLARE -1, No Direct Emissions to Atmosphere. B. STACK OR VENT INFORMATION (Identify below which stack if plant has two or more: refer to attached sketch of plant layout) Height ft Diameter ft Temperature °F Flow Rate ACFM Velocity ftlmin Moisture % Plant ID No. for Stack DEHY-1 C. FUEL INFORMATION Desiggn Input Rate Annual Fuel Consumption Fuel Heating Value: Percent by Weight Seasonal Fuel Use f% of Annual Use) Space Descnption of Combustion Unit (1e BTU/hr) Kind of Fuel Bunted Requested level Actual level (Data year level) (BTU/lb, BTU/gal, or BTUlscf) Sulfur Ash Dec -Feb Mar -May Jun -Aug Sep -Nov (% An Make/Model: - Se No, - - - - - , a } - IIa wry _ - -I - — -. _ .. a 46.••••••%T=- - - D. PROCESS INFORMATION Raw Materials Used Raw Materials-Annua Consumption Design Process Rate Finished Product Finished Product•Annua Output Descnption of Processing Unit Description. Requested level Actual level (Data year level) (5fv Units/Hour) Descnpaion - Requested level Actual level (Data year ley PLANT 1 EO DEHYDRATION UNIT T23 4Mscfiday Camineled N.G. Dehydrated N.G. Makellriode[: Sena! No.: yr I -grit - -. _._ —\ {E. POLLUTION CONTROL EQUIPMENT Overall ESTIMATED EMISSIONS ACTUAL ESTIMATION CHECK ALL BOXES THAT APPLY (Pollutant Type of Control Equipment Collection Efficiency (TONS/YEAR) AT THROUGHPUTS REQUESTED ABOVE EMISSIONS (from data year) METHOD New or previously unreported source* • Requesting modification of existing permit t 1 Pnmary Secondary CONTROLLED UNCONTROLLED 1 Change in emissions, throughputs or equipment t Particulate NA NA. Transfer of ownership (List owner in REMARKS section of box A.) t PMi4 NA _ NA. previous Previous APEN is expiring X SO, - - NA NA. Request for Emission Reduction Credit 11 (Specify) NO, NA NA ' Complete APEN VOC Process Flare 96%0.5 13.2 GRI GLYCaIc all applicable portions of t Complete ' Requested Level • values for permit limits CO NA _ NA_ s Complete all information above box A, and those remaining !'LEASE USE APCD NON -CRITERIA REPORTABLE AIRportions POLLUTANT ADDENDUM FORM TO REPORT SU POLLUTANTS OR POLLUTANTS NOT LISTED ABO CHEC HERE ) EMI i N• IF YO H THE DIVISION TO CALCULATE YOUR S • E ON ESTIMAT '-INSTRUCTIONS ON BACK. which reflect changes �^^- Signaturc of Person Legally Authorized to Supply Data: ,f 1 I p .7 r l �1'f (� YEAR FOR WHICH THE ACTUAL DATA APPLIES: Tpcd Name and Title: iron= G. Alberts. Principal irontat Specialist �r<. --s___—_," Date source began or will begin operation: October 2002 . �, THIS NOTICE IS VALID FOR FIVE YEARS. A revised notice shall be filed prior to this expiration date, whenever a permit Imitation must be modified, whenever control equipment Is changed, and annually whenever a signlfkant emissionfj --- $119.96 FILING FEE IS REQUIRED IFOR EACH NOTICE FILED, - ..4300 Colorado Dept. of Public Health Air Pollution Control Division Cherry Creek Drive South. & Environment APEN It_7_of_12_ APCD-SS-Bl For Information, Gall • NON -CRITERIA REPORTABLE AIR P D LLUTANT EMISSION NOTICE ADDENDUM (Instructions an reverse side) Permit Number Company Name: Plant Location: Person to Contact: E -Mail Address: 02GA0014 — AMINE -2 AIRS Number 045/0365/027 Williams Production RMT Company Near Parachute, Colorado Gerard G. Alberts -errv.alberts@williams.corn County Garfield Zip Code 81635 Phone 303 572-3900 Fax 303 629-8275 Chemical Abstract Service T Number Chemical Name Rcponing Bin Control Equipment/ Efficiency Emission Factor (include units) Emission Factor Source Requested Emissions— (lbs/yr) Actual Emission from the Data Year (lbs/yr) 71-43-2 Benzene A Flare 96 T.O.99.9' 48,942 lb/yr Uncontrolled 358 lb/yr Controlled AMINECa1c 358 108-88-3 Toluene C Flare 96% TO. 26,771 Ib/yr Uncontrolled 461 1b/yr Controlled AMINECalc 461 100-41-4 Ethylbenzene C Flare 96% T.D. 99.9% 4,380 lb/yr Uncontrolled 36 lb/yr Controlled AMINECalc 36 133-02-07 Xylenes C Flare 96% T.O.99.9% 8,970 lb/yr Uncontrolled 174 lb/yr Controlled AMINECa1c 174 110-54-3 n -Hexane C Flare 96' T.O.99.9%a 2,392 lb/yr Uncontrolled 90 lb/yr Controlled AMINECa1c 90 Uncontrolled. of All Other HAPs Are Below De Minimis Threshold Use this form for reporting Hazardous Air ilulants, Ozone Depl g Compounds. and other Non -Criteria Reportable Pollutan Signature of es o le ficia (not vendor or consultant) Gerard G. Alberts Mania /Air 9 T%ae•nnw.r.f F,l. , cc .....1 I..1.-- Year For Which The Actual Data Appli;- �s� Date Principal Environmental Specialist AI .)LLUTANT EMIS I " � C)N .NC�TI�� PERMIT N�.: az�cAaa �4 AIRS u�..i�+s/a36s/o27 FIRM NAME Williams Production RMT Company MAIL. ADDRESS 1515 Arapahoe St„ Tower 3. Suite 1000 STATE: CO ZIP: 80202 PLANT NAME & LOCATION PARACHUTE CREEK PLANT N'/ of NE' f« Section 33. T6S. R96W REQUEST PORTABLE SOURCE PERMIT HOME -BASE FOR PORTABLE SOURCE PERSON TO CONTACT REGARDING THIS INFORMATION Mr. Gerard G. Alberts GENERAL DESCRIPTION OF THIS PLANTS FUNCTION Natural Gas Proces.sin F? COUNTY: QARFIELP TITLE Principal Environmental Specialist PHONE 303 - 7 E-MAIL ADDRESS' 4 erry . a l be i t s @w i l l i atr,s . corn A. GENERAL INFORMATION Normal Operation of This Source Process Seasonal Throughput (% of Annual) ADDITIONAL INFORMATrON OR REMARKS: Flash Tank Routed to FLARE -2 and Still Ven! Routed to TO -1 Controls. No Direct Hours/Day 24 Days/Week 7 Weeks/Year 52 Dec -Feb 25 Mar -May 25 Jun -Aug 25 Sep -Nov 25 Emissions to Atmosphere. B. STACK OR VENT INFORMATION (Identify below which stack if plant has two or mors, refer to attached sketch of plan layout) Height ft Diameter ft Temperature 'F Flow Rate Velocity ACFM ft/min Mloisture Plant ID No. for Stack AMINE -2 Space (To Ar C FUEL INFORMATION Design Input Rate Annual Fuel Consumption Fuel Heating Value: Percent by Weight Seasonal Fuel Uses% of Annual Use) Description of Combustion Unit (10° EBTUIhr) ' Kind of Fuel Burned Requesred level Actual level (Data year level) (BTUflb. BTU/gal, or BTUlscf) Sulfur Ash Dec.Feb Mar -May tun -Aug Sep•Nov MakedModel Sepal No D, PROCESS INFORMATION Raw Matenals Used Raw hlatenals-AnnuaI Consumption Design Process Rate Finished Product Finished Product•Annua Output Description of Processing Unit Description ' Requested level Actual level - (Data year level) (Specify Units/Hour) Description Requested level Actual level (Data year ley _ PLANT 2 AMINE SWEETENING UNIT 150 MMscflday Low CO2 Nat. Gas MakeiModel : - - Serial No - 'Ilinimt E. POLLUTION CONTROL EQUIPMENT Ove all ESTIMATED EMISSIONS ACTUAL ESTIMATION CHECK ALL BOXES THAT APPLY Pollutant Type of Control Equipment - Collection Efficiency (TONS/YEAR) AT THROUGHPUTS REQUESTED ABOVE EMISSIONS (from data year) METHOD New or previously unreported source' • Requesting modification of existing permit t t Primary Secondary CONTROLLED UNCONTROLLED 11 Change in emissions, throughputs or equipment # Particulate NA NA Transfer of ownership (List owner in REMARKS section of box A.) r PMo NA NA previous Previous APEN is expiring 1 SO, _ NA NA Request for Emission Reduction Credit t s (Specify) NO. NA NA 'Complete of APEN VOC Flash to Flare Still Vent to TO Flare 96% TO e99.9 a 1.7 FLASH <0.1 STILL 41.9 FLASH 35.1 STILL VENT AM1NECalc all applicable pinions t Complete ' Requested Level' values for permit limits # Complete all information above box A. and those remaining CO NA NA portions which reflect changes PLEASE USE AICD NON -CRITERIA REPORTABLE Alli POLLUTANT ADDENTDUM FORM TO REPORT SU - POLLUTANTS OR POLLUTANTS NOT LISTED AB a 1 CHECK HERE IF YOU EMISSI ill SES "E, WIS . E DIVISION TO CAL SI, . IMA ' UCTIONS TE YOUR ON BACK. Sigesture o}Person Legally Authorized to Supply Data: I vrir ' ai YEAR FOR'HIC� UAL DATA APPLIES. Date source began or will begin operation: April 2005 _ _ rr in yped Name and Title: Gerard G. Alberts, Princi.al Env .nmenacialist �1"IIIS NOTICE 15 VALID FOR 1'14''E YEARS. A revised precise shah he tiled priorit Ito this expiration date, whenever a pertrut limitation must be modified, whenever kontrui eautpmCnl is chantted. and r.nrenally whenever a sivnirtr�nt ernicci ,n A h rrrvr FILING FEE IS REQUIRED Colorado Dept. of Public Health &Environment APEN 446_oL-12. 'O EACH NOTICE FILED. Air Pollution Control Division AIM Chrrr., Cn k tin WP Cn<Ai'h APrrI_CC.rt! Fnr lnfnrm�tinn inti • NON -CRITERIA REPORTABLE AIR P LLUTANT EMISSION NOTICE ADDENDUM* (Instructions on reverse side) Permit Number Company Name: Plant Location: Person to Contact: E -Mail Address: 02GA0014 - AMINE -1 AIRS Number 045/0365/009 Williams Production RMT Company Near Parachute, Colorado Gerard G. Alberts County Garfield Zip Code 81635 Phone 303 572-3900 Fax 303 629-8275 ierrv.alberts@wi 1 i,wns .corn Chemical Abstract Service Number Chemical Name Reporting Bin Control Equipment/ Efficiency Emission Factor (include units) Emission Factor Source — Requested Emissions (lbs/yr) Actual Emissions from the Data Year (lbs/yr) 71-43-2 Benzene T A Flare 96% T.O.99.9% 19,342 lb/yr Uncontrolled 153lb/yr Controlled AMINECaIc 153 108-88-3 Toluene C Flare 96% T.O.99.9% 10,074 lb/yr Uncontrolled 188lb/yr Controlled AMINECaIc 188 100-41-4 Ethylbenzene C Flare 96% T.O.99.9% I,7521b1yr T Uncontrolled 15lblyr Controlled AMINECaIc 15 133-02-07 Xylenes C Flare 96% T.O.99.9% 3,373 lb/yr Uncontrolled 701b/yr Controlled AMINECa1c 70 - Uncontrolled Emissions of All Other 1-lAPs Are Below De Minimis - Threshold - - r Use this f• rm for reporting Flan~ Reportable P lutan Po]jutants, Ozone Depicting Compounds, and other Non -Criteria Signat re of a R-sponsible Official of a ven'or or 1.nsultant) Gerard G. Alberts Year For Which The Actual Data ,rte} Applies: Date Principal Environmental Specialist AIR OLLUTANT EMISSION NOTICE .. FIRM NAME Williams Production RMT Com an MAIL ADDRESS 1515 Arapahoe St., Tower 3, Suite 1000 STATE: CO ZIP: PLANT NAME & LOCATION`PABACHUTE C1 EEK t PLANT P N of NE rA Section 33. T6$. RW 96COUNTY: Q( REX LD • PERMIT No.: 020A0014 AIRS ID.:045/0365/009 80202 REQUEST PORTABLE SOURCE PERMIT HOME -BASE FOR PORTABLE SOURCE PERSON TO CONTACT REGARDING THIS INFORMATION v1t. Qerard G. Alb r s TITLE Principal Environmental Specialist PHONE GENERAL DESCRIPTION OF THIS PLANTS FUNCTION Natural Gas Processing E-MAIL ADDRESS: -jerrv. alberts@williams . (303)-572-3900 A. GENERAL Normal Operatian of This Source INFORMATION Process Seasonal Throughput (% of Annual, ADDITIONAL INFORMATION OR REMARKS: Flash Tank Overhead Routed to FLARE -I. Still Vent Overhead Routed to Hours/Day Days/Week l 24 7 Weeks/Year 52 Dec -Feb 25 Mar -May 25 t Jun -Aug 25 Sep -Nov 25 TO -I, No Direct Emissions to Atmosphere. B. STACK OR VENT INFORMATION Identify below which stack ifpiant has two or more: refer to attached sketch of Dant layout) - - - Height tt Diameter ft Temperature 1= Flow Rate ACFM Velocity ft/min Moisture Saturated Plant ID No, for Stack AMINE- I Flash To FLARE -1 and Still Vent To TO -1 Controls, Emissions Reported On Control Device APENs Space (% Ar C. FUEL INFORMATION Design npput Rate Annual Fuel Consumption Fuel Heating Value: Percent by Weight Seasonal Fuel Use (% of Annual Use) Description of Combustion Unit (106 BTU/hr) Kind of Fuel Burned Requested level Actual level (Data year level) (BTU/lb. BTU/gal, or BTU/scf) Sulfur .Ash Dec -Feb Mar -May Jun -Aug Sep -Nov MakeiModel Serial No, D. PROCESS INFORMATION Raw Materials Used Raw Materials-Annua Consumption Design Process Rate Finished Product Finished Product -Annual Output Description of Processing Unit Description Requested level Actual level (Data year level) (Specify Units/Hour) Description Requested level Actual leve (Data year ley PLANT 1 AMINE SWEETENING UNIT 55 MMscf/day Low CO2 Nat. Gas hI eiModl, Sena] do E. POLLUTION CONTROL EQUIPMENT Overall ESTIMATED EMISSIONS ACTUAL. ESTIMATION CHECK ALL BOXES THAT APPLY Pollutant Type of Control Equipment Collection Efficiency (TONS/YEAR) AT THROUGHPUTS REQUESTED ABOVE EMISSIONS (from data year) METHOD New or previously unreported source' ■ Requesting modification of existing permit t t Primary Secondary CONTROLLED UNCONTROLLED ■ Change in emissions. throughputs or equipment s Pantcu late NA NA Transfer of ownership (List owner in REMARKS section of box. A.) t P`t,,? NA NA previous Previous APEN is expiring 1 S0, -- NA NA Request for Emission Reduction Credit t t — - — NA (Specify) NO, NA •' Complete of APEN VOC Flush to Flare Still Vent to TO Flare 9befa TO 99.9% 0.7 FLASH <0.1 STILL 16.8 FLASH 13.1 STILL GRI AMINECa1c all applicable portions t Complete ' Requested Level' values far permit limits t Complete all information above box A, and those remaining. CO NA NA portions which reflect changes PLEASE USE APCD I► ON.CRITERIA REPORTABLE AIR POLLUTANT ORRPOLLUENDUM FORM TO REPORT SUC . POLLUTANTS POLLUTANTS NOT LISTED AB • '?. a CK t• RE IF Y a U WI H THE DIVISION T O CALCULATE E YOUR ;Iii i 14 SE �1 USS r N ESTIMATES" INSTRUCTIONS ON BACK. Signature o Person Legally Aulhon to Supply DaNtlY IllrigEr _ fryped DA ): � YEAR FOR WHICH THE ACTUAL DATA APPLIES Name and Title: Gerard G. Alberts, Ptancipa1 EnvironmentaLiS - cialist Date source began or will begin operation: October 2002 THIS NOTICE IS VALID FOR FIVE SEARS. A revised notice shall be filed prior to this expiration date, whenever a permit limitation must be modified, whenever ns control equipment is changed, and annually whenever a significant emission change k $119.96 FILING FEE IS REQUIRED l OR EACH NOTICE FILED.I Colorado Dept. of Public Health Air Pollution Control Division 4300 Cherry Creek Drive South. & Environment APEN ti_5_o1-d12_ APCD-SS-B 1 For Information. Call Williams Production RMT Co. November 2005 Submittal 11. I .B.2 Dust Control at Parachute Creek Gas Plant Expansion- Phase 3 "All excavation work shall be conducted in a manner that preserves soil and allows for the segregation of soil types in order to facilitate land reclamation in the future. Measures shall be taken to prevent excessive soil erosion by wind or water including the Best Management Practices as detailed in the Stormwater Management Plan for the site. All excavated surfaces shall be maintained with adequate moisture to reduce wind erosion." • • • PVCMI Land Planning Division 1038 County Road 323 Rifle, CO 81650 Ph. 970-625-5350 Fax 970-625-4522 Email: pvcm@direcway.com Project: Williams Production RMT Co.- Parachute Creek Gas Plant Expansion Phase 3 Submittal Item Number: 11.t.B.4 Noise Abatement The Parachute Creek Gas Plant will have the following equipment installed that will produce noise: A. 4- Model 3612 Residue Gas Compressors With 4- Model 3612 Residue Gas Compressors added in the future as -needed. Each of these compressors will have residential quality exhaust silencers installed. Additionally, a pre-engineered steel building will enclose the residue gas compressors. The silencers are a Best Management Practice and will help ensure that the compressors meet regulations set forth by the State of Colorado for noise at property boundaries. B. 3 — Model 3512 Propane Refrigeration Engines With 1- Model 3512 Propane Refrigeration Engine added in the future as -needed. Each of these engines will have residential quality exhaust silencers installed. Additionally, a pre-engineered steel building will enclose the engines. The silencers are a Best Management Practice and will help ensure that the compressors meet regulations set forth by the State of Colorado for noise at property boundaries. As per rule 802- Noise Abatement, of the Colorado Oil and Gas Conservation Commission, noise emissions from this plant to adjacent industrial uses are 80 db(A) from 7:00 a.m. to 7:00 p.m. and 75 db(A) from 7:00 p.m. to 7:00 a.m. Industrial uses are the predominant uses in the area. As per rule 802- Noise Abatement, of the Colorado Oil and Gas Conservation Commission, noise emissions from this plant to adjacent residential uses are 55 db(A) from 7:00 a.m. to 7:00 p.m. and 50 db(A) from 7:00 p.m. to 7:00 a.m. The nearest residential units are located as follows: 1. A residence located on the east side of County Road #215, 3,770 ft. (.71 mile) south of the Parachute Creek Gas Plant entrance on County Road #215. Page 1 of 2 2. A residence 15,130 lineal feet (2.87 miles) to the south from the plant expansion boundary. COGCC Rule 802 (1) gives guidance regarding taking sound measurements. "If there are no occupied building units impacted, sound levels shall be measured at a distance of twenty-five (25) feet or more from the property line radiating the noise. Sound levels at occupied building units shall be measured as near as practicable to the exterior edge of the occupied building unit closest to the area radiating the noise." As noted in Garfield County Resolution 2005-09, Williams Production RMT Co. agrees that "If the proposed use allegedly produces a volume of sound which violates noise standards as set forth in the Colorado Revised Statutes, Williams Production RMT Co. shall hire an acoustical engineer, measure the amount of noise, and if in violation implement proposed mitigation measures of the nuisance noise within 60 days." Please contact me with any questions. Sincerely, Philip B. Vaughan President PVCMI Page 2 of 2 • • PVCMI Land Planning Division 1038 County Road 323 Rifle, CO 81650 Ph. 970-625-5350 Fax 970-625-4522 Email: pvcmrdirecway.com Project: Williams Production RMT Co.- Parachute Creek Gas Plant Expansion Phase 3 Submittal Item Number: 11.1,13.5 Glare Abatement Paint Colors: The Parachute Creek Gas Plant will painted as per COGCC Rule #804. Visual Impact Mitigation which states "Production Facilities constructed or substantially repainted after May 30, 1992 which are observable from any public highway shall be painted with uniform, non -contrasting, non -reflective color tones, (similar to Munsell Soil Color Coding System) and with colors matched to but slightly darker than the surrounding landscape." The existing plant has utilized the Munsell Soil Color "Desert Brown". The plant expansion will match the existing plant color of Desert Brown. Flares: There are 2 existing flares on-site and an additional flare will be added to the Phase 3 expansion. These flares are shown on the site plans. The plant flares are smokeless and will produce a glare when the plant is flaring. Flaring does not occur very often. This is a safety feature of the plant that cannot be hidden or obscured. Please contact me with any questions. Sincerely, Philip B. Vaughan President PVCMI Page 1 of I • PVC11411 Land Planning Division 1038 County Road 323 Rifle, CO 81650 Ph. 970-625-5350 Fax 970-625-4522 Email: pvem@direcway.com direcway.com Project: Williams Production RMT Co.- Parachute Creek Gas Plant Expansion Phase 3 Submittal Item Number: 11.1.13.6 Vibration Abatement Vibrations produced by rotating equipment such as the residue gas compressors will be minimized through concrete foundation design and geotechnical reports. The Hanover Company will be supplying and installing the compressor and will be designing the concrete foundations. The Hanover Company has experience in design of thousands of compressors and compressor foundations worldwide. Minimization of vibration is also important to prolong equipment life and is a goal of foundation design. Geotechnical reports have also been prepared by Geotechnical Engineering Group, Inc. Please find this information attached. We feel that the expertise of The Hanover Company and Geotechnical Engineering Group will ensure the minimization of vibrations. Please contact me with any questions. Sincerely, Philip B. Vaughan President PVCMI Page 1 of 1 • Geotechnical Engineering &,Group, Ine. GEOTECHNICAL INVESTIGATION Williams Production, Gas Plant No. 3 Addition County Road 215, South of Starkey Gulch Garfield County, Colorado Prepared For: Williams Production RMT Company P.O. Box 370 Parachute, CO 81635 Attention: Mr. Eric Miller Job No. 2,108 November 3, 2005 Geotechnical, Environmental and Materials Testing Consultants Grand Junction - Montrose - Moab - Crested Butte (970) 245-4078 • fax (970) 245-7115 • geotechnicalgroup.cam 2308 Interstate Avenue, Grand Junction, Colorado 81505 • TABLE OF CONTENTS SCOPE 1 SUMMARY OF CONCLUSIONS 2 SITE CONDITIONS 3 PROPOSED CONSTRUCTION 4 SUBSURFACE CONDITIONS 5 SITE DEVELOPMENT 6 FOUNDATIONS 7 DRIVEN PILES 9 DRILLED PIER FOUNDATIONS 10 SPREAD FOOTINGS- STRUCTURES WHERE MORE RISK OF MOVEMENT IS ACCEPTABLE 11 MAT FOUNDATIONS - TANK STORAGE AREAS WHERE MORE RISK OF MOVEMENT IS ACCEPTABLE 12 FLOOR SYSTEMS 13 • BELOW -GRADE CONSTRUCTION 14 PERCOLATION TESTING 15 CONCRETE 16 SURFACE DRAINAGE 16 CONSTRUCTION MONITORING 17 LIMITATIONS ....18 FIG. 1 - VICINITY MAP FIG. 2 - LOCATION OF EXPLORATORY BORINGS FIGS. 3 THROUGH 7 - LOGS OF EXPLORATORY BORINGS RG. 8 - LEGEND AND NOTES OF EXPLORATORY BORINGS FIGS. 9 THROUGH 13 - SWELL CONSOLIDATION TEST RESULTS FIGS. 14 AND 15 - GRADATION TEST RESULTS FIGS. 16 THROUGH 18 - SOIL PERCOLATION TEST RESULTS TABLE 1 - SUMMARY OF LABORATORY TEST RESULTS APPENDIX A - SAMPLE SITE GRADING SPECIFICATIONS • • • • SCOPE This report presents the results of our Geotechnical Investigation for the proposed Williams Production, Gas Plant No. 3 southwest of County Road 215 in Parachute, Colorado. Our investigation was conducted to explore subsurface conditions and provide foundation design recommendations for the anticipated construction. The report includes descriptions of subsoil and groundwater conditions found in nineteen exploratory borings made during this investigation, results of soil percolation testing, recommended foundation systems, allowable design soil pressures and design and construction criteria for details influenced by the subsurface conditions. This report was prepared as continuing services, in general conformance with our Proposal No. 04-101, dated June 4, 2004. The report was prepared from data developed during field exploration, laboratory testing, engineering analysis and experience with similar conditions. A brief summary of our conclusions and recommendations follows. Detailed criteria are presented within the report. Williams Production Gas Plant No. 3 1 GEG Job No. 2,108 SUMMARY OF CONCLUSIONS Subsoils found in the exploratory borings included up to 67 of sandy clay underlain by clayey gravel to the maximum depth explored of 15 to 78 feet. Practical drill rig refusal was encountered at 67 feet, using 4 -inch solid stem auger, in exploratory boring TH-2 in the underlying gravels. Groundwater was encountered at 15.5, 26 and 32 feet below the ground surface on the day of drilling in exploratory borings TH-1, TH-2 and TH-16 (respectively). 2. Variable, medium stiff to very stiff, sandy clay soils were identified at foundation levels. We recommend driven piles or drilled piers bedded in an underlying competent strata to mitigate potential settlement of structures. A competent stratum was identified at depths of 59 to 76 feet. A recommendation for shallow foundations supported by well -compacted engineered structural fill is also presented for structures where more risk of potential movement is acceptable. A discussion of alternatives, including detailed design and construction criteria are included in the text of the report. 3. We believe slab -on -grade construction supported by the soil encountered will involve low potential for movement. We recommend structurally supported floors in all finished areas. Detailed design and construction criteria area presented in the text of this report. 4. Subsurface conditions encountered in the soil percolation profile boring (TH-19), at a location indicated by others, consisted of approximately 8 feet of sandy clay, Percolation test results ranged between 20 minutes per inch to time intervals which did not measurably percolate. Groundwater was not identified in the boring to the maximum depths observed. Additional discussion is included in the text of the report. Surface drainage should be designed for rapid runoff of surface water away from the proposed structures. Williams Production Gas Plant No. 3 2 GEG Job No. 2.108 SITE CONDITIONS The subject site was located approximately 4 miles northwest of Parachute, Colorado south of Starkey Gulch and west of County Road 215, Fig. 1. The subject site was located in a northwest and southeast oriented valley bottom. Steeper slopes were noted along the sides of the valley. The subject site was located north and west of an existing gas production facility on vacant, undeveloped land. Low indigenous and non - indigenous vegetation was noted across the site The subject site was gently undulating and generally sloped down toward the southwest at 3 to 6 percent (measured with handheld rangefinder and hand level). Northwest -southeast trending irrigation type risers (dry at the time of our visit) were noted crossing the central portion of the subject site. Smaller gas production structures were noted near the north, east and west portions of the subject site. An earth bermed ditch was noted near the north and east portion of the subject site. The ditch was approximately 15 to 20 feet wide and 5 to 7 feet deep. Water in the ditch was flowing toward the south, An open excavation near the west portion of the subject site was 4 to 10 feet wide, more than 180 feet long and approximately 8 to 12 feet deep. The excavation sidewalls indicated clay type soils. Man Camp Road was southeast of the site; the previously mentioned gas production facility was beyond. Parachute Creek, undeveloped 'land and steeper upslopes of the valley sidewalls were southwest. Undeveloped land was northwest. County Road 215 was north and east of the site with steeper valley sidewalls beyond. The vicinity sloped down toward the valley Williams Production Gas Plant No. 3 3 GEG Job No. 2,108 • • bottom; the valley bottom sloped down toward the southeast at less than 1 percent (USGS Parachute, Colorado Quadrangle, 1962). PROPOSED CONSTRUCTION We understand proposed construction will consist of a gas facility addition. There will be various gas plant related structures. There will be no below grade construction. We understand compressor engine structures will have a relatively low tolerance for movement (on the order of 1/2 inch). We understand deep foundations are desired for support of these structures. The tolerance for differential movement of the remaining structures will be 2 -inches. We understand there be a tank storage area where mat foundations are desired. Shallow spread footing foundations are desired for the remainder of proposed construction. We anticipate relatively light foundation loads of 1,000 to 2,000 pounds per lineal foot of perimeter foundation wall for each structure. We understand that there may be up to approximately 12 feet of site grading cut and fill across the site. There will be no below grade construction. If proposed construction changes or is different from what is stated, we should be contacted to review actual construction and our recommendations. Williams Production Gas Plant No. 3 4 GEG Job No. 2,108 • • • SUBSURFACE CONDITIONS Subsurface conditions at the site were investigated by drilling and sampling nineteen exploratory borings. Locations of the exploratory borings are shown on Fig. 2. Graphic logs of the soils found in the borings and field penetration resistance tests are presented on Figs. 3 through 8. Subsurface conditions encountered included up to 67 of sandy clay underlain by clayey gravel to the maximum depth explored of 8 to 78 feet. Practical drill rig refusal was encountered at 67 feet, using 4 -inch solid stem auger, in exploratory boring TH-2 in the underlying gravels. The sandy clay had clayey gravelly sand and sandy, silty clay lenses, was medium stiff to very stiff, dry to wet and brown. This soil had an appearance of ancient landslide / sheet flow type deposition and sulfates noted. The clayey gravel exhibited substantial drill rig resistance to practical drill rig refusal with 4 -inch solid stem augers. Penetration tests into the gravels indicated dense to very dense, wet material. Groundwater was encountered at 15.5, 26 and 32 feet below the ground surface on the day of drilling in exploratory borings TH-1, TH-2 and TH-16 (respectively). Clay samples tested had moisture contents ranging from 5.3 to 22,6 percent and dry densities from 100 to 119 pcf. Four clay samples were tested for Atterberg limits. These samples exhibited liquid limits of 23 to 32, plasticity indices of 8 to 16 and 59 to 83 percent passing the No. 200 sieve (silt and clay sized particles). Two other clay Williams Production Gas Plant No. 3 5 GEG Job No. 2,108 samples had 51 and 69 percent passing the No. 200 sieve. Nine clay samples were tested for swell consolidation characteristics using a one-dimensional oedometer apparatus. These samples ranged from 0.7 percent consolidation to 5.5 percent swell when wetted under a confining pressure of 250 or 1.000 psf. We do not believe the sample that swelled 5.5 percent is representative of soil generally found on site. Three sand samples were tested. These samples had moisture contents of 7.3 to 14.3 percent and dry densities of 84 to 114 pcf. One sand sample exhibited a liquid limit of 24, plasticity index of 10 and 46 percent passing the No. 200 sieve. Two clayey, gravelly sand samples tested had 11 and 18 percent retained on the No. 4 sieve (gravel sized particles) and 24 and 30 percent passing the No. 200 sieve, Results of laboratory testing are presented on Figs. 9 through 15 and summarized on Table 1. SITE DEVELOPMENT We understand up to approximately 12 feet of cut and fill are proposed across the site. Prior to fill placement, the surface of native soils below fill should be stripped and all organic and deleterious materials completely removed. The surface should be scarified to a depth of 10 inches, moisture conditioned to within 2 percent of optimum moisture content and compacted to at least 95 percent of standard Proctor (ASTM D 698) maximum dry density. On-site soils free of deleterious materials, organics and particles Williams Production Gas Plant No. 3 6 GEG Job No. 2,108 • • over 6 -inches diameter can be reused in non-structural areas during grading. Fill in structural areas may include special requirements as shown later under the "FOUNDATIONS" section of this report. Additional fill placement should be moisture conditioned to within 2 percent of optimum moisture content and compacted to at least 95 percent of standard Proctor (ASTM D 698) maximum dry density in 10 -inch maximum thickness loose lifts. Subgrade soils and fill greater than 15 foot in depth should be moisture conditioned to within 2 percent of maximum dry density and compacted to at least 100 percent maximum dry density standard Proctor (ASTM D698). Subgrade preparation, and placement and compaction of grading fill should be observed and tested by a representative of our firm during construction. Sample site grading specifications are included in Appendix A. FOUNDATIONS This investigation indicates variable, medium stiff to very stiff, sandy clay soils exist at foundation levels. Laboratory test results indicate the sandy clay has relatively low bearing capacity, consolidation potential and expansion potential. We believe a foundation system that is anchored in an underlying competent strata would offer lower movement potential than shallow foundations at the subject site. Driven piling or drilled pier foundations are examples of deep foundations. Drilled pier installation would likely require casing / special installation techniques and be more expensive. We understand Williams Production Gas Plant No. 3 7 GEG Job No. 2,108 the compressor engine structures will have a relatively low tolerance for movement (on the order of 172 inch). We recommend driven pile or drilled pier foundations, embedded in a competent bearing stratum for structures where less potential movement is desired. Depth to competent bearing stratum was variable. We identified a competent stratum at approximately 76 feet in exploratory boring TH-2. A competent bearing stratum was identified at 47 and 42 feet below the ground surface in exploratory borings TH-8 and TH-16 respectively. We believe it would be a prudent measure to locate each structure that requires Tess movement on the same foundation to further mitigate differential movement. For relatively light structures and structures where more risk of potential for movement is acceptable an alternative of shallow foundations (spread footing and mat) bearing on well -compacted structural fill is also presented. The recommended design and construction criteria for driven piles, drilled piers and shallow foundations (spread footing and mat) are presented below in order of decreasing attractiveness. These criteria were developed from analysis of field and laboratory data and our experience. The owner should also consider additional (if any) requirements established by the structural engineer. Williams Production Gas Plant No. 3 8 GEG Job No. 2,108 • Driven Piles 1. Pile material should be steel H sections (HP 10x42 or larger) or concrete filled, closed end, steel pipes (10 -314 -inch O.D., 0.25 -inch thick walled or heavier). Pipe piles are typically used in this area. Tip reinforcement should be provided to reduce pile damage during hard driving. A maximum allowable service stress of 12,000 psi should not be exceeded. Based on our experience, capacities of 50 tons to 75 tons can be developed during driving. The capacity of piles in compression driven as described above will be the structural strength of the piles. 2. We identified a competent bearing strata at a depth of 42 to 76 feet below existing ground surface. We anticipate variable and increased depths to competent bearing stratum across the site. 3. Groups of piles placed closer than three diameters, center to center, should be evaluated to determine their reduced capacity. 4. The pile -driving hammer should be operated at the manufacturer's recommended stroke and speed when the "set" is measured. 5. The contractor should select a driving hammer and cushion combination which is capable of installing selected piles without overstressing the pile. The contractor should submit the pile driving plan and the pile hammer cushion combination to the structural engineer for evaluation of the driving stress in advance of the pile installation. 6. We believe a modulus of subgrade reaction of 50 to 150 psi/in can be used for lateral resistance of pile caps. A plate Toad test can be performed to provide a more direct correlation between site soils and modulus of subgrade reaction. 7 A representative of our office should observe and keep records of penetration resistance, pile lengths and other factors that could affect the performance of the foundation, during driving. Williams Production Gas Plant No. 3 9 GEG .lob No. 2,108 • DRILLED PIER FOUNDATIONS Piers should be designed for a maximum allowable end bearing pressure of 4,000 psf and an allowable skin friction value of 400 psf for the portion of pier in native sandy clay soils. Skin friction should be neglected for the portion of pier within 3 feet of the ground surface. End bearing resistance should be neglected within 5 feet of groundwater. Piers should be designed for a minimum deadload pressure of 500 psf based on pier cross-sectional area. If this deadload cannot be achieved, pier length and bedrock penetration should be increased. The native sandy clay can be assigned a skin friction value of 300 psf for uplift resistance, at least 3 feet below the pier cap. Piers should penetrate at least 4 feet into undisturbed native sandy clay soils and have a total length of at least 15 feet. 4. Piers should be reinforced the full length of the pier with at least two No. 4 Grade 60 reinforcing bars to resist tension in the event of soil movement. Reinforcement should extend into grade beams and foundation walls. 5. Foundation walls and grade beams should be well reinforced; the reinforcement should be designed by a qualified structural engineer. Piers should be carefully cleaned prior to placement of concrete. Groundwater was not encountered at the time of this investigation to the depths investigated. We believe problems associated with pier installation can be significantly reduced by using a "drill and pour" construction procedure; that is, placing concrete immediately after pier holes are drilled, cleaned and inspected. Pumping, tremie placement, vacuum truck or auger cast methods may be required for proper dewatering of the pier holes if water is encountered during drilling. Concrete should not be placed in any pier hole containing more than 3 inches water. Due to recent experience with improper installation, we recommend the use of a contractor with previous drilled pier installation experience. Williams Production Gas Plant. No. 3 10 GEG Job No. 2,108 8. Formation of mushrooms or enlargements at the top of piers should be avoided during pier drilling and subsequent construction operations. 9. Installation of drilled piers should be observed by a representative of our firm to identify the proper bearing strata and confirm proper installation technique. Our representative should be called to visit the site at the time of the first pier excavation and throughout the installation process. Spread Footings- Structures where more risk of movement is acceptable 1 Existing soils should be removed to at least a depth of 2 feet below and 2 feet horizontally beyond footings in each direction and replaced with a well - compacted structural fill. The resulting subgrade should be prepared by scarifying 10 -inches, moisture conditioning to with 2 percent of optimum moisture and compacting to at least 95 percent of standard Proctor (ASTM 0698) maximum dry density. Structural fill soils should consist of well graded sands and gravels with a maximum particle size of 3 -inches, maximum 30 percent passing the No. 200 sieve and maximum liquid limit of 30 percent. A CDOT type Class 5 aggregate base course would meet this criteria and is recommended. A sample of the proposed fill soils should be supplied to our office for acceptance testing, prior to use or import. Additional fill should be moisture conditioned to within 2 percent of optimum moisture content and compacted to at least 95 percent of standard Proctor (ASTM 0698) maximum dry density in 10 -inch maximum loose lifts. 2. Footings bearing on well -compacted structural fill placed as stated above should be designed for a maximum soils bearing pressure of 1,000 psf. Loose soils should be completely removed from foundation bearing areas, prior to placing concrete. 3. We recommend a minimum width of at least 18 -inches for continuous footings. Isolated pads should be at least 36 inches by 36 inches. Foundation walls should be well -reinforced top and bottom. We recommend reinforcement sufficient to span an unsupported distance of at least 15 feet. Reinforcement should be designed by the structural engineer. Williams Production Gas Plant No. 3 11 GEG Job No. 2,108 Exterior walls should be protected from freezing. We understand the normal depth assumed for frost protection in the Garfield County area is 3 feet. The completed foundation excavation should be inspected by our representative for proof roll and to verify the subsurface foundation conditions are as anticipated from our exploratory borings. Geotechnical Engineering Group should also be called to test compaction of subgrade and fill during placement. Mat Foundations — Tank storage areas where more risk of movement is acceptable Mat foundations can be designed for a maximum soils bearing pressure of 500 psf. Loose sods should be completely removed from foundation bearing areas, prior to placing concrete. Existing soils should be removed to at least a depth of 2 feet below and 2 feet horizontally beyond mat in each direction and replaced with a well - compacted structural fill. The resulting subgrade should be prepared by scarifying 10 -inches, moisture conditioning to with 2 percent of optimum moisture and compacting to at least 95 percent of standard Proctor (ASTM D698) maximum dry density. Structural fill soils should consist of well graded sands and gravels with a maximum particle size of 3 -inches, maximum 30 percent passing the No. 200 sieve and maximum liquid limit of 30 percent. A C00T type Class 5 aggregate base course would meet this criteria and is recommended for structures where mitigating potential movement is a concern. A sample of the proposed fill soils should be supplied to our office for acceptance testing, prior to use or import. Additional fill should be moisture conditioned to within 2 percent of optimum moisture content and compacted to at least 95 percent of standard Proctor (ASTM D698) maximum dry density in 10 -inch maximum loose lifts. Mat foundations should be well reinforced, both top and bottom. We recommend reinforcement sufficient to span an unsupported distance of at least 12 feet. Reinforcement should be designed by the structural engineer. Williams Production Gas Plant No. 3 12 GEG Job No. 2,108 4. Foundations should be protected from freezing. The normal depth assumed for frost protection in the Garfield County area is 3 feet. The completed foundation excavation should be observed by our representative to verify subsurface foundation conditions are as anticipated from our borings and to test compaction. FLOOR SYSTEMS The near -surface soils which will support slab -on -grade floors exhibited low to moderate movement potential. Some movement must be assumed. To our knowledge. the only reliable solution to control floor movement is the construction of a structurally supported floor with at least a 12 -inch air space between the floor and subgrade. In our opinion, structural floors should be used in all finished areas. We recommend the following precautions for construction of slabs -on -grade at this site. These precautions will not prevent movement in the event the underlying conditions become wetted, they tend to reduce damage if movement occurs. Slabs should be supported by at least a 1 foot depth of well compacted, structural fill as stated above under the "FOUNDATIONS, Spread Footings" section of this report. The completed subgrade should be scarified 10 -inches depth, moisture conditioned to within 2 percent of optimum moisture content and compacted to at least 95 percent of maximum standard Proctor (ASTM D698) dry density, prior to structural fill placement. A Geotechnical Engineering Group, Inc. representative should be called to visit the site to test compaction and observe soils in the excavation bottom and structural fill. Williams Production Gas Plant No. 3 13 GEG Job No. 2.108 2. Slab -on -grade construction should be limited to unfinished areas and exterior flatwork where practical. 3. Slabs should be separated from exterior walls and interior bearing members with a slip joint which allows for free vertical movement of slabs. 4. The use of slab -bearing partitions should be minimized. Where such partitions are necessary, a slip joint allowing at least 3 inches of free vertical slab movement should be used. Doorways and stairwells should also be designed for this movement. 5. Underslab plumbing should be eliminated where feasible. Where such plumbing is unavoidable, it should be thoroughly pressure tested during construction for leaks and should be provided with flexible couplings. Frequent control joints should be provided to reduce problems associated with shrinkage and curling. The American Concrete Institute (ACI) and Portland Cement Association (PCA) recommend a maximum panel size of 8 to 15 feet depending upon concrete thickness and slump, and the maximum aggregate size. We advocate additional control joints 3 feet off and parallel to grade beams and foundation wails. BELOW -GRADE CONSTRUCTION No below -grade construction is anticipated at this site. Typically, foundation drains are not required for construction of this type. Crawl space areas should be sloped so that potential moisture will not collect in these areas, but flow out of the crawl space. Crawl space areas should also be well ventilated to mitigate potential musty odors. Williams Production Gas Plant No. 3 14 GEG Job No. 2,108 • PERCOLATION TESTING Percolation testing was performed on August 24 and 25, 2005 in percolation holes P-1 through P-3. A profile boring was observed at TH-19. Locations of profile boring TH-19 and P-1 through P-3 are shown on Fig. 2. Three percolation holes were augered to depths of 4 feet below existing grade and prewetted on August 24, 2005. A small drainage (dry at the time of our visit) was noted more than 100 feet southwest of the proposed septic area. No other water sources were identified within 300 feet of the area of the proposed septic system. A log and legend of the soil • percolation profile boring TH-19 is included on Figs. 3 and 4. Results of the percolation testing are included in Figs. 16 through 18. • Subsurface conditions encountered in the profile (TH-19) consisted of 8 feet of sandy clay to the maximum depth explored of 8 feet below the ground surface. Groundwater was not identified in the profile to the maximum depth observed. We estimate a high seasonal groundwater level of 7 feet below the ground surface. Percolation test results ranged between 20 minutes per inch to time intervals which did not measurably percolate. Groundwater was not identified in the boring to the maximum depths observed. Many of the percolation readings were 40 minutes per inch. Williams Production Gas Plant No. 3 15 GEG Job No. 2,108 CONCRETE Sulfate concentrations in this area have been shown to have a negligible to moderate effect on concrete that comes into contact with the soils. We recommend a Type II (sulfate resistant) cement be used for concrete that comes into contact with the subsoils. In addition, concrete should have a maximum water -cement ratio of 0.5. SURFACE DRAINAGE Performance of foundations and concrete flatwork is influenced by surface moisture conditions. Risk of wetting foundation soils can be reduced by carefully planned and maintained surface drainage, Surface drainage should be designed to provide rapid runoff of surface water away from the proposed structures. We recommend the following precautions be observed during construction and maintained at all time after the construction is completed. The ground surface surrounding the exterior of the structures should be sloped to drain away from the additions in all directions, We recommend a slope of at least 12 inches in the first 10 feet around the additions, where possible. In no case should the slope be less than 6 inches in the first 5 feet. The ground surface should be sloped so that water will not pond adjacent to the additions. Backfill around foundation walls should be moistened and compacted. Williams Production Gas Plant No. 3 16 GEG Job No. Z108 • 3. Roof downspouts and drains should discharge well beyond the limits of all backfill. Splash blocks and downspout extenders should be provided at all discharge points. Landscaping should be carefully designed to minimize irrigation. Plants used dose to foundations should be limited to those with low moisture requirements; irrigated grass should not be located within 5 feet of the foundation. Sprinklers should not discharge within 5 feet of foundations. Irrigation should be limited to the minimum amount sufficient to maintain vegetation, application of more water will increase likelihood of slab and foundation movements, 5. Impervious plastic membranes should not be used to cover the ground surface immediately surrounding the structures. These membranes tend to trap moisture and prevent normal evaporation from occurring. Geotextile fabrics can be used to limit the weed growth and allow for evaporation. 4110 CONSTRUCTION MONITORING • Geotechnical Engineering Group, Inc. should be retained to provide general review of construction plans for compliance with our recommendations. Geotechnical Engineering Group, Inc, should be retained to provide construction -monitoring services during all earthwork and foundation construction phases of the work. This is to observe the construction with respect to the geotechnical recommendations, to enable design changes in the event that subsurface conditions differ from those anticipated prior to start of construction and to give the owner a greater degree of confidence that the additions are constructed in accordance with the geotechnical recommendations. Williams Production Gas Plant No. 3 17 GEG Job No. 2,1O$ • LIMITATIONS Nineteen exploratory borings were drilled in the proposed structure areas. The exploratory borings are representative of conditions encountered only at the exact locations. Variations in the subsoil conditions not indicated by the borings are always possible. Our representative should observe driven pile installation and calculate pile capacity during driving, as applicable. Our representative should observe drilled pier installation, open foundation excavations, observe proof roll and test compaction of subgrade and structural fill soils (as applicable) to confirm soils are as anticipated from the borings and foundations are prepared as recommended herein. The scope of work performed is specific to the proposed construction and the client identified by this report. Any other use of the data, recommendations and design parameters (as applicable) provided within this report are not appropriate applications. Other proposed construction and/or reliance by other clients will require project specific review by this firm. Changes in site conditions can occur with time. Changes in standard of practice also occur with time. This report should not be relied upon after a period of three years from the date of this report and is subject to review by this firm in Tight of new information which may periodically become known. Williams Production Gas Plait No. 3 18 GEG Job No. 2,108 • We believe this investigation was conducted in a manner consistent with that level of care and skill ordinarily used by geotechnical engineers practicing in this area at this time. No other warranty, express or implied, is made. If we can be of further service in discussing the contents of this report or the analysis of the influence of the subsurface conditions on the development or design of the proposed construction, please call. Sincerely, GEOTECHNICAL ENGINEERING GROUP, INC. Randall G. Dean Project Geologist ,qQ RECis Reviewed by: r � .� � wItz" ,' ,-, arc 3 15 eP John P. WitheraT' rr �wes.eu ��~�• Principal Enginee _/OP AO,' RGD:JPW:cb (3 copies sent) Williams Production Gas Plant No. 3 19 GEG Job No. 2,108 • • • Geotechnical Investigation Williams Gas Plant No. 3 County Road 215 and Mancamp Road Garfield County, Colorado 711 Subject Site a r ° Marl camp Road r (Locaic,pproxima#e) • 1 J / r7 y 'f t A O p• \ •°�,`r �',� tib, .J r; 'N1�2^,kh '2G7 _Y Job No. 2,108 Vicinity Map Fig. 1 TH-1 • Note: This figure was prepared based on GEG field and in house mapping, and is intended to show exploratory boring locations only. 6TH -2 _ TH - TH 5 TH-13 H-15 j • TH-9 TF -f-4 TH- Anticipated location of proposed structures (typical) TH-16 MN MINI TH-17• TH-18 TH= P-10 • p P-3 0 P-2 Legend • Indicates location of exploratory borings. o Indicates location of percolation testing. Job No. 2,108 Location of Exploratory Borings Fig. 2 TH-1 TH-2 TH-3 TH-4 elev. 5434' elev. 5444' elev. 5442' elev. 5433' 5450 5440 5430 c a C13 ill 5420 0 5410 5390 5380 5370 5/12 6/12 0/12 5/12 Anticipated Plant Finish Grade elev. 5431' & 5440' 20/12 18/12 7/12 8/12 7/12 4/12 Job No. 2108 Logs of Exploratory Borings Fig. 3 Elevation -feet TH-5 elev_ 5441' 5450 5440 — 22/12 5430 8/12 7/12 5420 5410 5400 5390 5380 5370 TH-6 elev. 5432' TH-7 elev. 5433' 8/12 4/12 7/12 TH-8 elev. 5430' Anticipated Plant Finish Grade elev. 5431' & 5440" 19/12 16/12 16/12 6/12 21/12 5450 5440 5430 /-18/12 5420 6/13 ///\ 5410 '` 6/12 5400 5390 5380 50/10 5370 50/10 Job No. 2108 Logs of Exploratory Borings Fig. 4 Elevation -fee TH-9 TH-10 TH-11 TH-12 elev. 5434' elev. 5439' elev. 5442' elev. 5448' 5450 5450 Anticipated Plant Finish Grade elev. 5431' & 5440' 5440 5440 16/12 25112 21112 19/12 5430 21112 11112 8/12 5430 5420 5410 5400 18/12 14112 13/12 8/12 7/12 11/12 5420 5410 5400 Job No. 2108 Logs of Exploratory Borings Fig. 5 Elevation -feet • Elevation -feet • TH-13 elev. 5444' 5450 5440 -- 5430 TH-14 elev. 5443' 5420 5410 5400 5390 5380 5370 19/12 TH-15 elev. 5339' Anticipated Plant Finish Grade elev. 5440' 23112 1211.2 413I12 14/12 6/13 15/12 8/12 8/12 TH-16 elev. 5442' 24/12 8/12 8/12 5450 5440 5430 5420 11/12 5410 29/12 48/12 50/5 Job No. 2108 Logs of Exploratory Borings 5400 5390 5380 5370 Fig. 6 a) C c 0 465 a.) Iw TH-17 TH-18 TH-19 elev. 5436' elev. 5431' elev. 5429' 0 — 5450 5450 5440 1-1)— 5430 Q w- 5420 5410 T- 5400 Job No. 2108 r / 119112 Anticipated Plant Finish Grade elev. 5431' 21112 17/12 7/12 9/12 5440 5430 5420 5410 5400 Logs of Exploratory Borings Fig. 7 Elevation -feet Legend Clay, sandy, Sand, clayey, gravelly and Clay, sandy, silty lenses, medium stiff to very stiff, dry to wet, brown, sulfates noted, possible ancient slide deposits. (CL) Gravel, clayey, dense to very dense, wet. (GC) Indicates drive sample. The symbol 5/12 indicates that 5 blows of a 140 pound hammer falling 30 inches were required to drive a 2.5 inch O.D. sample barrel 12 inches. Indicates bag sample taken from auger cuttings. Indicates free water level. Numeral indicates number of days after drilling that measurement was taken. Indicates depth at which exploratory boring caved. Indicates practical drill rig refusal with augering methods. Boring terminated. Indicates penetration test. The symbol 50/9 indicates that 50 blows of a 140 pound hammer falling 30 inches were required to drive a 2.5 inch 0.0. dynamic cone 9 inches. Elev. Indicates elevation of ground surfaces at test boring location as obtained 5,434 from topographic map provided by Williams Production and is approximate. Notes 1. Exploratory borings were drilled and sampled on August 24 and 25, 2005 using a 4 -inch diameter solid stem, continuous flight auger and a track mounted drill rig. 2. These logs are subject to the explanations, limitations and conclusions as contained in this report. S Job No. 2,108 Legend of Logs of Exploratory Borings Fig. 8 0 0 a 0. W a c 0 3 2 1 0 1 00 02 U 3 2 0 0 C 1 0. x wo 0 3 IlotecIInical Engineering Group, Inc. 0.1 Sample of: Clay, sandy (CL) From: TH-5 @ 9 foot depth 1.0 10 Applied Pressure - KSF Dry Unit Weight=112 PCF Moisture Content= 8.9 % 100 Indicates expansion under pressure due to wetting 0.1 Sample of: Clay, sandy (CO From: TH-7 @ 19 foot depth 1.0 10 Applied Pressure - KSF Dry Unit Weight= 114 PCF Moisture Content= 8.2 % 100 Job No. 2,108 Swell Consolidation Test Results Fig. 9 • Compression % Expansion 3 2 1 0 1 2 3 3 3 IIotechIlical Engineering Group, Inc. I�di tes e • . a 'on.indersxrnstant prestsure due to wett ng 0.1 Sample af: Clay, sandy (CL) From: TH-8 [7a 2 foot depth 1.0 10 Applied Pressure - KSF Dry Unit Weight= 110 PCF Moisture Content= 5.3 % 100 Indicates a spaision under canstaint Pres.ure d e t Wetting 0.1 Sample of: Clay, sandy (CL) From: TH-11 @ 9 foot depth 1.0 10 Applied Pressure - KSF Dry Unit Weight= 119 PCF Moisture Content= 7.5 % 100 Job No. 2,108 Swell Consolidation Test Results Fig. 10 Compression % Expansion Compression % Expansion 3 2 1 0 1 2 3 2 1 0 1 2 3 11 eoteehnical Engineering Group, Inc. Indi tes expansion under pressure due to wetting con start 0.1 Sample of: Clay, sandy (CL) From: TH-10 @ 4 foot depth 1.0 10 Applied Pressure - KSF Dry Unit Weight= 105 PCF Moisture Content= 8.0 % 100 Indi pressure d ue Netting to 0.1 Sample of: Clay, sandy (CL) From: TH-13 @ 14 foot depth 1.0 10 Applied Pressure - KSF Dry Unit Weight= 109 PCF Moisture Content= 26 % 100 Job No. 2,108 Swell Consolidation Test Results Fig. 11 • II 1eotechniea1 Engineering Group, Inc 3 2 D N 1 c co 0_ x w 0 v_ 'F 0. E 2 0 Compression % Expansion 3 2 1 0 1 2 3 4 ad itignal compreIssion pre sure due to wetting unde r 0.1 Sample of. Clay, sandy (CL) From: TH-14 cr 9 foot depth 1.0 10 Applied Pressure - KSF Dry Unit Weight= 114 PCF Moisture Content= 4.5 % 100 Indicates ekpansiOn under constant pressure d4c9 to wetting 0.1 Sample of: Clay, sandy (CL) From: TH-17 @ 9 foot depth 1.0 10 Applied Pressure - KSF Dry Unit Weight= 114 PCF Moisture Content= 5.7 % 100 Job No. 2,108 Swell Consolidation Test Results Fig. 12 • • 7 6 4 3 2 4 5 6 7 8 0.1 Ilheoteehnical Engineering Group, Inc. U n icates expansion )r ssiure due to welt and ng con tan Applied Pressure - KSF Sample of: Clay, sandy (CL) From: TH-17 @ 2 foot depth 1.0 10 Dry Unit Weight= 108 PCF Moisture Content= 8.6 % 100 Job No. 2,108 Swell Consolidation Test Results Fig. 13 rometer Analysis 1 Sieve Analysis Clear Square Openings 25HR 7HR w e Readirups U S S1a dao Se 1e$ 110 45min 15rnll 60nrn 19min 4rnn 1 min 1200 1100 150 130 116 18 14 air 14' 1.5' 3' 5' 6' 8' 100 ° 00 -- _...._ 1 i 1 - -11 1 - 10 I # BO 20 70 i 30 I 414 a4° 30 — 1— # - 7a 20 t { _ r + BO 10 r 90 0 r 1 1E r r L 1 r• ' r-' 1 } 1 1 1 1 111 1 1 r 1 1 r r t r r 1 1 r 1 WI I 1 100 .001 .002 .005 .009 .019 .037 .074 ,149 .297 .590 1.19 2.36 4.76 9.52 19.1 35.1 78.2 127 200 42 2.0 152 Diameter of Particle in Millimeters Clay Plastic to Silt sand gavel (Non -Plastic (Plastic) 1 � Fine 1 Medium l Coarse Fine 1 Coarse i Cobbles Sampleof: From: Sand, clayey, gravelly (SC) TH-11 @ 19 feet Gravel: 11 % Sand: 65 % Silt & Clay: 24 % Liquid Limit: Plasticity Index: 1 �y'� m eler lirlalysks 1 -. Sieve Analysis 1 25HR 45mn ,°a 7HR Te a ReacFn s , 5min 60min 19mn dnt n l min 1200 U.S. Standard banes 110 Clear Square Openi'19! 1100 150 130 116 18 14 3,8" 314" 1 5' r 5" 6- 8' ° 90 1 ! T 1 i 10 80 l } 20 70 30 1 °- 50 1 50 cr � l I i 80 30 9 1 t I 11 } 70 20 I I 80 10 1 I I 0 1 L I r r 1 , 1 1 1 1 1 1 - I 1 11 I I 140 i e r 1 100.. 001 .002 .005 .009 .019 037 .074 149 297 42 590 1.19 22.38 4.76 9 52 19.1 38,1 78,2 127200 Dierneler of Panicle in MIllimeters Clay(Plastic)to Silt sand Graver l 1 - (Non -Plastic) Fine 1 Medium 1 Coarsei=lrie 1 Coarse 1 Cobbles Sample From: of: Sand, clayey, gravelly (SC) Gravel: 18 % Sand: 52 % TH-15 @ 4 feet Silt & Clay: 30 % Liquid Limit: Plasticity Index: Gradation Test Results Job Na. 2,108 Geotechnical Cgineering Grvnp, 11nc. Date: November, 2005 Fig. 14 lameter Analysis _ Sieve Analysis 25HR 7HR Readings U.S. Standard Series#10 Clear Square Openings 45ndn 15min 60min 19m1n 4min 1 min 1200 #100 #50 #30 #16 18 14 318" 314' 1.5" 3' 5" 6' 6" 1000 i - 1 90 1 1 10 60 1 20 7 — I 30 tl 6tS 1 ..---i s . i -- 40 0 , t ---a. - 50 1_ 60 i 1 3-_ 0 1 70 9 20 - 1 { 80 10 90 0 — - [ 1 1 1 1 1 1 1 1 1 r 1 I t 1 1 -11 Y 1 11 1 1 1 1 1 1 E 1 1 - 1 1 1 1 1 1 7 9 111 1 100 .001 .002 .005 .009 .019 .037 .074 .149 .297 .590 1.19 2.38 4.76 9.52 19.1 36.1 76.2 127 200 .42 2.0 152 Diameter of article In Millimeters to Silt Sand Gravel (Plastic) (Non -Plastic) Fine IMedm 1 Coarse Fine I Coarse e I Cobbles Sample From: of: Clay, sandy, gravelly (CL) TH-16 @ 29 feet Gravel: 13 % Sand: 36 % Silt & Clay: 51 % Liquid Limit: Plasticity index: 1 Hydrometer Analysis 1 Sieve Analysis 1 25HR 100 7HR Time Readings 15min 60n1in 19min 4min lmin #200 U S. Standard Series *19 Square Openings #4045min #100 #50 130 116 18 14 318" 314" 1.5" 3" 5'8` 8' 0 90 .. 1 I 1 1 10 80 _ I I i 20 70 C i - 30 i I i I I 40 10 CL� _ 50 Et g g 60 X40 30 l C I I ! a 70 20 I i i 30 10 I i i 90 0 , 1 + 1 i1 r 1 r 1 1 1 T 1 1 1 1 L,LIE 1 J E r r f 1 1 1 ''Ii- 100 .001 .002 .005 .009 .019 .037 .074 .149 .297 .590 1.19 2.38 4.76 9.52 19.1 36.1 762 127 200 .42 2.0 152 Diameter of Particle in Millimeters Clay(Plastic) to Silt(Non-Plastic) sand cam Fine 1 Medium i Coarse Fine 1 Coarse 1 Cobbles Sample From: of: Gravel: % Sand: % Silt & Clay: % Liquid Limit: Plasticity Index: Gradation Test Results Job No. 2,108 Geotechnieall Engincerin I�,Graap, Inc. Date: November, 2005 Fig. 15 Geotechnical IIEugi aeering Group, hie. SATURATION AND PREPARATION DATE: August 24, 2005 TIME AT START OF SATURATION: 11:30 PERCOLATION TEST DATE: August 25, 2005 WATER IN BORINGS AFTER SATURATION Depth to Water YES X NO PERCOLATION TEST RESULTS HOLE NUMBER 8" Diameter DEPTH (INCHES) TIME AT START OF INTERVAL TIME INTERVAL (MINUTES) DEPTH TO WATER CHANGE IN WATER DEPTH (INCHES) PERCOLATION 1 RATE (MIN/INCH) START OF END OF INTERVAL INTERVAL (INCHES) (INCHES) P-1 @ 0' 4" DIA 48" 11:01 10 33.25 33.5 0.25 40 48" 11:11 10 33.5 34.0 0.5 20 48" 11:21 10 34.0 34.25 0.25 40 48" 11:31 10 34.25 34.25 0.0 00 48" 11:41 10 34.25 34.5 0.25 40 48" 11:51 10 34.5 34.75 0.25 40 * Note * «° : indicates did not percolate during this interval. Job No. 2,108 Fig. 16 • • Geoterk Iea1 I k,Eagi.eerwg Group, Inc. SATURATION AND PREPARATION DATE: August 24, 2005 TIME AT START OF SATURATION: 11:40 PERCOLATION TEST DATE: August 25, 2005 WATER IN BORINGS AFTER SATURATION Depth to Water YES NO PERCOLATION TEST RESULTS HOLE NUMBER 8" Diameter DEPTH (INCHES) TIME AT START OF INTERVAL TIME INTERVAL (MINUTES) DEPTH TO WATER CHANGE IN WATER DEPTH (INCHES) PERCOLATION RATE (MIN/INCH) START OF END OF INTERVAL INTERVAL (INCHES) (INCHES) P-2 @ 0° 4" DIA 48" 11:02 10 33.25 33.5 0.25 40 48" 11:12 10 33.5 33.75 0.25 40 48" 11:22 10 33.75 34.0 0.25 40 48" 11:32 10 34.0 34.25 0.25 40 48" 11:42 10 34.25 34.5 0.25 40 48" 11:52 10 34.5 34.75 0.25 40 Job No. 2,108 Fig. 17 Geoteelhoieni IhkEngineering (,roup, Ine. SATURATION AND PREPARATION DATE: August 24, 2005 TIME AT START OF SATURATION: 11:50 PERCOLATION TEST DATE: August 25, 2005 WATER IN BORINGS AFTER SATURATION Depth to Water YES A I NO PERCOLATION TEST RESULTS HOLE NUMBER 8° Diameter DEPTH (INCHES) TIME AT START OF INTERVAL TIME INTERVAL (MINUTES) PEPTH TO WATER CHANGE IN WATER DEPTH (INCHES) PERCOLATION RATE (MIN/INCH) START OF END OF INTERVAL INTERVAL (INCHES) (INCHES) P-3 © 0' 4" DIA 48" 11:03 10 30.25 30.75 0.5 20 48" 11:13 10 - 30.75 31.0 0.25 40 48" 11:23 10 31.0 31.0 0.0 00 48" 11:33 10 31.0 31.25 0.25 40 48" 11:43 10 31.25 31.5 0.25 40 48" 11:53 10 31.5 31.5 0.0 CO * Note * co : indicates did not percolate during this interval. el Job No. 2,108 Fig. 18 • Geotecbniral iEngineering �Group, Inc. • TABLET SUMMARY OF LABORATORY TEST RESULTS • JOB NO. 2,108 HOLE DEPTH (FEET) NATURAL MOISTURE (%) DRY 1 DENSITY (PCF) Atterberg Limits Swell / Consolidation PASSING NO. 200 SIEVE (%) WATER SOLUBLE SULFATES (ppm) SOL TYPE LIQUID LIMIT (%) PLASTICITY INDEX (%o) SWELL (%) CONFINING PRESSURE (PSF) TH-1 2 20.8 107 32 16 79 Clay, sandy (CL) 9 17.9 107 a Clay, sandy (CL) 14 20.8 105 - - Clay, sandy (CL) 24_ 22.6 100 Clay, sandy (CL) TH-2 9 Laborato Testing in Progress TH-3 4 6.8 119 Clay, sandy (CL) 9 Laboratory Testing in Progress 14 20.2 106 28 15 83 - Clay, sandy, silty (CL) TH-4 4 11.5 102 - Clay, sandy (CL) TH-5 9 8.9 112 +1.6 1,000 Clay, sandy (CL) TH-6 2 13.6 107 Clay, sandy (CL) 9 22.4 103 Clay, sandy (CL) TH-7 4 Laboratory Testin9in Progress 19 8.2 114 - +0.6 1,000 Clay, sandy (CL) TH-8 2 5.3 109 +0.6 250 Clay, sandy (CL) TH-9 2 7.5 Clay, sandy (CL) TH-10 4 8.0 105 +0.2 250 Clay, sandy (CL) 9 8.2 113 Clay, sandy (CL) 19 16.2 111 Clay, sandy (CL) 1 29 19.8 96 23 8 66 Clay,. sandy, silty (CL) Page 1 of 2 • GeoteehniraI II Engineering Group, Inc. • TABLE 1 SUMMARY OF LABORATORY TEST RESULTS • JOB NO. 2,108 HOLE DEPTH (FEET) NATURAL MOISTURE (%) DRY DENSITY (PCF) Atterberg Limits Swell 1 Consolidation PASSING NO. 200 SIEVE (%) WATER SOLUBLE SULFATES (ppm) SOIL TYPE LIQUID LIMIT (%) PLASTICITY INDEX (%) SWELL 4%) CONFINING PRESSURE (PSF) TH-11 9 7.6 119 +1.2 1,000 Clay, sandy (CL) 19 9.1 103 24 Sand, clayey, gravelly (SC) TH-12 9 12.8 111 Clay, sandy (CL) TH-13 9 Laboratory Testing in progress - - 14 26.0 109 +0.4 1,000 Clay, sandy (CL) TH-14 9 4.5 114 -0.7 1,000 Clay, sandy_(CL) TH-15 4 7.3 84 - - - - - 30 Sand, clayey, gravellykSQ) TH-16 19 14.3 114 24 10 46 Sand, clayey (SC) 29 14.7 115 51 Clay, sandy, gravelly (CL) TH-17 2 8.6 108 +5.5 250 - - Clay, sandy (CL) 9 5.7 114 ! +0.5 1,000 Clay, sandy (CL) TH-18 4 Laboratory Testing in Progress 9 10.9 107 26 12 59 Clay, sandy, silty (CL) 14 16.4 107 69 Clay, sandy (CL) Page 2 of 2 APPENDIX A SAMPLE SITE GRADING SPECIFICATIONS • SAMPLE SITE GRADING SPECIFICATIONS Williams Production, Gas Plant No. 3 Addition County Road 215, South of Starkey Gulch Garfield County, Colorado GEG Job No. 2,108 1. DESCRIPTION This item shall consist of the excavation, transportation, placement and compaction of materials from locations indicated on the plans, or staked by the Engineer, as necessary to achieve preliminary street and overlot elevations. These specifications shall also apply to compaction of excess cut materials that may be placed outside of the subdivision and/or filing boundaries. 2. GENERAL The Soils Engineer shall be the Owner's representative. The Soils Engineer shall approve fill materials, method of placement, moisture contents and percent compaction, and shall give written approval of the completed fill. 3. CLEARING JOB SITE The Contractor shall remove all trees. brush, and rubbish before excavation or fill placement is begun. The Contractor shall dispose of the cleared material to provide the Owner with a clean, neat appearing job site. Cleared material shall not be placed in areas to receive fill or where the material will support structures of any kind, 4. SCARIFYING AREA TO BE FILLED All topsoil and vegetable matter shall be removed from the ground surface upon which fill is to be placed. The surface shall then be plowed or scarified until the surface is free from ruts, hummocks or other uneven features, which would prevent uniform compaction by the equipment to be used. 5. COMPACTING AREA TO BE FILLED After the foundation for the fill has been cleared and scarified, it shall be disked or bladed until it is free from large clods, brought to the proper moisture Job No. 2,108 Fig. A-1 • • • content (within 2 percent above or below optimum) and compacted to not less than 95 percent of maximum density as determined in accordance with ASTM D 698. If soft/ yielding subgrade conditions are encountered, stabilization may be required. 6. FILL MATERIALS Fill soils shall be free from vegetable matter or other deleterious substances, and shall not contain rocks or lumps having a diameter greater than six (6) inches. Fill materials shall be obtained from cut areas shown on the plans or staked in the field by the Engineer. On-site materials classifying as CL, SC, SM, SW, SP, GP, GC and GM are acceptable. Concrete, asphalt, organic matter and other deleterious materials or debris shall not be used as fill. 7. MOISTURE CONTENT Fill materials shall be moisture treated to within 2 ± percent of optimum moisture content as determined from Proctor compaction tests. Sufficient laboratory compaction tests shall be made to determine the optimum moisture content for thee various soils encountered in borrow areas. The Contractor may be required to add moisture to the excavation materials in the borrow area if, in the opinion of the Soils Engineer, it is not possible to obtain uniform moisture content by adding water on the fill surface. The Contractor may be required to rake or disk the fill soils to provide uniform moisture content through the soils. The application of water to embankment materials shall be made with any type of watering equipment approved by the Soils Engineer, which will give the desired results. Water jets from the spreader shall not be directed at the embankment with such force that fill materials are washed out. Should too much water be added to any part of the fill, such that the material is too wet to permit the desired compaction from being obtained, rolling and all work on that section of the fill shall be delayed until the material has been allowed to dry to the required moisture content. The Contractor will be permitted to rework wet material in an approved manner to hasten its drying. 8. COMPACTION OF FILL AREAS Selected fill material shall be placed and mixed in evenly spread layers. After each fill layer has been placed, it shall be uniformly compacted to not less than the specified percentage of maximum density. Expansive soils classifying as Job No. 2,108 Fig. A-2 • • • CL or SC shall be compacted to at least 95 percent of the maximum dry density as determined in accordance with ASTM D 698 (100 percent for fill deeper than 15 feet below final grade). At the option of the Soils Engineer, soils classifying as SW, SP, GP, GC or GM may be compacted to 90 percent of the maximum density as determined in accordance with ASTM D 1557 (95 percent for fill deeper than 15 feet below final grade). Fill materials shall be placed such that the thickness of loose material does not exceed 10 inches and the compacted lift thickness does not exceed 6 inches. Compaction, as specified above, shall be obtained by the use of sheepsfoot rollers, multiple -wheel pneumatic -tired rollers, or other equipment approved by the Engineer for soils classifying as CL or SC. Granular fill shall be compacted using vibratory equipment or other equipment approved by the Soils Engineer. Compaction shall be accomplished while the fill material is at the specified moisture content. Compaction of each layer shall be continuous over the entire area. Compaction equipment shall make sufficient trips to insure that the required density is obtained. 9. COMPACTION OF SLOPES Fill slopes shall be compacted by means of sheepsfoot rollers or other suitable equipment. Compaction operations shall be continued until slopes are stable, but not too dense for planting, and there is no appreciable amount of loose soil on the slopes. Compaction of slopes may be done progressively in increments of three to five feet (3' to 5') in height or after the fill is brought to its total height. Permanent fill slopes shall not exceed 3:1 (horizontal to vertical). 10. DENSITY TESTS Field density tests shall be made by the Soils Engineer at locations and depths of his choosing. Where sheepsfoot rollers are used, the soil may be disturbed to a depth of several inches. Density tests shall be taken in compacted material below the disturbed surface. When density tests indicate that the density or moisture content of any layer of fill or portion thereof is below that required, the particular layer or portion shall be reworked until the required density or moisture content has been achieved. 11. COMPLETED PRELIMINARY GRADES All areas, both cut and fill, shall be finished to a level surface and shall meet the following limits of construction: A. Overlot cut or fill areas shall be within plus or minus 2110 of one foot. Job No. 2,108 Fig. A-3 B. Street grading shall be within plus or minus 1/10 of one foot. The civil engineer, or duly authorized representative, shall check all cut and fill areas to observe that the work is in accordance with the above limits. 12. SUPERVISION AND CONSTRUCTION STAKING Observation by the Soils Engineer shall be continuous during the placement of fill and compaction operations so that he can declare that the fill was placed in general conformance with specifications. All inspections necessary to test the placement of fill and observe compaction operations will be at the expense of the Owner. All construction staking will be provided by the Civil Engineer or his duly authorized representative. Initial and final grading staking shall be at the expense of the owner. The replacement of grade stakes through construction shall be at the expense of the contractor. 13. SEASONAL LIMITS No fill material shall be placed, spread or rolled while it is frozen, thawing, or during unfavorable weather conditions. When work is interrupted by heavy precipitation, fill operations shall not be resumed until the Soils Engineer indicates that the moisture content and density of previously placed materials are as specified. 14. NOTICE REGARDING START OF GRADING The contractor shall submit notification to the Soils Engineer and Owner advising them of the start of grading operations at least three (3) days in advance of the starting date. Notification shall also be submitted at least 3 days in advance of any resumption dates when grading operations have been stopped for any reason other than adverse weather conditions. 15. REPORTING OF FIELD DENSITY TESTS Density tests made by the Soils Engineer, as specified under "Density Tests" above, shall be submitted progressively to the Owner. Dry density, moisture content, of each test taken and percentage compaction shall be reported for each test taken. Job No. 2,108 Fig. A-4 • 16. DECLARATION REGARDING COMPLETED FILL • The Soils Engineer shall provide a written declaration stating that the site was filled with acceptable materials, or was placed in general accordance with the specifications. 17. DECLARATION REGARDING COMPLETED GRADE ELEVATIONS A registered Civil Engineer or licensed Land Surveyor shall provide a declaration stating that the site grading has been completed and resulting elevations are in general conformance with the accepted detailed development plan. Job No. 2,108 Fig. A-5 • • • PvCMI Land Planning Division 1038 County Road 323 Rifle, CO 81650 Ph. 970-625-5350 Fax 970-625-4522 Email: pvcm@direcway.com Project: Williams Production RMT Co.- Parachute Creek Gas Plant Expansion Phase 3 Submittal. Item Number: 11,1.0 Impacts on Wildlife Colorado Division of Wildlife- We had an on-site meeting on August 30, 2004 regarding the Phase 2 expansion with J.T. Romatzke with the CDOW regarding the project. In general, Mr. Romatzke agreed wih the 8' tall chainlink fence installation at the perimeter of the plant site.. We have attempted to make contact with J.T. Romatzke and Dean Riggs with the CDOW over the last 2 months regarding our Phase 3 expansion but have not been able to because of the hunting seasons. Over the last year, Dave Cesark- Principal Environmental Specialist for Williams Production RMT Co. has been meeting with J.T. Romatske to review the Wildlife Enhancement projects, Operation Game Thief and wildlife corridor issues that Williams Production RMT Co. has been addressing. Williams Production RMT Co. is "Partners in the Field" with the Colorado Division of Wildlife and has provided Williams Production RMT Co. owned lands and training facilities for a Youth Mule Deer Hunt held in Fall 2004 and a Ladies Turkey Hunt held in Spring 2005. Williams Production RMT Co. has also donated funds to Wildlife for the Future and the Mesa Land Trust over the past years to protect wildlife habitat and big game migration corridors Williams Production RMT Co. contracted with Dr. Kirk Beattie of Rifle for a 5 year mule deer study to assess impacts of natural gas development upon the mule deer population. Dr. Beattie is currently in the 4th year of the study and according to the latest report there has been "no significant difference in deer density" between the test and control area and "Qualitative observations suggest that mule deer are attracted to forage on reclaimed well pads." Page 1 of 2 • • • Williams Production RMT Co. is spearheading a natural gas industry coalition of Northwest Colorado operators in conjunction with the U.S. Bureau of Land Management, Colorado Division of Wildlife and the U.S. Fish and Wildlife Service to develop a Wildlife Protection Plan with the goal of having this plan adopted by area producers. The first coalition meeting was held in Meeker, CO within the last quarter and there is currently a working draft plan that is being reviewed by the coalition partners. All of the efforts noted above that have been put forth by Williams Production RMT Co. have been voluntary and not required by governmental agencies. This 1,333 acre parcel enables Williams Production RMT Co. to partner with the Colorado Division of Wildlife to make enhancements for wildlife. Please also find attached an article regarding Williams Production RMT Co., Principal Environmental Specialist, Dave Cesark's efforts in cooperation with the Colorado Division of Wildlife. Dave Cesark and CDOW have worked together to produce a Wildlife Enhancement Plan on neighboring Williams Production RMT Co. property that will aid in protection of riparian areas, reduce overgrazing, removing noxious weeds and will improve habitat for mule deer, native wild turkey and rainbow and brown trout. Williams Production RMT Co. has been coordinating with the CDOW in regards to Operation Gamethief by doubling the reward given to citizens who identify wildlife poachers. Williams Production RMT Co. agrees to install a new 8' tall chainlink fence to surround the Phase 3 plant expansion. This is the same requirement that CDOW made on Phase 1 and Phase 2 of the project. Please contact me with any questions. Sincerely, Philip B. Vaughan President PVCME Page 2 of 2 • • Williams works to turn producing M property into productive wildlife habitat When Dave Cesark envisions the 1,400 acres of land Williams owns and develops for natural gas in the Parachute Creek Valley of western Colorado, he sees hundreds of mule deer, thriving alfalfa fields and pristine creeks. The principal environmental spe- cialist for Exploration & Production's office in Parachute is leading a proj- ect not just to protect the lands where we operate some 20 natural gas wells, but to enhance the prop- erty for wildlife's sake. "We want to turn this place into a mecca for wildlife; Dave says of the Williams -owned acreage. It will be rewarding down the road to see how it develops and improves over the years and how the wildlife pop- ulation continues to grow and thrive on the property. That's when we'll be able to look back and feel like we've accomplished something." Working closely with Colorado's Division of Wildlife, Williams start- ed what Dave calls the Wildlife Habitat Enhancement Plan for the property about a year ago. When Williams acquired the land in 2001, it had been overgrazed by cattle and was in need of work to get it in shape to support a mix of wildlife ranging from native wild turkey and mule deer to rainbow and brown trout. With the help of a property manag- er possessing expertise in wildlife biology and range management, the project began with a years worth of work that included taking wildlife inventories, producing accu- rate maps of the area, recording wildlife observations and consider- ing potential management options. What lies ahead is a list of priori- ties to improve the land over the next five years. Plans include implementing a livestock grazing management program, installing fencing to protect the riparian area, removing noxious weeds, seeding to improve alfalfa growth, planting an acre's worth of cotton- wood trees and equipping existing Mule deer congregate on Williams -owned land in the Parachute Creek Valley of western Colorado. Working closely with Colorado's Division of Wildlife. Williams began a Wildlife Habitat Enhancement Plan for the property about a year ago to improve the mule deer population. Dave Cesark stands in front of a beaver pond on Williams -owned property in Parachute Creek Valley where he's leading a Wildlife Habitat Enhancement Plan. trees with wire wrappings to pro- tect them from beaver damage. As an added benefit, the Division of Wildlife plans to use the land as a training ground for its youth hunting program beginning this spring. The division also is in the process of forming a formal part- nership with Williams to provide oversight on the project. As a community leader, Dave says the company recognizes the importance of going above and beyond the regulatory require- ments to be good environmental stewards of the land. Not only is Williams the largest taxpayer and employer in Garfield County, but it also is committed to raising the bar for protecting our lands for generations to come. "It's important not only to reclaim the lands we use, but to make them better than they were before," Dave says. `This project is a perfect example of us trying to do just that:' o CDOW Needs Your Help to Stop Poaching of Wildlife W:II:ams1 .REWARD POT of $4,000 The Colorado Division of Wildlife is asking for help with recent big game poaching incidents that have occurred along Rio Blanco County Road 5 in the Pieeance Creek Basin area located between Rifle and Meeker. Sometime around October 9 -10, 2005, several deer and elk were shot and left to waste on private lands directly off of Rio Blanco County Road 5. The CDOW is asking for your help to solve this wildlife poaching investigation. If anyone has any information regarding these big game poaching incidents, please call the Meeker CDOW Office at 970-878-6090 or call the Operation Game Thief hotline toll-free at 1 -877 -COLO -OGT (1-877-2656-648). The CDOW's Operation Game Thief program in cooperation with Williams Energy is offering a total pot of $4,000 to be split between anyone that provides key information which leads to arrest(s) or citation(s) being issued for this big dane poaching incident. Colorado's Operation Game Thief (OGT) program ays cash rewards to people that provide information about wildlife violations. Callers may remain anonymous and do not have to testify in court. Please help stop poaching because Colorado's wildlife belongs to you! PVCM.I Land Planning Division 1038 County Road 323 Rifle, CO 81650 Ph. 970-625-5350 Fax 970-625-4522 Email: pvcm@direcway.com Project: Williams Production RMT Co.- Parachute Creek Gas Plant Expansion- Phase 3 Submittal Item Number: 11.1.D Impacts of Truck and Automobile Traffic Garfield County Road & Bridge Department- I met Jake Mall on September 13, 2005 at the intersection of County Road #215 and Man Camp Road. There is an existing Garfield County Access permit for the intersection. The attached map at Exhibit 5 dated 1118105 by Construction Surveys details the existing conditions of the intersection and the accel/deeal lanes up -valley and down -valley from this intersection. Installation of additional signage and improvements regarding striping of the acceleration and deceleration lanes on County Road #215 occurred in Spring 2005 and were paid for by Williams Production RMT Co. Please find attached a detailed traffic analysis prepared by Felsberg, Holt and Ullevig dated 11/10/05. Traffic counts were taken visually on-site over 2- 24 hour periods. The traffic analysis considers the existing and proposed level of service at the Mancamp Road/County Road #215 intersection is a Level of Service A. Please contact me with any questions. Sincerely, Philip B. Vaughan NI President PVCM1 Page I of 1 • Pa FELSBURG HOLT & ULLEVIG engineering paths to transportation solutions November 10, 2005 Mr. Phil Vaughan Phil Vaughan Construction Management, Inc. 1038 County Road 323 Rifle, Colorado 81650 RE: Williams Production RMT Company Parachute Creek Gas Plant Expansion — Phase 3 Garfield County, Colorado FHU Project # 05-221 Dear Mr. Vaughan: We have prepared a traffic impact analysis for the proposed Phase 3 Expansion of the Parachute Creek Gas Plant in Garfield County, Colorado. A traffic study for the Phase 2 Expansion was completed by FHU in August of 2004. The traffic count procedures and methodologies used in that study were also utilized for the completion of this study. Williams Production RMT Company is proposing to increase the full time employment by seventeen FTEs, from the current 20 to 37 in the future. The new facility will be constructed to the northwest of Mancamp Road, on the opposite side of the road from the existing facility. It is anticipated that the new employees will be concentrated at this new facility. The number of trucks that load at the plant will increase by 13, from the current 18 to a total of 31 in the future. All trucks will use the existing load -out facility on the southeast side of Mancamp Road. Our analyses are based on the traffic count data that was compiled for two 24 hour periods. The following is our analysis of potential traffic impacts that might result from this proposed expansion. EXISTING TRAFFIC Turning movement volumes were manually counted for a total of two days and were summarized in 15 minute periods. These counts were taken at seven intersections that serve various areas of the existing gas plant. The count program included the intersection of CR 215 and Mancamp Road as well as six intersections on Mancamp Road (five serve the gas plant and the other is the Well Access Road). These counts were taken from 6:00 am on October 25, 2005 to 6:00 am on October 26, 2005. Counts were also taken from 6:00 am on October 27, 2005 to 6:00 am on October 28, 2005. The resulting daily volumes for these two 24-hour counts are shown in Figure 1. These counts specifically surveyed the access points that serve the gas plant and show that there were a total of 463 vehicles per day (vpd) on October 25-26 going into or out of the gas plant. Trucks comprised 52 of these daily vehicles (11%). On October 27-28, there were a total 4111 of 425 vpd with 85 vpd being trucks (20%), 6300 South Syracuse Way, Suite 600 Centennial, CO 80111 tel 303.721.1440 fax 303.721.0832 www.fhueng.com info@fhueng.com • • • November 10, 2005 Mr. Phil Vaughan Page 2 The 15 -minute data for both of the days were reviewed to determine the through the day. The following peak hour periods were used: • The morning peak hour occurred between 7:00 am and 8:00 am. peak hour turning movement volumes are shown in Figure 2. • A mid-day peak hour occurred between 11:00 am and 12:00 am. peak hour turning movement volumes are shown in Figure 3. • The evening peak hour occurred between 5:00 pm and 6:00 pm. peak hour turning movement volumes are shown in Figure 4. pattern of peak hours The resulting morning The resulting mid-day The resulting evening Operational analyses of the existing intersections and driveways were performed according to the techniques documented in the Highway Capacity Manual 2000, by the Transportation Research Board (TRB), 2000. The result of such an analysis is a level of service (LOS) rating, which is a qualitative assessment of the traffic flow based on the average stopped delay per vehicle at a controlled intersection. Levels of service are described by a letter designation ranging from "A" to "F", with LOS A representing essentially uninterrupted flow, and LOS F representing a breakdown of traffic flow with excessive congestion and delay. The results of this analysis shows that morning, mid-day, and evening peak hour volumes at all of the analyzed intersections/driveways currently operate at LOS A (see Figures 2, 3, and 4). S1TE-GENERATED TRAFFIC The Parachute Creek Gas Plant is a unique land use, and detailed traffic counts that were collected in the field provide ample information on which to base future traffic forecasts. The forecasts of future traffic (see Table 1) are based on the following methodology: • Future daily and hourly volumes are based on an average of the two count periods. • Truck traffic related to the site is assumed to increase in proportion to the forecast of future trucks serving the site. All truck volumes were multiplied by a factor of 1.72. This is the ratio between 27 trucks in the future and 20 currently. • Automobile traffic related to the site is assumed to increase in proportion to the forecast of future employees working at the site. All automobile volumes were multiplied by a factor of 1.85. This is the ratio between 37 full time employees in the future and 20 currently. • November 10, 2005 Mr. Phil Vaughan Page 3 Table 1 Trip Generation Analysis Total Volume (Truck Volume) The results of this analysis show that there will be about 815 trips per day with the proposed expansion of the gas plan with between 49 and 95 trips occurring during the three peak hours. Truck traffic will represent approximately 15% of the total traffic in the future, about the same as the current truck proportions. BACKGROUND TRAFFIC GROWTH In addition to the expansion of the gas plant, it was assumed that general growth in the county will result in corresponding growth in background (unrelated to the project) traffic volumes. A growth rate of 4% per year was assumed for this analysis. This is higher than the approximate 3% growth rate in population for Garfield County that is forecasted by the State of Colorado Demography Office over the next 30 years. Background traffic growth was assumed to occur over the next 20 year — through 2025. TOTAL TRAFFIC AND LEVELS OF SERVICE Figures were prepared showing the average daily and peak hour traffic volumes that were forecasted for 2025. These figures are as follows: • Figure 5 — 2025 Total Daily Traffic Volumes • Figure 6 — 2025 Morning Peak Hour Traffic Volumes • Figure 7 — 2025 Mid -Day Peak Hour Traffic Volumes • Figure 8 — 2025 Evening Peak Hour Traffic Volumes Level of service analyses were also completed for the project intersections/driveways for each of the three peak periods. Figures 6, 7, and 8 show that all of the intersections and driveways will continue to operate at LOS B or better over the next 20 years. CONCLUSION The results of the level of service analyses show that there will not be any traffic operational concerns, and all intersections and driveways will operate well (LOS B). Daily Morning Peak Hour Mid -Day Peak Hour Evening Peak Hour Current 10/24 - 25/05 463 (52) 61(16) 25 (2) 35 (6) 10/27 - 28/05 425 (85) 42 (3) 42 (15) 19 (6) Average 444 (69) 52 (10) 34 (9) 27 (6) Future 813 (119) _95 (17) 61 (15) 49 (10) The results of this analysis show that there will be about 815 trips per day with the proposed expansion of the gas plan with between 49 and 95 trips occurring during the three peak hours. Truck traffic will represent approximately 15% of the total traffic in the future, about the same as the current truck proportions. BACKGROUND TRAFFIC GROWTH In addition to the expansion of the gas plant, it was assumed that general growth in the county will result in corresponding growth in background (unrelated to the project) traffic volumes. A growth rate of 4% per year was assumed for this analysis. This is higher than the approximate 3% growth rate in population for Garfield County that is forecasted by the State of Colorado Demography Office over the next 30 years. Background traffic growth was assumed to occur over the next 20 year — through 2025. TOTAL TRAFFIC AND LEVELS OF SERVICE Figures were prepared showing the average daily and peak hour traffic volumes that were forecasted for 2025. These figures are as follows: • Figure 5 — 2025 Total Daily Traffic Volumes • Figure 6 — 2025 Morning Peak Hour Traffic Volumes • Figure 7 — 2025 Mid -Day Peak Hour Traffic Volumes • Figure 8 — 2025 Evening Peak Hour Traffic Volumes Level of service analyses were also completed for the project intersections/driveways for each of the three peak periods. Figures 6, 7, and 8 show that all of the intersections and driveways will continue to operate at LOS B or better over the next 20 years. CONCLUSION The results of the level of service analyses show that there will not be any traffic operational concerns, and all intersections and driveways will operate well (LOS B). November 10, 2005 Mr. Phil Vaughan Page 4 Please calf if you have any questions or need additional information. Sincerely, FELSBURG HOLTofi.„,,,f & ULLEV1G ��,�.\\i„„„„,!„„„1/44,,fff i �-,i. „.. „..,„lo 1 ,r fit. .,. David E. Hattan, P.E. - i ° ** Associate Ul .o if ;,+I.,:` ,i•'••• .,nL 0^�,....^?. /f i* /// �� Fffiliti0\-- FELSBURG HOLT & ULLEVIG North LEGEND 462(75) 564(135) 256(47) CR 215 4— 299(49) 501(65) 560(130) —' 44(8) 29(5) C7? 0) W N @ O \\N N s? CJ N co 0) CO 0A r �p Ch c0 -+ V 0 :A W 68(9) 60(13) 26(3) 4— 37(6) L. 0) CJ1.73 L� 23(0) T 17(3) 5(0) 5(0) —4 r.� w 1 v m w o� w O w 431N G1 67 m rn ■ ))`i Pa CO N rD N CF1 t 44(1) 42(4) 17(0) r- 12(0) W t T P1 p)o N o Office Building ■ 140(11) = Tota( Daily Turning Movements 10/24-25!05 (Truck Volume) 123(7) Total Daily Turning Movements 10/27-28/05 (Truck. Volume) xxxx xxxx Total Two -Way Daily Volume (Truck Volume) Figure 1 Daily Volumes Parachute Creek Gas Plant Expansion 04-073 1119105 PFELSBURG HOLT & ULLEV1G • North CF12 1 5 26(0) 24(4) 4(0) 37(4) 25(2) 39(1) N ov u.,.n -16 1; 7(3) 3(0) 6(2) 5(0) >-- ala so 0 1 3(1) 3(0) 5(0) ,– r- 3(0) N ra Office Building a/a —411 1? -->j LEGEND 3(0) 2(1) 1(0) 0(0) O 0 O co O so a O 140(11) = Hourly Turning Movements 10/24-05/05 (Truck Volume) 123(7) = Hourly Turning Movements 10127-28105 (Truck Voiurne) xfx = 8112-13-041 8/16-17/04 Peak Hour [Jnsignalized Levels of Service Stop Sign Figure 2 Morning Peak Hour Parachute Creels Gas Plaril Expansion 04-073 1116105 North FELSBURG HOLT &>_ ULLEVIG CR 215 39(6) 42(16) 9(2) 17(7) 41(10) '— 39(17) 3(1) 2(2) - a 0 t 5(0) 5(0) 0(0) 4 1(0) AQ 0 0 Office Building LEGEND olQj �ro1 400 A6 O `Oag/ O V 140(11) = Hourly Turning Movements 10/24-05/05 (Truck Volume) 123(7) = Hourly Turning Movements 10/27-28/05 (Truck Volume) xlx - 8/12-13-04 / 8/16-17/04 Peak Hour Unsignalized Levels of Service 1 Stop Sign Figure 3 Mid -Day Peak Hour ParaChuie Creek Gas PIan1 Expansron 04073 1119105 FELSBIJRG HOLT Sr. ULLEVIG North CR 215 69(11) 58(4) 4(3) 3(0) 27(5) 26 5) 12 5) 11(1) ala or— _ 12(2) 10(3) 3(0) 0(0) (dt sloLiv o w a w m o0aw,2 o(p1 qi` (()) 9(0) 0(0) 111 0(0) N 1,3 %u } Office Building � a ▪ o of p1i 0 (0 0 LEGEND 140(11) = Hourly Turning Movements 10/24-05/05 (Truck Volume) 123(7) = Hourly Turning Movements 10/27-28/05 (Truck Volume) x/x = 8/12-13-04 1$116-17/04 Peak Hour Unsignalized Levels of Service = Stop Sign O Truck Load Out Figure 4 Afternoon Peak Hour Pareonuie Creek Gas Plant Expansion 0A 073 11r9I05 NI FELSBURG �A HOLT Si. ULLEVIG North .-1 124(105) CR 215 579(69) 1163(100)--r 86(11)- Ir Ch mw `.) rn LEGEND XXX(XXX) = Daily Volume (Truck Volume) = Total Two -Way Average Daily Traffic Volume (Truck Volume) XXX(XXX) f--64(11) s 32(5) r7R 0) CO A ▪ tSs 'I_ 44(3) 114 15(0) tr 01- v— o 0) W office Building Figure 5 2025 Daily Volumes Parachute Creek Gas Pliant Expansion O4-0]3 11I1Ofls • FELSBURG (41 1-1OLT ULLEVIG North CR 215 55(2)—,- 4(0)-4 5(2)—:4(0)-i .— 85(8) k 70(6) U7 A Q� LEGEND 2,1co --6373 i1 t3(1) 40) 8(0 1 5(0)-4, Ar O O� O W cn na hI32 i L 0(0)0 FO Office Building Truck Loan Out XXX(XXx) = Total Hourly Volume (Truck Volume) x = Unsignalized Level of Service i = Stop Sign Figure 6 2025 Morning Peak Hour Parachute Creek Gas Plant txpansuan 04.073 11/10/05 IP IRFELSBURG HOLT (Si. ULLEVIG North +— 41(11) CR 215 � 25(8) aa()- ► 4(2(2)—+ flS z N GJ CO N W O t 6(1) 11 s 1(1) tr' N43 L}i^N p�- Office Building LEGEND xxx(xxx) = Total Hourly Volume (Truck Volume) = Unsignalized Level of Service = Stop Sign Figure 7 2025 Mid -Day Peak Hour Parachute Creek Gas Pfanl Expansion 04.073 11/10+05 FELSBURG HOLT & GLLEVIG • North CR 215 4-27(5) 22 (5) 64(8)—w- 4(0)-4, 0 4(8)—Y4(0)- 0 CO o" I as CI, 0-3 N 0 TO l 3() 3(0) tr 4(0) 1(0) LEGEND 0(0) rh- wr, „ Office Building Truck Load Out XXX(XXX) = Total Hourly Volume (Truck Volume) x = Unsignalized'Level of Service Stop Sign Figure 8 2025 PM Peak Hour Parachute Creak Gas Plant Expansion 04.073 Ile10105 • • • PVCMI Land Planning Division 1038 County Road 323 Rifle, CO 81650 Ph. 970-625-5350 Fax 970-625-4522 Email: pvcm@direcway.com Project: Williams Production RMT Co.- Parachute Creek Gas Plant Expansion Phase 3 Submittal Item Number: 11.1.E Distances from Abutting Property Please refer to Submittal #6- Vicinity Map. The Parachute Creek Gas Plant Expansion is abutted to the North by Puckett Land Co., to the East by Mobil Oil Corp. to the Southeast by EnCana Oil & Gas and American Soda and the Southwest by BLM and Puckett Land Co. All of the nearest adjacent uses are industrial. The distance to the nearest BLM corner from the existing Parachute Creek Gas Plant boundary is approximately 3,000 lineal feet (.57 miles). The Parachute Creek Gas Plant Expansion is within a 1,333 acre parcel owned by Williams Production RMT Co, that aids in buffering the plant. The existing industrial uses adjacent also help to buffer this use. Please contact me with any questions. Sincerely, Philip B. Vaughan President PVCMI Page 1 of 1 • • PVCNI Land Planning Division 1038 County Road 323 Rifle, CO 81650 Ph. 970-625-5350 Fax 970-625-4522 Email: pvcm@direcway.com Project: Williams Production RMT Co.- Parachute Creek Gas Plant Expansion Phase 3 Submittal Item Number: 11.2.A. Site Rehabilitation Plan Please find attached a Site Rehabilitation Plan that has been utilized for the existing Parachute Creek Gas Plant SUP Application and has been revised and items have been added below as per comments from Steve Anthony. An inventory of noxious weeds was completed for the riparian area consisting of approximately 100 acres within the 1,333 -acre parcel owned by Williams Production RMT Co. This was completed as part of the Parachute Creek Wildlife Enhancement Project. 2.3 acres of tamarisk was identified and was eradicated in Spring 2004. Additionally, hounds tongue and various thistles were identified and eradicated. Steve Anthony and I discussed that a reclamation bond will be required by Garfield County for the new plant site totaling approximately 11 acres of surface disturbance. Please note that the above and attached information presented discusses a carefully implemented plan for mitigation of impacts caused by the Parachute Creek Gas Plant. The majority of these mitigation strategies are currently in-place in the existing Parachute Creek Gas Plant and will be extended to the expansion. Please contact me with any questions. Sincerely, Philip B. aughan President PVCM1 Page I of 1 SITE REHABILITATION PLAN PARACHUTE CREEK GAS PLANT EXPANSION- PHASE3 AisThe Parachute Creek Gas Plant Expansion (Plant Expansion) will be located on rangeland owned by Williams Production 111PMT Company (Williams). The Plant Expansion area is 11.18 acres and is immediately adjacent to the existing Parachute Creek Gas Plant phases 1 and 2. The subject site appears to lie in the Villa Grove soil series. The Villa Grove series consists of deep, weld-drained soils that formed in alluvium derived from sandstone, shale, or basalt. The soil should be stripped to a depth of approximately twelve (12) inches and stockpiled at the facility margins. The maximum depth of stockpiled shall be 24' or less to preserve soil viability. Topsoil stockpiles will be seeded as described below in the section on seeding methods and times. RECLAMATION Two phases of reclamation are planned. Soil stockpiles and areas disturbed by construction that will not be utilized during Plant Expansion operation will be reclaimed immediately following Plant Expansion construction. Final reclamation will be performed within one year of Plant Expansion closure and removal. The objectives of reclamation will be as follows: • 1. Stabilization of the disturbed areas will be conducted by providing wind and water erosion control to reduce soil loss. 2. Utilize the prescribed seed mixtures and additional vegetation practices as described below to establish a self- sustaining vegetative rangeland cover for cattle pasture use. FACILITY AND STRUCTURE REMOVAL The Plant Expansion will be abandoned in accordance with Colorado Oil and Gas Conservation Commission regulations in place at the time of facility abandonment. Equipment will be removed from the site. BACKFILUNG, GRADING, AND RE -CONTOURING Reclaimed areas will be sloped to 3:1 or less. • fare 1 of 3 TOPSOIL REPLACEMENT Soil salvaged during Plant Expansion construction activities will be redistributed over the soil surface after subsoil has Oen replaced and additional backfilling; grading, and re -contouring steps have been completed as described below. Soil will be replaced by using front-end loaders, trackhoes, and dozers. Soil will not be replaced when it is excessively wet and frozen so as to jeopardize soil structure. SEEDBED PREPARATION/SOIL TILLAGE Seedbed preparation and soil tillage will be completed after the application of subsoil, topsoil, and any soil amendments. Soil tillage will be to a minimum depth of 4' utilizing a disk, chisel plow, or harrow. Seedbed preparation will also include removal of coarse fragments (rock material) that exceed 35% to 40% of the soil surface as well as rocks 8' in diameter that occupy more than 10% of the soil surface. SEEDING METHODS AND TIMES Soil stockpiles and areas disturbed by construction that will not be utilized during Plant Expansion operation will be seeded. If seeding is performed in the spring, it will be accomplished by May 15; if fall seeding is performed it will be completed after August 30 and before the soil freezes. Seeding efforts will consist of drill seeding with a rangeland drill to a planting depth of W to 1/2' on slopes a1 or flatter. Broadcast seeding followed by harrowing or hand raking to Tightly *over the seed with soil will be used on slopes steeper than 3:1, or on areas inaccessible for drill seeding equipment. All areas to be reclaimed will be mulched no later than 24 hours after seeding with a certified weed -free straw or grass hay material. Grass hay mulch will be applied at 1 % tons per acre, or straw mulch will be applied at 2 tons per acre, Mulch material will be crimped into the soil surface with a commercial mulch crimper, a straight disc, or bulldozer tracks if too steep to otherwise crimp mulch In place. SEED MIXTURES Please see Table 1 for the seed mixtures. WEED CONTROL, PLAN A qualified person will inspect the Plant Expansion area and will inventory and map the proposed project area for any listed Garfield County noxious weeds. Based on this inventory and mapping, methods, materials, and timing of weed control measures will be specified. The vast majority of the Plant Expansion area will be graveled and will be devoid of vegetation. Williams Production RMT Co. reserves the right to modify this plan based an Best Available Technology eiBAT) at the time of plant closure. Page2of3 TABLE 1 Stockpile and Disturbed Areas Reclamation Common Name Scientific Name Pounds Pure Uve Seed (PLS) per acre Western wheatgrass Pascopyrum smithii 8.0 Sporobolus airoides TOTAL PLS 8.0 TABLE 2 Final Reclamation Seed Mixture Common Name Scientific Name Pounds Pure Uve Seed (PLS) per acre Alkali Sacaton Sporobolus airoides 1.0 Sideoats Grama Bouteloua curtpendula 2.0 Basin Wildrye ILeymus cinereas 2.0 Westem wheatgrass Pascopyrum smithii 4.0 TOTAL PLS 9.0 Page 3 of 3 • • • PVCMI Land Planning Division 1038 County Road 323 Rifle, CO 81650 Ph. 970-625-5350 Fax 970-625-4522 Email: ovcm@direcway.com Project: Williams Production RMT Co.- Parachute Creek Gas Plant Expansion- Phase 3 Submittal Item Number: 12- Supplementary Regulations 5.03.08 (5) Please find below and attached requirements met as per the Garfield County Supplemental Regulations. 5.03.08 (5)A. Storage of flammable or explosive solids or gases. On September 20, 2005 a meeting was held with David Blair of the Grand Valley Fire Protection District (GVFPD) at Parachute Creek Gas Plant Site, The items noted below were discussed during our meeting regarding fire protection issues at the Parachute Creek Gas Plant. Plant Safety Systems and Plant Design Plant spacing is designed as to minimize impact of fire and allow unobstructed access for outside fire fighting equipment (i.e. trucks). NGL storage tanks are set back from county road 215 as per NFPA spacing requirements. Plant safety systems include gas and fire detection, which either shuts down or isolates specific equipment and/or plant when activated. Emergency flare system is designed per API 520, 521, to insure adequate emergency flaring. The Control Room monitors the plant 24 hours per day, 7 days per week. This Control Room is set back from the process as per NFPA spacing requirements. Fire extinguishers are located throughout the plant, so plant personnel can fight incipient stage fires. Loading Rack and Thick Drivers Truck drivers are given a safety briefing / safety orientation when they arrive to haul there first Toad from our plant. Also, for new drivers one of our plant personnel goes to the loading rack with the driver to discuss the loading process. Page 1 of 4 Truck drivers must check-in at the office by signing in, at which time they are given a loading ticket. They then travel to the loading rack and hook-up. Once they have achieved a proper ground, the control room receives a signal and allows loading to begin. Safety equipment at the loading rack includes breakaway valves which shutdown the flow of liquid in the event of a line problem. Also, an Emergency Shut Down (ESD) button is located near the rack, which shuts down the loading process in the event of an emergency when manually activated. Fire Training Fire extinguisher training is provided to Williams employees on an annual basis. Emergency Response Plan The current emergency response plan (ERP) will be updated to include the plant expansion and will be reviewed with the GVFPD. A copy is also available via the Local Emergency Planning Committee (LEPC). Please find a copy of the Emergency Response Plan dated April 2005. Perimeter access for GVFPD will be provided and clearance under piperacks at certain locations for vehicle crossings will be provided. A gate in the Westernmost plant chainlink fence will be provided for emergency access to the new flare. Fire Department Walk -Through A walk-through will be scheduled with the GVFPD prior to the plant expansion start up. 5.03.08 (5)B. Enclosures As described in the Wildlife Impact submittal 1 1.1.C. Williams Production RMT Co. will be installing an 8' tall chainlink fence around the new plant expansion perimeter to keep wildlife out of the plant and for plant. security. No further berating or plantings have been planned for the site as the adjacent parcels are industrial uses. Berming or screening from Garfield County Road #215 would be ineffective because of the lower grade of the plant as compared to the higher grade of road #215. Page 2 of 4 5.03.08 (5)C. Materials or wastes transferred off -property. Vapor, dust, smoke, noise, glare and vibration have been addressed in 11.1.B in the application. The Construction stormwater management plan and the Spill Prevention Control and Countermeasure Plan have been addressed in 11.1.A in the application. As a part of the Williams Production RMT Co. safety regulations, notation is made to securing all loose materials and trash so that these items are not lifted by strong winds and subsequently provide a safety hazard or trash concerns off-site. This issue will be noted to all contractors and employees on-site. Any trash items inadvertently allowed to blow off-site will be pickud-up by Williams Production. In addition, the perimeter chainlink fence will aid in this effort. 5.03.08 (5)D. Storage or heavy equipment With the exception of construction of the plant expansion, 1 backhoe will be on-site on a permanent basis. 5.03.08 (5)E. Storage Area Sizing- Not applicable. 5.03.08 (5)F. Lighting. As per Garfield County Regulations and COGCC rule 803, site lighting shall be pointed downward and inward to the property center and shaded to prevent direct reflection on adjacent property. This regulation will be followed on all site lighting. Page 3 of 4 5.03.08 (6) Water Pollution Please see submittals in 11.1.A.1 SWMP and 11.1.A.2 SPCC. Please note that the above and attached information presented discusses a carefully implemented plan for mitigation of impacts caused by the Parachute Creek Gas Plant. These mitigation strategies are currently in- place in the existing Parachute Creek Gas Plant and will be extended to the expansion. Please contact me with any questions. Sincerely, Philip B. Vaughan President P VCMI Page 4 of 4 • EMERGENCY RESPONSE PLAN • • PARACHUTE CREEK GAS PLANT GARFIELD COUNTY, COLORADO LATITUDE OF FACILITY: N39° 29' 13" LONGITUDE OF FACILITY: W108° 6' 31" REVISION DATE: April 2005 TABLE OF CONTENTS Section Page No. 1.0 INTRODUCTION 1 1.1 Purpose of the Emergency Response Plan ............................... 1 1.2 Legal Authority 1 Table 1. Regulatory Compliance Matrix 2 1.3 Assumptions and Situations 3 1.4 Facility Health and Safety Policy 4 1.5 Response Team and Personnel Responsibilities 4 1.6 Plan Update Procedures and Revisions 6 1.7 Plan Distribution 6 0 FACILITY HAZARD AND RISK ANALYSIS 7 2.1 Overview of the Facility 7 2.2 Facility Risk Evaluation 7 2.3 Offsite Risk Evaluation 7 3.0 PREVENTION 8 3.1 General Prevention Policy 8 3.2 Fire Prevention Policy 8 3.3 Facility Safety Inspections and Audits ...................................... 8 4.0 PREPAREDNESS 9 4.1 Training 9 4.2 Drills and Exercises 9 4.3 Facilities, Supplies, and Equipment 10 4.4 Facility Security 10 4.5 Media Relations Policy I0 5.0 DETECTION AND NOTIFICATION PROCEDURES 11 5.1 Incident Discovery 11 5.2 Emergency Notification 11 5.3 Emergency Alerting Procedures 11 5.4 Evacuation and Personnel Accountability 1 I 5.5 Regulatory Notifications 11 6.0 INCIDENT HANDLING PROCEDURES 12 6.1 Fires and Explosions 12 6.2 Hazardous Material Releases 12 6.3 Medical Emergency 13 6.4 Severe Weather Incidents 13 6.5 Transportation Accidents 13 6.6 Vandalism or Sabotage 14 6.7 Bomb Threats 14 Bomb Threat Checklist 15 7.0 FACILITY SHUTDOWN GUIDELINES 16 7.1 Emergency Shutdown Procedures ............................ 16 8.0 TERMINATING THE EMERGENCY 17 8.1 Recovery of Operations 17 8.2 Documentation 17 8.3 Damage Assessment 17 8.4 Post -Emergency Activites 17 APPENDICES • I. ContactlPersonnel List IL Emergency Action Site Plan III. Emergency Contacts IV. On Site Emergency Response Equipment V. Facility Personnel Responsibilities VI. Chronological Record of Emergency VII. Emergency Drill Form VIM Critique and Follow-up Response IX. Emergency Response Plan Review Record X. Registration Form • EMERGENCY RESPONSE PLAN Revised: Summer 04' 1.0 INTRODUCTIION 1.1 Purpose of the Emergency Response Plan 1.2 Legal Authority This Emergency Response Plan (ERP) is specific to the Parachute Creek Gas Plant, owned and operated by Williams Production RMT Company (WPC). This document is designed to provide for the safety and welfare of facility personnel, the community, the environment, and property by enabling a coordinated and efficient response by WPC personnel in the event of an emergency. When the words WPC personnel are used in this plan, they are intended to mean all WPC employees and contractors. This ERP includes details to: • make the facility and immediate surrounding area safe (people first, then property and environment); • isolate the area/facility; • notify appropriate public agencies; • identify evacuation routes, fire extinguishing equipment, and meeting locations with the facility plot plan; • establish procedures for personnel who remain to maintain critical operations until they evacuate; • establish emergency escape procedures; identify medical and rescue responsibilities for trained employees; • establish methods for reporting fires and other emergency events; • provide primary and alternate meeting locations for employees and contractors after evacuation; • provide labor, materials, and equipment; • establish and maintain adequate communication with governmental agencies (fire, police, public officials, etc.) and clarify their responsibilities; • identify emergency shutdown procedures for affected equipment; • handle hazardous substances; • establish an off-site media center; and • return the facility to service. The intent of this ERP is to comply with guidelines set forth by the Occupational Safety and Health Administration (OSHA). The Emergency Planning and Response Regulations of 29 CFR 1910.38 and Hazardous Waste Operations and Emergency Response (HAZWOPER) Standards of 29 CFR 1910.120 have been specifically followed when applicable. Page 1 • • • EMERGENCY RESPONSE PLAN Revised: Summer 04' Table 1. Regulatory Compliance Matrix. REGULATORY SUBJECT REGULATORY CITATION LOCATION IN WPC PLAN OSHA Emergency Response Program 29 CFR 1910.120 Pre -emergency planning and coordination with outside parties. (p)(8)(ii)(A) Section 1 Personnel roles, lines of authority, training, and communication. (p)(8)(ii)(B) Sections 1.4- 1.5, 4.4- 4.5, 5.2 Appendix V Emergency recognition and prevention. (p)(8)(ii)(C) Sections 2 & 3 Safe distances and places of refuge. (p)(8)(ii)(D) Appendix III & Section 6.2 Site security and control. (p)(8)(ii)(E) Section 4.4 Evacuation routes and procedures. (p)(8)(i)(F) Section 7 & Appendix 111 Decontamination procedures. (p)(8)(ii)(G) Section 8 Emergency medical treatment and first aid. (p)(8)(ii)(H) Section 6.3 Emergency alerting and response procedures. (p)(8)(ii)(I) Section 5 & 7.1 Critique of response and follow- up. (p)(8)(ii)(J) Section 8.2 & Appendix VIII PPE and emergency equipment. (p)(8)(ii)(K) Section 4.1 Page 2 EMERGENCY RESPONSE PLAN Revised: Summer 04' • 1.3 Assumptions and Situations • • The procedures outlined in this ERP were developed under the assumption that the local fire protection and emergency response agencies will respond to emergencies at the facility when notified and will assist to the extent of their respective capabilities. The procedures outlined in this document are to be followed when responding to any of a number of events. These event include, but are not Limited to the following: • Natural disasters and severe weather conditions including: floods - damaging storms earthquakes weather extremes (cold, blizzards, heat) lightning and wildfires • Disruption to normal operations: -Hazardouse material/chemical releases from stationary or mobile sources - unscheduled valve closure or safety equipment shutdown, or any unscheduled emergency shutdown - major accidents involving WPC vehicles or equipment owned by contractors - bomb threats -threats against employees or WPC facilities - fatalities or multiple hospitalizations involving employees or members of the public -disturbances on WPC property - damage to WPC property which interferes with the performance of normal business - disruption of service to customers (scheduled and unscheduled) • Catastrophic Failure and Damage: - major fires - major environmental release - significant destruction of facilities The ERP also provides procedures for communications with employees,. governmental agencies, and the public during emergencies to assure an effective response during an emergency situation. Page 3 EMERGENCY RESPONSE PLAN Revised: Summer 04' 1.4 Facility Health and Safety Policy This ERP is a reflection of the WPC health and safety policies and procedures. When the facility, or a portion of the facility, is involved in an emergency event, WPC personnel shall take the appropriate action to safeguard human life, protect WPC and surrounding property, and maintain or restore operations if possible. Field personnel must immediately communicate information about any emergency event to their immediate supervisor. The supervisor will immediately initiate the appropriate notification procedure. In the event that the supervisor cannot be reached immediately, field personnel will initiate necessary notifications. 1.5 Response Team and The response team is an organized management group established to Personnel respond to an emergency and should be comprised of personnel assigned Responsibilities to perform the following functions (an individual may perform multiple functions, due to the size of the facility and typical staffing levels): See Appendix V. • The Incident Commander is responsible for managing the emergency event, and will coordinate the following activities: - Establish a command post, assemble the response team and assign team member responsibilities; - Assess priorities - safety first, mitigation second; - Account for Location of all personnel who were in the area/facility at the start of the emergency; -Implement the Emergency Response Plan; -Provide on-site supervision of response activities; -Assess and deploy needed resources and coordinate activities; -Serve as or provide for an emergency event safety officer, responsible to prevent injuries and/or death; - Maintain communications with the Plant Superintendent and the Safety Engineer throughout the response; - Coordinate activities of and respond to outside agencies; - Coordinate response to initial contacts with local press and government agencies; -Return the facility back to normal service; - Complete alI reports associated with the emergency event; - Conduct an investigation to determine the root cause of the event and develop corrective actions to prevent recurrence. • The Incident Commander is any employee with operational responsibility (a supervisor, foreman, manager, plant operator, etc.) who has received training in emergency response. The Incident Page 4 EMERGENCY RESPONSE PLAN Revised: Summer 04' Commander must: • have access to this ERP • immediately initiate procedures in the ERP and notify the immediate supervisor. • gather information on the emergency event • implement actions to mitigate the emergency and coordinate and document all telephone calls, conversations, pressures, etc. pertinent to the emergency event until relieved of the responsibility by a higher level of management. • The Logistics Officer obtains necessary response equipment and material to support emergency and mitigation procedures. • The Adrninistration/Fnance Coordinator arranges for humanitarian assistance, lodging, meals, etc. and manages purchase orders, contacts, etc. • The On -Site Safety Officer ensures site, public, and employee safety, establishes the site safety plan, coordinates environmental response, maintains proper communication with local, state, and federal emergency response organizations, or other agencies as necessary. • The On -Site Coordinator/Operations Chief is responsible for oversight and management of site activities. • The Planning Officer coordinates contractors and additional company personnel as necessary. If informed of an emergency event by a private citizen, WPC personnel will obtain as much detail as possible and call a designated field employee to investigate the status. Employees at or near the scene will respond to the emergency immediately. • The Safety Engineer will communicate reportable incidents by telephone to appropriate regulatory agencies as soon as possible. The first employee to detect or to be notified of an emergency event has the responsibility to: • activate an Emergency Shutdown (ESD) if warranted • notify emergency personnel • notify the Incident Commander. If the designated Incident Commander is not available, contact the Alternate Incident Commander. • initiate procedures outlined in the ERP • initiate defensive measures to control the emergency event. If these measures can be done safely, and then only if the employee has been trained in emergency response or has completed Page 5 EMERGENCY RESPONSE PLAN Revised: Summer 04' Hazardous Waste Operations and Emergency Response (HAZWOPER) operations level training. -If the first employee has not completed emergency response training, including appropriate HAZWOPER training he/she shall not initiate defensive measures, but shall complete notification procedures, Area/facility Personnel are responsible to provide initial response and containment of the emergency. They shall: • take appropriate actions to guarantee public, employee, equipment and environmental safety • have completed emergency response training, including a minimum HAZWOPER incident command and technician level training (if expected to respond offensively, e.g., to stop a hazardous materials release or perform as an incident commander). 1.6 Plan Update This ERP should be considered a controlled document and treated Procedures and accordingly. The Safety Engineer is responsible for revising and Revisions updating the ERP on a regular basis. 1.7 Plan Distribution This document is the property of the Williams Production RMT Company (WPC). Controlled copies shall be distributed at a minimum to the WPC personnel in Appendix 1 and to various government agencies for the response coordination. All recipients of this Plan must complete and return the Receipt Form (See Appendix X) to WPC. This action is necessary to acknowledge receipt of the Plan and to register the document for future updates and change distributions. Page 6 • • • EMERGENCY RESPONSE PLAN Revised: Summer 04' 2.0 FACILITY HAZARD AND RISK ANALYSIS 2.1 Overview of the Facility The Parachute Creek Gas Plant is a natural gas conditioning facility owned and operated by Williams Production RMT Company. In general, the major equipment at the site includes heat exchangers, condensers, boilers, coolers, filters, heaters, separators, contactors, dehydrators, scrubbers, natural gas compressor engines, and pumps. Additionally, storage tanks for new and used chemicals and for natural gas liquids (NGL's) and produced water are located onsite. The overall facility process involves receiving gas from area gathering systems and sending it into two separate processes where water, natural gas liquids, and carbon dioxide (CO2) are removed. The design capacity of the facility is 400,000,000 standard cubic feet of natural gas per day (400 MIVISCFD). The water and natural gas liquids are transported offsite by truck, while the carbon dioxide is sold to Solvay and partially vented to atmosphere. This facility operates 24 hours per day, 365 days per year with two or more employees. 2.2 Facility Risk Evaluation A natural gas processing facility is inherently vulnerable to risk due to the constant presence of flammable or combustible materials. Fire or explosions caused by accidents or improper procedures is a serious threat to life, property and the environment and is considered to be the greatest risk at the Parachute Creek Gas Plant. Following proper safety guidelines and adhering to safe -work practices can mitigate this risk. 23 Offsite Risk Evaluation The Parachute Creek Gas Plant is a semi -remote facility with several other industrial or municipal structures near the plant property. The surrounding area is used for livestock grazing and natural gas exploration, production, processing, and transportation. As such, there exists a risk of impact or influence to the facility from offsite sources. Page 7 • • EMERGENCY RESPONSE PLAN Revised: Summer 04' 3.0 PREVENTION 3.1 General Prevention Policy Incidents at the facility will be minimized through personnel training, regular safety inspections, and implementation of the policies and procedures outlined in this ERP and the WPC safety program. The primary responsibility for prevention of emergency incidents is placed on facility operations personnel. Any substantial change or addition to facility equipment or process will necessitate a review of safety procedures and a revision of applicable procedures in this ERP. 3.2 Fire Prevention Policy Please refer to the Safety Manual for information concerning fire prevention. This is available from the Safety Engineer or PSM coordinator at The Parachute Creek facility and on the Intranet at http://intranet. wi 11 iams.comiepssfEHS/safetyrnanual.doc. 3.3 Facility Safety Inspections and Audits Periodic safety audits along with regular operations and maintenance routines will be carried out with the intent of identifying and minimizing potential safety hazards and poor housekeeping practices. Page 8 EMERGENCY RESPONSE PLAN Revised: Summer 04' 4.0 PREPAREDNESS 4.1 Training The Plant Superintendent or the Safety Engineer will make certain that this ERP is reviewed with all new employees during their orientation (or first week of employment), and with all employees on an annual basis. At the time of orientation it will be made clear that at a minimum, the Personal Protective Equipment (PPE) required at the Parachute Creek Gas Plant includes a hard hat, steel -toe shoes, Fire Resistant Clothing (FRC's) and ear protection and safety glasses in posted areas. Training will cover the proper use of PPE for general work and specific tasks at the plant. Documentation of the individual employee review is required for verification of training. All records of training should be kept up to date. Each employee identified in the ERP shall be current on emergency response training that shall include the appropriate level of HAZWOPER training. Training shall cover the follow i ng; • responses for specific roles in various ER scenarios; • the use of appropriate communication systems and alternate communication methods when the plant system is disabled; • organizing and actively taking part in a response team drill; • how to locate isolation valves/shutdown controls; • how to respond to specific failures; • how to respond to media questions; • how to interact with public officials; • where to meet in the event roads to the station are impassable and/ or communications are unavailable; • appropriate control, containment, and clean-up procedures; 4.2 Drills and Exercises The Safety Engineer will schedule an annual facility drill to assess the effectiveness of the ERP and associated procedures. The drill shall consist of an emergency scenario that exercises various procedures described in the ERP. At the completion of the drill, a review shall be performed and documented. If necessary, the ERP will be revised to correct any deficiencies noted during the review. The drills, activities and review comments should be recorded on the Facility Personnel Responsibilities form provided in. Appendix VII, and kept on file for three years. Page 9 • • EMERGENCY RESPONSE PLAN Revised: Summer 04' 4.3 Facilities, Supplies, and Equipment 4.4 Facility Security 4.5 Media Relations Policy Equipment and supplies to be used in the event of an emergency shall be stored at the facility or carried in field vehicles (if appropriate). Emergency fire equipment will be maintained and located as described in the Fire Prevention portion of the Safety Manual under section 2.5. (http:/(intranet.williams.comlepssfEHS/safetymanual.doc). Spill or release response materials should be stored in a protected location and replenished immediately after they are used. All emergency equipment should be inspected frequently and deficiencies corrected immediately. Upon receipt of this ERP, Facility Operations Personnel should complete the list of equipment provided in Appendix IV. Operations personnel control general security during regular duties. The plant is a fenced facility with specific access points. The electronic and motor control systems are within the facility's property boundaries and not generally accessible to unauthorized personnel. During an emergency, the Incident Commander will control security. Access to the site will be restricted to individuals involved in specific emergency response procedures. Local taw enforcement may be contacted if needed to secure the facility and immediate surroundings. In the event of an emergency, a designated spokesperson (who receives periodic media training) at the site will handle initial communications with the public and the media. The designated spokesperson may give the media a brief outline of known facts at the scene; subsequent responses will be coordinated through the WPC Corporate Office. In addition, the designated supervisor, and only that person (usually the Plant Superintendent or the District Manager) who has had media training shall speak to the media or the public about the emergency event. If reporters arrive, the designated supervisor should check their credentials to confirm that they are reporters, assign someone to escort them to the site and keep them within safe areas. Page 10 • • • EMERGENCY RESPONSE PLAN Revised: Summer 04' 5.0 DETECTION AND NOTIFICATION PROCEDURES 5.1 Incident Discovery The facility operates with the assistance of automated control devices that will shut down various systems when abnormal conditions are detected. There are also facility -wide detection and alarm systems in place at the Parachute Creek Gas Plant to aid operations personnel with incident discovery. 5.2 Emergency Notification Upon discovery of an emergency by operations personnel, the Plant Superintendent and Safety Engineer should be notified. Contact information is provided in Appendix I. 5.3 Emergency Alerting Procedures In the event of an emergency, the Site Safety Officer (See section 1.5) will alert any personnel at the site or near the facility of the emergency. 5.4 Evacuation and Personnel shall evacuate in a safe, prompt manner, following an Personnel appropriate evacuation route. Evacuation routes are indicated on the Accountability Emergency Action Site Plan in Appendix II. Upon evacuation of the facility, personnel shall proceed to the designated assembly area. Personnel and any visitors to the site at the time of the emergency will be accounted for when evacuation is complete by checking the site visitor logs, personnel shift schedules, and by questioning all individuals present. 53 Regulatory Notifications Reporting of incidents to regulatory agencies will be the responsibility of the Safety Engineer and the Principal Environmental Specialist. In the event of an emergency, the Safety Engineer and/or Principal Environmental Specialist will determine which agencies should be notified and provide information to the proper representatives. The Spill Prevention Control and Countermeasure Plan (SPCC) for the Parachute Creek Gas Plant should be referenced for reporting procedures and regulatory contacts related to spills and releases. Page 11 EMERGENCY RESPONSE PLAN Revised: Summer 04' • 6.0 INCIDENT HANDLING PROCEDURES 6.1 Fires • 6.2 Hazardous Material Releases • When responding to a fire or explosion, evaluate the situation upon discovery and alert the appropriate WPC personnel of the fire and its location. Give details of the fire to the Senior WPC Representative as soon as possible. The fire could either be 1) limited to the immediate work area 2) be limited to the confines of the Parachute Creek Gas Plant with the potential for migrating off-site or 3) extend beyond the area of the Parachute Creek Gas Plant. In the first situation the incident can be mitigated with trained personnel. If the emergency will not necessitate the shutdown of equipment, secure the area, and proceed with containment and control procedures as necessary. Only attempt to extinguish incipient fires with portable extinguishers and by shutting off the flow of the gas to the fire. If the fire cannot be quickly controlled, evacuate the hazard area. Keep supervision aware of the conditions, and whether additional personnel or equipment will be needed. The second situation probably cannot be mitigated without outside assistance from local emergency response agencies. The Fire Department and the Sheriffs Department must be alerted via "911". The Senior On -Duty WPC Representative should take command of the incident until the Senior Officer from the emergency response organization arrives on the scene and assumes control. Provide follow- up information to the responding fire department units including the Property Damage/ Loss Report/ Near Miss Report (http:llintranet.williams.comleformslformslproperty loss near miss.doc) and any hazardous material release information. In the third situation, a fire beyond the confines of the gas plant, the public could be affected within 60 minutes. The response cannot be mitigated without both WPC and local government resources. A more aggressive firefighting posture towards a fire may be attempted with the on-site approval and direction of a Williams SuperintendentlManager or their superiors. In the event of a hazardous material release, the primary concern and responsibility is the protection of life. The second responsibility is the protection of property and the surrounding environment. Notify the Senior WPC Representative of the emergency with a brief description of the incident, the location, product and specific equipment involved. Page 12 • EMERGENCY RESPONSE PLAN Revised: Summer 04' 6.3 Medical Emergency 6.4 Severe Weather Incidents Leave the area immediately if potentially harmful levels of flammable vapors/gas are present. Do not allow access to the area by unnecessary persons. if the hazardous material spill or leak is beyond the capability of the WPC personnel, follow the posted evacuation routes to designated assembly points (where?). When possible evacuate up wind of the hazard. Personnel should rendezvous at least 500 feet from the Hazard. Refer to the Material Safety Data Sheets (MSDS's) for information on the specific materials released in order to evaluate the hazard. Contact CHEMTREC at 1-800-424-9300 if additional information is required. Attempt to defensively control the leak or reduce the spill size by remotely closing the appropriate valve, reducing operating pressure, or rotating a leaking container so that the hole is above the levet of the liquid. Proceed within the guidelines of HAZWOPER and other appropriate emergency processes to control or contain the extent of the release. A medical emergency must be responded to immediately using available First Aid equipment. Personnel with current First Aid training should be called upon first to control the situation. Local medical emergency response agencies must be notified immediately. Emergency contacts are listed in Appendix 11I. Be ready with the following information: • Location of incident with directions to the scene. • Number of people injured. • Type(s) of injuries if known. • Condition of the patient if known. • Whether rescue equipment is needed to transport the victim. For example, is the victim trapped in machinery, in a confined space, ect? The facility operations personnel will rely on local weather forecasts and media broadcasts for warning of approaching severe weather. Upon notice or alert of severe weather, operations personnel shall move to a safe location to monitor or observe facility systems during the weather event. 1f the facility cannot be monitored safely from an immediate or nearby location, personnel shall leave the area until the severe weather has passed by the facility. When it is safe to return to the facility, all systems and equipment should be checked for damage and any emergency situations handled in accordance with the ERP. Page 13 • • • EMERGENCY RESPONSE PLAN Revised: Summer 04' 6.5 Transportation kccidents 6.6 Vandalism/Sabotage 6.7 Bomb Threats Response to vehicle accidents at or near the facility should be appropriate to the extent of injury and property damage. Accidents involving WPC or contractor vehicles that cause or have the potential to cause an emergency at the facility shall be reported as soon as safely possible to the Plant Manager and Safety Engineer. In the case of any accident follow the instructions listed on the back of the Accident Report Kit. If this packet is not located in the vehicle contact the Safety Engineer. Upon discovery of evidence of vandalism or sabotage, an immediate assessment of all facility equipment and systems shall be performed. After the assessment is accomplished and a return to normal operations is possible, a thorough documentation of the vandalism should be completed and reported to the Plant Superintendent. Local law enforcement should be contacted as necessary. Any threat made toward personnel or WPC property should be taken seriously and considered dangerous. This threat could be receive by phone, written or electronic message, through a third party such as the media, or by actual discovery of an explosive device. When a threat has been received promptly notify the Plant Superintendent, the Safety Engineer and local law enforcement agencies_ The Bomb Threat Checklist provided in this section is to help access the threat and to properly document the situation. Most prank calls involve very general information, which makes it difficult to develop an appropriate response. When the bomb threat contains specific information and has positively identified a target, the threat will be treated as very serious and immediate action should be taken to evacuate the threatened area. If Possible, obtain as much information as possible about the location of the bomb, when it is set to explode, ect. The caller might refuse to give any information, or may actually want to provide detailed information so those employees can be evacuated. Whenever a specific location is included in a bomb threat, a search must be performed, but only a Military Explosive Ordinance Disposal Team, a Police Bomb Squad, or a Fire Department Bomb Squad should conduct the search. Williams personnel should not enter the facility during a bomb threat situation for any reason? Page 14 EMERGENCY RESPONSE PLAN Revised: Summer 04' BOMB THREAT CHECKLIST Name of Facility: Report call immediately to: Telephone Bomb threat received by:. Date Questions to ask Exact wording of threat 1. When is bomb going to explode? Child 2. Where is bomb right now? Teenage 3. What does bomb look like? 50+ 4. What kind of bomb is it? 5. What will cause it to explode? Heavy 6. Did you place the bomb? Spanish 7. Why? Other 8. What is your address? New England 9. What is your name? Calm THE FOLLOWING INFORMATION REQUIRES OPINION, PERCEPTION AND JUDGEMENT. PLEASE GIVE YOUR VERY FIRST IMPRESSIONS: CALLER WAS: Male Adult Female Child ESTIMATE AGE Pre Teen Teenage 20 — 40 40 — 50 50+ CALLER'S SPEECH: Accent Heavy Slight Foreign Spanish Asian German Other American Southern New England Other CALLER'S VOICE: Calm Soft Distinct Angry Loud Slurred Excited _ Ragged Laughing Crying Rapid Slow Normal Deep Nasal Lisp Stutter Deep Breathing Familiar Raspy Clearing Throat Cracking Voice BACKGROUND SOUNDS: Street Noises Office Machinery Animal Noises Tele Booth Kitchen Ware Voices Airplane Bus Factory Machinery Train Clear Music House Noises Local Weather Motor Long Distance Static Other THREAT LANGUAGE: Well Spoken Incoherent Foul Taped Irrational Message Read by_Threat Maker Page 15 EMERGENCY RESPONSE PLAN Revised: Summer 04' 7.0 FACILITY SHUTDOWN 7.1 Emergency Shutdown Procedures If an emergency necessitates that facility operation be terminated, an emergency shutdown (ESD) should be performed by facility personnel. At the Parachute Creek Gas Plant no manual shut down is required since all shutdown is automated from the control room. After initiating the ESD, personnel should activate the evacuation horn. The horn is a continuous waling sound and is accompanied by a blue Tight that can be seen by those working in the plant. Next, account for all the personnel working at the site. If the operations personnel does not know where his partner is, he should make a quick sweep of the plant to warn him. After that, grab the magnetic "Personnel inlout" board and the sign in clipboard that are located next to the time cards. Then follow the evacuation plan as shown in Appendix ll. Any emergency shutdown should occur with the intent of maximizing safety and minimizing property or equipment damage. If performing an emergency shutdown will potentially cause injury or death, then personnel should evacuate the facility without completing shutdown procedures. Page 16 EMERGENCY RESPONSE PLAN Revised: Summer 04' 8.0 TERIVIINATINO THE EMERGENCY 8.1 Recovery of Operations 8.2 Documentation 8.3 Damage Assessment Facility operations should commence as soon as safely possible following a facility or equipment shutdown event. An inspection and review of affected equipment or systems by safety and engineering staff members may be required before normal operations can be restored. The Incident Commander shall make certain all calls, conversations, pressures, quantities, or other information pertinent to an emergency event are documented per this ERP and the attachments herein. See Attachment VI. Personnel designated by the Incident Commander shall visually inspect all equipment and systems following an emergency incident. Any evidence of damage will be reported to the Incident Commander and properly documented. Any damaged equipment that presents an unsafe condition shall be repaired or replaced before returning affected systems to normal operation. 8.4 Post -Emergency When the emergency has ended or as soon as practical, the following Activities should be considered: ■ the extent of the damage; • an estimate of time required to repair the equipment/facility. Call personnel and have them report to duty if and when they are needed: locate pertinent material available from stock or suppliers; • arrange for contract equipment and personnel; • prepare plans for returning the facility to service; ■ assist in any other activities affected by the emergency; • dispatch work crews and equipment to the site as needed; • restore facility to service as soon as repairs can be made safely and in accordance with established procedure; • evaluate the cause of failure and provide a written plan to prevent a reoccurrence of the emergency event. Emergency events will be investigated per the requirements of WPC accident investigation procedures. The investigation will determine the root cause of the emergency event and recommend any needed changes in order to prevent recurrence. The investigation will assess the effectiveness of the response team and the ERP to detennine whether Page 17 • • EMERGENCY RESPONSE PLAN Revised: Summer 04' improvements are needed. Page 18 EMERGENCY RESPONSE PLAN • APPENDICES I. ContactlPersonnel List II. Emergency Action Site Plan III. Emergency Contacts IV. On Site Emergency Response Equipment V. Facility Personnel Responsibilities VL Chronological Record of Emergency VII. Emergency Drill Form VIII. Critique and Follow-up Response IX. Emergency Response Plan Review Record X. Registration Form • • • • • EMERGENCY RESPONSE PLAN L CONTACT/PERSONNEL LIST For further information about the Emergency Response Plan, evacuation, response to emergency events, or other information regarding area/facility emergencies, contact the following people: NAME TITLE TELEPHONE Steve Soychak District Manager (970) 263-0383 (970) 216-0922 (cell) Eric Miller Plant Engineer (970) 285-9377 (970) 270-2813 (cell) Mike Damori Processing Supervisor (970) 263-5327 (970) 26I-4612 (cell) Kevin McDermott Safety Engineer (970) 285-9377 (970) 309-1195 (cell) Dave Cesark Principal Environmental Specialist (970) 285-9377 (470) 216-9181 (cell) EMERGENCY RESPONSE PLAN • II. EMERGENCY ACTION SITE PLAN • —.a— •EMIR MNACCAFE RWOk POI YACn4NJ4 A-sweer W+ Ann XA WISES Mums 001410 WOK For Wei d alvnx ■ CCPPPIY%4N asomi•Nous mmmmmm seumns••e•R • SECONDARY POST- EVACUATIDN ASS•EAARLY AREA /// 1:00 witE N p, 4PPIISkWAAIE :{4l PI Emergency Exits FIGURE 1 ACTION SITE PLAN WILLIMS PRODUCTION RMT COMPANY PARACHUTE CREEK GAS PLANT GARFIELD COUNTY COLORADO REVISIN DATE NI2w REVIONSTON NUId9ER nut REVISED NY C HAIL_ SCALE AS NOTED • • • EMERGENCY RESPONSE PLAN III.. EMERGENCY CONTACTS NAME OF FACILITY: PARACHUTE CREEK GAS PLANT Issue Date: 7/04 Latitude of Facility: N39° 29' 13" Longitude of Facility: W108° 6' 31" NAME OF COMPANY OR AGENCY PHONE NO. Any Emergency 911 St. Mary's Air Life City: Grand Junction State: Colorado 1-800-322-4923 St. Mary's Hospital City: Grand Junction State: Colorado (970) 244-2273 Clagett Memorial Hospital City: Rifle State: Colorado (970) 625-1510 Garfield County Sheriff City: Rifle State: Colorado (970) 625-1899 State Highway Patrol City: State: Colorado (970) 248-7277 Colorado State Patrol HAZMAT Service City: Parachute State: Colorado (970) 248-7283 Rifle Fire Protection District City: Rifle State: Colorado (970) 625-1220 Rifle Fire Protection District City: Parachute State: Colorado Other Agencies or Contacts (Customers, people living near the Facility, etc) Garfield County Emergency Planning Committee City: Glenwood Springs State: Colorado (970) 945-8020 Colorado Department of Public Health and Environment City: Denver State: Colorado (303) 692-2035 Environmental Protection Agency City: State: 1-800-227-8917 City: State: City: State: City: State: City: State: City: State: EMERGENCY RESPONSE PLAN IV. ON SITE EMERGENCY RESPONSE EQUIPMENT Equipment Location Spill Containment/Control Equipment • Approximately 20 Pig Blankets • Compressor Building, Generator Building, Warehouse Fire Control Equipment (Extinguishers) • Approximately 45 Fire Extinguishers • Throughout the Plant Warehouse, Generator Building, Note: An updated list of extinguishers and their Condenser Tanks, NGL Tanks, locations is available in the PSMfrle cabinet at Compressor Building, Amine Parachute Creek Building, Control Room, ect. Other • • • EMERGENCY RESPONSE PLAN Y. FACILITY PERSONNEL RESPONSIBILITIES Facility Name: PARACHUTE CREEK GAS PLANT Issue Date: TITLE NAME RESPONSIBILI'I MS DURING AN EMERGENCY Incident Commander Supervises the response activities and coordination of efforts, media contacts, and compliance contacts. Logistics Officer Obtains necessary response equipment and materia! to support emergency and mitigation procedures. Administration/Finance Coordinator Arranges for humanitarian assistance, lodging and meals as well as manages purchase orders, contacts, etc. Planning Officer Coordinates contractors and additional company personnel as necessary Safety Engineer Communicates reportable incidents, assists with safety equipment, & control efforts. In addition, as personnel available: On -Site Safety Officer Ensures site, public, and employee safety, establishes the site safety plan, coordinates environmental response, maintains proper communication with agencies as necessary. On -Site Coordinator/Operations Chief Control of emergency, isolation of facility. As required by HAZWOPER: Technician Level Responder Set up incident command post & isolation offacility_ Operations Level Responder Defensive response, contact appropriate personnel. Other Facility/Area Personnel: Person in Charge Coordinate support efforts. Operations Manager Rescue Personnel (AH area field personnel): Medical Personnel (All personnel trained in First Aid & CPR): Other Area/Facility/Regional Personnel: • • EMERGENCY RESPONSE PLAN VL _CHRONOLOGICAL RECORD OF EMERGENCY NAME OF FACILITY: YOUR NAME: DATE OF INCIDENT: TIME Isl. AWARE: FIRST RESPONDER EMPLOYEE COLLECTS THE FACTS. Briefly describe the emergency: Was the ESD activated? Yes No I Time: Did you activate the siren? Yes No Time: Can you isolate the problem area? Yes No Time: CAUTION: Do not risk your life or the life of others. Is rescue needed? _ Yes No _ Time: Is first aid needed? Yes No Time: _ If yes, can you move the victim? Yes No Time: Are you in a hazardous environment? Yes No Time: Do you have the proper equipment to proceed without help? Yes No Time: Do you need to call 911? Yes No Time: Are you able to set up an emergency command center? Yes No Who should you contact for assistance? If the emergency is outside of the plant: Who is reporting the emergency? Name: Called From: Address: Phone No. Phone No. LOCAL EMERGENCY RESPONSE AGENCIES Time: Name Ambulance Service: City: State: Phone No. Time: Name Hospital: City: State: Phone No. Tirne: Name Air Life: City: State: Phone No. Time: Name Alternate Hospital: _ City: State: Phone No. LAW ENFORCEMENT Time: Name City Police: City: State: Phone No. Time: Sheriff's Office County: City: State: Phone No. Tirne: State Patrol Name: City: State: Phone No. EMERGENCY RESPONSE PLAN FIRE DEPARTMENT Time: Fire Department Name: City: State: Phone No. COMPANY PERSONNEL Time: Name: City: State: Phone No. NOTE: Notify Primary Contact as soon as you have the emergency in primary control (e.g., ESD - evacuate - rescue - first aid - isolate fuel source if fire - spill containment to prevent environmental contamination). Time: Name Plant Superintendent: - Phone No. Time: Name Other Operators: Phone No. Tirne: Name Other Technicians: Phone No. Phone No. Time: Name Plant/Facility Operator: Work No. Home No. Time: Name Safety Engineer: Work No. Home No. If you have the problem under control, start your Emergency Response Plan. LOCAL RESIDENCES Time: Name of Resident: Location: Phone No. Time: Name of Resident: Location: Phone No. Time: Name of Resident: Location: Phone No. PIPELINE COMPANY(S) or OTHER AFFECTED COMPANY(S Time: Company: Phone No. Time: Company: Phone No. Time: Company: Phone No. UTILITIES Time: Company: Phone No. Time: Company: - - Phone No. Other Action(s) Taken - Attach extra sheets if necessary. Time: Time: Time: Time: Emergency is under total control. Time: Pale: Incident Commander's Initials: EMERGENCY RESPONSE PLAN VII, EMERGENCY DRILL FORM Date of Drill: Attendees: Drill Scenario: Facility Name: Emergency Equipment/Activities Involved/Topics Covered (check if yes): SCBA: Emergency Rescue: Portable Fire Extinguishers: Wheeled Fire Extinguishers: Eye/Face Equipment: SPCC: Plant Shutdown: Equipment Shutdown: Lockout/Tagout: CPR/First Aid: Hazard Communication: HAZWOPER: Others: Contacts Made: Safety Department: Operations Manager: Others: Discussion Points/Comments: Training Conducted/Accomplished: EMERGENCY RESPONSE PLAN VIII. CRITIQUE AND FOLLOW-UP OF RESPONSE General Once a practice drill or an emergency incident has occurred, and an investigation into that incident has begun, the use of this emergency response plan along with the procedures and policies listed in it should be critiqued bases on its use, effectiveness, and its completeness. This section establishes basic questions, which will assist in this follow-up evaluation and is intended to meet compliance with OSHA standard CFR 1910.120(q)(2)(x)). Questions The following are the types of questions that should be answered, after an incident has been mitigated or after a practice drill has been completed, in order to evaluate this Emergency Response Plan. 1. Was the Emergency Response Plan implemented in a timely and efficient manner? 2. Were evacuation alarms activated, escape routes followed and personnel accounted for? 3. Were the proper authorities and agencies notified in a timely manner? 4. Were proper procedures/checklists followed and were they effective in resolving the incident? 5. Was the correct personal protective equipment used? 6. How could this emergency response plan be changed to increase its effectiveness? This emergency response plan should be revised if it is determined that its use, procedures or policies are not effective in mitigating the practice drill or emergency incident. DATE RESPONSIBLE PARTY ACTION August 2003 Cordilleran Original Documents Summer 2004 C. Hale/ K. McDermott Annual Revision EMERGENCY RESPONSE PLAN IX. EMERGENCY RESPONSE PLAN REVIEW RECORD Name of Facility: PARACHUTE CREEK GAS PLANT Date of Initial Plan Development: 8/21/03 Date of Last Review for Plan Accuracy: July 2004 Date of Last Revision: July 2004 Plant Superintendent Name: Eric Miller Plant Superintendent Signature: Date: EMERGENCY RESPONSE PLAN X. Registration Form All Recipients of the Plan must complete and return this form to register it for distribution and future change/updates. If this form is not returned, the copy of the Plan will be recalled. This is to acknowledge receipt of the Williams Parachute Creek Emergency Response Plan: Name: Company: Division: Street / P.O. Box No.: Zip Code: Return To: Williams Production RMT Company Safety Engineer 1058 County RD #215 Parachute, CO 81635