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HomeMy WebLinkAbout1.10 Geo-Hazard, Emergency Response, SPCCGeo —Hazard Report ■ HUNTER RIDGE ENERGY SERVICES LLC OLSSON ASSOCIATES GEOLOGIC AND SOIL HAZARDS REPORT Introduction Hunter Ridge Energy Services, LLC is requesting land use approval for an existing Facility constructed by Encana Oil and Gas (USA) Inc., the Booster Compressor Station, located in Section 3, Township 5 South, and Range 96 West, of the Sixth Principal Meridian (see vicinity map). This facility is situated between two seasonal drainages and at an elevation of 8,240 feet above sea level, and located north of West Fork Parachute Creek, approximately eighteen miles northwest of Parachute, Colorado in Garfield County. Structural Geology The location for this facility is underlain by the main body of the Eocene Uinta Formation. The Uinta Formation (Eocene) formed mainly from the clastic sediments of a generally southward prograding deltaic complex that ultimately filled the Eocene lake in which sediments of the Green River Formation were deposited. Much of the Uinta consists of southward -thinning wedges composed chiefly of sandstone, and sandstone that interfingers with northward -thinning tongues of marlstone of the Green River Formation. The Uinta Formation, including its tongues, is mostly brown weathering sandstone, but also includes marlstone, mudstone, shale, oil shale, minor limestone, and thin tuff beds The sandstone beds, highly variable in lithology, range from very fine to very coarse grained, and are locally conglomeratic sandstone beds that are generally massive or poorly bedded. Main body of Uinta Formation - The uppermost part of the Uinta in the map area includes fairly abundant marlstone beds similar in lithology to the underlying tongues of the Green River Formation. However, most, if not all of these marlstone beds, are lenticular and are not regarded as tongues of the Green River Formation. The basal contact of the main body of the Uinta is placed at the top of the stratigraphically highest mapped tongue of the Green River Formation or at the top of the Parachute Creek Member where tongues of the Green River Formation are absent. Surficial Geology Hunter Ridge Energy Services, LLC 003 Story Booster Booster Compressor Station December 2012 1 Olsson Associates Grand Junction, CO OA Project # 012-2798 This part of the Uinta Formation consists of siltstone, marlstone and sandstone with some minor oil shale, limestone and conglomeratic sandstone. The majority of the plateau top in the central Roan Plateau area is underlain by this part of the Uinta Formation (Fig. G-1). The cliffs at the edges of the plateau to the west, southwest of the location are comprised of the Parachute Creek Member of the Green River Formation and consist of oil shale, sandstone and mudstone. The rocks of the Uintah Formation are the parent material for the soils that occur at this location. Geologic Hazards In Figure F-1 the floodplain data provided by Garfield County GIS Department shows that the Booster Compressor Station Facility does not lie within a floodplain area. The proposed site is in an area with steep terrain and at an elevation of approximately 8220 feet above mean sea level. Based on a comparison with similar areas, slope hazards likely exist. No geologic hazards have been mapped by Garfield County in this area, and no faults or other hazards are evident on the Geologic Map of Colorado. Soils According to information prepared by the Natural Resources Conservation Service (NRCS) Soil Survey, soils in the location of this site have been mapped as the Rhone loam (61), Parachute loam (52), and Parachute -Rhone loam (53), (Fig. S-1). A copy of a NCRS Custom Soil Resource Report for the project site has been provided. The majority (56.4%) of the facility lies within the Rhone loam (61), with 36.3% being the Parachute -Rhone loam (52) and 7.2% being the Parachute -Rhone loam (53) The Rhone loam soils are developed on 30 to 70 percent slopes consisting of well drained soils on mountainsides and ridges at elevations ranging from 7,600 to 8,600 feet. The restrictive bedrock layer is approximately 40 to 60 inches in depth. The parent material for this soil is Marl and/or residuum weathered from sandstone. The Parachute -Rhone loam soils are developed on 26 to 65 percent slopes, and consist of welldrained soils on mountain sides, ranging in elevations from 7,500 to 8,700 feet. The parent material for this soil is residuum weathered from sandstone. The Parachute -Rhone loam soils set at elevations ranging from 7,600 to 8,600 feet and found on mountainsides and ridges. Depth to restrictive paralithic bedrock is approximately 40 to 60 inches. The parent material of this soil is Marl and/or residuum weathered from sandstone. Conclusions and Summary Olsson Associates appreciates the opportunity to provide this information to Hunter Ridge energy Services, LLC pertaining to the assessment of geologic and soil hazards associated with the Booster Compressor Station Facility in Garfield County, Colorado. Olsson can conduct field Hunter Ridge Energy Services, LLC 003 Story Booster Booster Compressor Station December 2012 2 Olsson Associates Grand Junction, CO OA Project # 012-2798 work to assist with the site specific assessments of the proposed project, to determine the degree to which these hazards may affect the specific location. Sincerely, Olsson Associates, Inc. Tammie Lee Crossen Associate Geologist Attachments: Vicinity Map Figure G-1 — Geology Map Figure F-1 — Flood Plain Map Figure S-1 — Soils Map References Online References Colorado Oil and Gas Conservation Commission http://cogcc.state.co.us/ Natural Resources Conservation Service - Soil Survey http://www.nrcs.usda.qov/ Garfield County, Colorado - GIS Department http://www.garfield-county.com/ U.S. Geological Survey (USGS) http://qeosurvey.state.co.us/apps/wateratlas/chapter6 2pagel.asp Hunter Ridge Energy Services, LLC 003 Story Booster Booster Compressor Station December 2012 3 Olsson Associates Grand Junction, CO OA Project # 012-2798 Tu Site Location Geologic data obtained from USGS Legend 0 Site Location — Local Roads Geology Type Tu - Uinta Formation Tgp - Green River Fm., Parachute Creek Member 0 250 500 Feet 1,000 PROJECT NO: 012-2798 DRAWN BY: Jenna Muhlbach DATE: 12/31/12 GEOLOGY MAP HUNTER RIDGE ENERGY SERVICES LLC STORY BOOSTER (003) GARFIELD COUNTY, COLORADO O\OLSSONJ ASSOCIATES 826 21-1/2 ROAD GRAND JUNCTION, CO 81505 TEL 970.263.7800 FAX 970.263.7456 FIGURE G-1 Legend 0 Site Location — Highway — Local Roads / Floodway 0 1 2 4 Miles PROJECT NO: 012-2798 DRAWN BY: Jenna Muhlbach DATE: 12/31/12 FLOODPLAIN MAP HUNTER RIDGE ENERGY SERVICES LLC STORY BOOSTER (003) GARFIELD COUNTY, COLORADO O\OLSSON ASSOCIATES 826 21-1/2 ROAD GRAND JUNCTION, CO 81505 TEL 970.263.7800 FAX 970.263.7456 FIGURE F-1 Legend 0 Site Location Soil Types Local Roads IM 36 - Irigul channery loam, 9-50% slopes En 38 - IrigualStarman channery loams, 5-50% slopes 1 148 - Northwater loam, 15-65% slopes F-152 - Parachute loam, 25-65% slopes 53 - Parachute -Rhone loams, 50-30% slopes 61 - Rhone loam, 30-70% slopes 0 62 - Rock outcrop Torriothents complex, very steep MN 63 - Silas loam, 3- 2% slopes I I 0 250 500 Feet 1,000 PROJECT NO: 012-2798 DRAWN BY: Jenna Muhlbach DATE: 12/31/12 SOILS MAP HUNTER RIDGE ENERGY SERVICES LLC STORY BOOSTER (003) GARFIELD COUNTY, COLORADO O\OLSSONJ ASSOCIATES 826 21-1/2 ROAD GRAND JUNCTION, CO 81505 TEL 970.263.7800 FAX 970.263.7456 FIGURE S-1 Emergency Response Plan ■ HUNTER RIDGE ENERGY SERVICES LLC encana. ethos OPE RATL!ONAL EXCELLENCE Emergency Response Plan Quick Reference Guide (Condensed copy for permit submittals) Encana's complete Emergency Response Plan is on file with all applicable Fire Districts and updates are provided as necessary Updated Sep 2012 safe3 O erica`' baa riaturaf gas EMERGENCY RESPONSE PLAN U.S.A. DIVISION SRBU EMERGENCY RESPONSE REPORTING TEMPLATE Document No: ERP -00442 SRBU Revised By/Date: Rev'icwed By/Date; ERPCommf05.26.2010 Approved By/Date: ERPComml05.26.2010 SBU: Name of Event: Date: 2010 Location: Secured : I❑Yes ❑No Town, State: , 1. Time of the call. (Military Time) 2. What is the location of the emergency? What has happened'? Location?: What Happened?: 3. Has anyone been hurt? ❑No ❑Yes If so, Who? How? 4. Who is the most senior Encana or Company representative on location? 5. Who is the most senior Encana or company representative on location who will be the INCIDENT COMMANDER? Do they have the proper Incident Commander Training? Incident Commander Trained? No Yes 6. Based on your assessment, what Level of Emergency are you declaring? Level 1 ❑ Level 2 ❑ Level 3 ❑ 7. Who are you appointing as OPERATION CHIEF? 8. Do not respond to a man down, or to the emergency, until you have completed a Risk Assessment, gained control and understanding of the emergency, and can assure life safety of the responders. Have you completed a Risk Assessment? N • Y ❑ t nruntrulled Document When Printed Page 1 of 2 encana_ Hatt/rag yams EMERGENCY RESPONSE PLAN U.S.A. DIVISION SRBU EMERGENCY RESPONSE REPORTING TEMPLATE Document No: ERP -0042 SRBU Revised By/Date; Reviewed %/Date: ERPComm/05.26.2010 Approved By/Date: ERPComm/05.26.2010 9. Are there FIRST RESPONDERS on location? No . Yes Time of Arrival:• Who arrived? 10. Have you set up an INCIDENT COMMAND POST, if so, where? No ❑Yes Location of the Incident Command Center? 11. Based on your initial assessment, what is your proposed preliminary response strategy? 12. 1 will act as EMERGENCY MANAGER, and activate the EOC. Plan on calling in to the EOC, using the Emergency Notification Conference Call Number, within 15 minutes. Emergency Manager Activated at: Emergency Operations Center Activated at: We will be using EOC Conference Line: EOC 1 and EOC 2: 1-877-445-2224 EOC 1: ❑Profile # :421013 Password 10131 EOC 2: ❑ Profile # 2421014 Password 10141 EOC 3: D {20 or more incoming calls) North American Dial -In: 1-866-400-1788 international Dial -In:: (647) 427-2433 Conference code: 835 298 4806 Leader PIN: 2846 13. I will notify EXECUTIVE LEAD, EHS OFFICER, and put together the EMERGENCY MANAGEMENT TEAM. Executive Lead Notified: No ❑ Yes ❑ Time: EHS Officer Notified: No ❑ Yes ❑ Time: EMT Notified• No ❑ Yes ❑ Time: 14. Start to put together a local INCIDENT COMMAND TEAM. Incident Deputy Safety Officer: Liaison Public Information Operations Planning Logistics Commander: Incident Commander: Officer: Officer: Section Chief: Section Chief: Section Chief: Uncontrolled Document When Printed Page 2 of 2 Emer 1 enc Classification / Levels Definition / Criteria EMERGENCY LEVELS Examples (may not re ect area -s + eci le risks or threats) LEVEL 1 - Onsite incidents where control of the hazard has been obtained but the potential exists for the imminent loss of control due to deteriorating conditions. o Immediate control of the hazard has been established using available resources, however, conditions are not improving and/or resources are being depleted. o Injuries to onsite personnel that are of a moderate impact. o Public safety is not threatened, however there is, or may be, a public perception of moderate risk to human health or the environment. o Environmental impacts are confined to the site and have limited potential to impact offsite. o All control and relief systems are functioning normally. o Any controlled situation, outside of normal operation conditions, where the ability to maintain control using onsite resources is in question or offsite resources are required to maintain control such as a fire or explosion where imminent control of the fire is probable. o Injuries to personnel requiring offsite medical attention. - o Spills and releases that are contained onsite but have the potential to extend offsite. o Any incident requiring the advisory notification of the public of a non -routine, onsite occurrence. o Weather conditions (i.e., tornado) which may threaten personnel and operations. o Potential social / political unrest, labor disputes Uncontrolled Document \Vhen Printed LEVEL 2 - An incident where control oftie hazard has been lost but where imminent nd/or intermittent control of the -hard is possible, o Control of the hazard has been lost, however, through the application of available resources intermittent control is being obtained or hazard control is imminent. o Injuries to onsite personnel that are ofa major impact. o Public safety is not. threatened, however, there is or may be a public perception of significant risk to human health or the environment o Environmental effects extend offsite and are resulting in minor or short- term detrimental impacts. o Some control and relief systems are not o i erational. o Any uncontrolled hazard where the ability to regain control using available resources is imminent or intermittent control is being achieved using available resources such as pipeline integrity failure. o Injuries to personnel which have or are likely to result in a lost time (beyond the day of the occurrence) injury or short term health impact. o Spills or releases that extend offsite and are, or will, result in minor or short-term detrimental impacts. o Any incident requiring the notification of the public of a potential or imminent threat to human health or the environment, such as or pipeline rupture. a Some control and/or relief systems are not operational. o Imminent security threats, social / political unrest, and labor disputes. a Severe weather threats which threatens personnel and/or operations. o Overdue vehicle or aircraft. o LEVEL 3 - Anincident where control of the hazard has been lost, imminent control is not possible and public safety is, or has the potential, to be threatened. o Control of the hazard has been lost and regaining control is not imminently possible. o Onsite personnel have sustained injuries with a serious impact. o Public safety is being, or has the imminent potential to be, jeopardized. o Environmental impacts are significant, extend offsite and have the potential to result in long-term environmental degradation. o Key control and relief functions have failed and are not o.eratin: correctl . o Any situation where control of a hazard has been lost and regaining control is not imminently possible such as loss of well control or failure of essential well control equipment. o Injuries to personnel which have or are likely to result in permanent disability, long term health impacts or death a Any incident that has necessitated the evacuation or sheltering of public such as or a catastrophic facility fire or loss of process control. o Spills or releases that have extended off site and are, or likely to, result in significant and substantial detrimental impact to the environment. o Key control and relief systems are not operational. o Act of terrorism, violence, social/political unrest. a Severe weather impacting personnel and/or operations. o Overdue vehicle or aircraft, missin _ 'person. ACTIVATION AND NOTIFICATION REQUIREMENTS Receiving an Emergency Call - Typical Notification First Responder to notify Incident Commander Level 1 - as soon as possible Level 2 or 3 - IMMEDIATELY Report direct or via 24 Hr Emergency Number 11-877-386-2200 Encana local Incident Commander (IC), notified (Reception /Answering Service will initiate call -down. The first person contacted establishes the Incident Commander position, until delegated) Notify/dispatch Operator to Investigate - Sr. Operator Or Representative establishes the First Responder position - Two operators (buddy system) required when H2S z 10 ppm known to be present incident Commander - Contact individual who reported the incident to advise outcome First Responder - Initiate standard operating/ maintenance procedures First Responder determines if the incident involves an Encana facility? it -NO Incident Commander and First Responder will assess the incident. Is it an Emergency? Determine Level of Emergency (see Emergency Levels in this Section) NO incident Commander Contact Operating Company Contact individual who reported the incident to advise outcome First Responder Provide assistance, if possible, until relieved by Operating Company. Maintain contact with operating company and Incident Commander until relieved of duties 4 Identify ScopelArea affected (exposure zone) and: - Activate ERP, notify support personnel (field and Region), emergency services, initiate regulatory notifications - First Responder establishes Command Post (CP) and initiates response actions. Incident Commander notifies authorities and contacts Encana's Emergency Manager. - Incident Commander contacts persons who reported incident to advise them of outcome. - RECORD YOUR ACTIONS! I'ncontrofc d Document When Printed First Responder Actions Protect Yourself ❑ Approach the incident from upwind and uphill, if possible. D Position vehicle far enough away from the release, allowing for a safe retreat, if necessary. 0 Resist the urge to rush in, others cannot be helped if you are injured. 0 Avoid any contact with liquids, mists, sludge's, gases, vapors and smoke. Sound the Alarm 0 Announce level of emergency. 0 Direct others to safe areas and alert other personnel. CaII for Help 0 Notify control room, local office and or the on-call supervisor. 0 Confirm emergency services has been dispatched. 0 Activate Emergency Response Plan. Assume Command ❑ Size up incident and make report. 0 Confirm location (if necessary). 0 Situation found. 0 Make assignments (as necessary). Summon additional help and technical assistance as required. Do not hesitate to summon assistance; it can always be canceled if not needed. 0 Tactical considerations: o Life safety, 0 Environmental protection, and o Incident stabilization, o Property conservation. 0 Zoning: o Utilize, with caution, the U.S. DOT Emergency Response Guidebook for recommended actions if MSDSs are unavailable for released material, o Establish hazard / hot zone (use fire line tape for hot line), 0 Establish and mark warm zone (decontamination corridor), and o Establish cold zone (set security line). 0 Immediately provide for proper decontamination of responders and/or injured. 0 Transfer command (as necessary). Assess Hazard 0 If immediate rescue is required, it should only be attempted when the rescuers are fully aware of the risks posed to them, they are wearing protective clothing, as required, utilizing a bare minimum number of personnel. If the hazards are unknown or exceptionally life-threatening, the rescuer should consider waiting until the situation has been assessed by the IC, SO, and the EHS/HazMat Unit. Secure the Area 0 Restrict access to location or area. 0 Utilize law enforcement agencies (Emergency Alert System) and any other available resources to evacuate or shelter in-place exposed victims. Uncontrolled Document /When Tinted 6 Transfer of Command The process of moving the responsibility for incident command from one Incident Commander (IC) to another is called "transfer of command." It should be recognized that transition of command on an expanding incident is to be expected. It does not reflect on the competency of the current IC. The most important steps in effectively assuming command of an incident in progress are: Assessment & Briefing ❑ Perform assessment of incident situation with existing IC. ❑ Receive adequate briefing by the current IC in face-to-face meeting. The briefing must cover the following items: o incident history (what has happened), o Priorities and objectives, o Current plan, o Resource assignments, o Incident organization, o Resources orderedlneeded, o Facilities established, o Status of communications, o Any constraints or limitations, o Incident potential, and o Delegation of Authority. Written Summary Report ❑ Incoming IC to receive written summary to assist in incident briefings. This form contains: o Incident objectives, o A place for a sketch map, o Summary of current actions, o Organizational framework, and o Resources summary. Notice of Command Change O Determine an appropriate time for transfer of command. CI Provide notice of a change in incident command to: o Emergency Management Team (through dispatch), o General Staff members (if designated), c Command Staff members (if designated), and o All incident personnel and agencies. The incoming IC may give the out -going IC another assignment on the incident. O There are several advantages of this: o The out -going IC retains first-hand knowledge at the incident site, and o This strategy allows the out -going IC to observe the progress of the incident and to gain experience. 'ncontrolled Document When Printed 7 SPCC ■ HUNTER RIDGE ENERGY SERVICES LLC SPILL PREVENTION, CONTROL, AND COUNTERMEASURE PLAN Story Booster Compressor Station GARFIELD COUNTY, COLORADO Prepared for: encana. tural ga Encana Oil & Gas (USA) Inc. PARACHUTE, COLORADO JUNE 14, 2011 REV.2 SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 TABLE OF CONTENTS 1.0 GENERAL INFORMATION 1-4 1.1 INTRODUCTION 1-4 1.2 LOCATION AND DEFINITION OF PLAN AREA 1-4 1.3 CONTACT INFORMATION 1-5 1.4 MANAGEMENT APPROVAL AND COMMITMENT OF RESOURCES 1-5 1.5 SUBSTANTIAL HARM CERTIFICATION 1-6 1.6 PROFESSIONAL ENGINEER CERTIFICATION 1-6 1.7 PLAN LOCATION 1-7 2.0 FACILITY DESCRIPTION 2-1 2.1 PHYSICAL LAYOUT, OPERATIONS, AND FACILITY DEFINITION 2-1 2.2 BULK STORAGE CONTAINER DATA 2-1 2.3 SECONDARY CONTAINMENT AND DRAINAGE CONTROL 2-1 2.4 ANALYSIS OF EQUIPMENT FAILURE 2-2 2.5 TEMPORARY, MOBILE, AND PORTABLE CONTAINERS 2-2 2.6 INTRA -FACILITY GATHERING LINES 2-2 2.7 OIL -FILLED OPERATIONAL EQUIPMENT 2-3 3.0 INSPECTIONS, TESTING, AND MAINTENANCE 3-1 3.1 INSPECTIONS 3-1 3.1.1 Field -Constructed Aboveground Containers 3-1 3.1.2 Shop -Built Containers 3-1 3.1.3 Pressure and Flow-through Vessels 3-2 3.1.4 Produced Water Pits/Ponds 3-2 3.1.5 Portable Containers 3-2 3.1.6 Above -ground Piping 3-3 3.1.7 Field Drainage Systems 3-3 3.1.8 Inspection Schedule and Documentation 3-3 3.2 MAINTENANCE AND TESTING 3-4 3.2.1 Above -ground Piping Maintenance and Monitoring 3-4 3.2.2 Container Maintenance and Testing 3-5 3.2.3 Maintenance and Testing Schedule and Documentation 3-5 4.0 OIL HANDLING PROCEDURES 4-1 4.1 LOADING AND UNLOADING area(s) 4-1 4.2 LOADING AND UNLOADING PROCEDURES 4-1 4.3 INTRA -FACILITY TRANSFER PROCEDURES 4-2 ii SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 4.4 DRAINAGE CONTROL PROCEDURES 4-2 5.0 COUNTERMEASURES AND SPILL RESPONSE 5-1 6.0 TRAINING 6-1 7.0 PLAN MAINTENANCE 7-1 7.1 AMENDMENTS BY OWNERS OR OPERATORS 7-1 7.2 AMENDMENTS BY REGIONAL ADMINISTRATOR 7-1 8.0 RECORDKEEPING 8-1 9.0 CONFORMANCE WITH 40 CFR 112 AND STATE SPCC REQUIREMENTS AND NEEDED MODIFICATIONS 9-1 Table 1 Table 2 Table 3 Table 4 9.1 CONFORMANCE WITH RULE REQUIREMENTS AND NEEDED MODIFICATIONS 9-1 9.2 CONFORMANCE WITH STATE -SPECIFIC SPCC REQUIREMENTS 9-1 LIST OF TABLES Contact List Bulk Storage Containers Secondary Containment Analysis of Equipment Failure Figure 1 — Facility Location Map Figure 2 — Facility Layout Diagram Appendix A Appendix B Appendix C Appendix D Appendix E Appendix F LIST OF FIGURES LIST OF APPENDICES Certification of Applicability of Substantial Harm Criteria Oil Spill Contingency Plan Inspection Forms Plan Review and Amendment Logs Spill History Form Secondary Containment Calculations iii SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 ACRONYMS API American Petroleum Institute ARC annual regulatory compliance AST above ground storage tank ASTM American Society for Testing and Materials Bbl barrel(s), US petroleum, 42 gallons BLM Bureau of Land Management, U.S. Department of the Interior BMPs Best Management Practices BOP blow out preventer CDP central delivery point CDPHE Colorado Department of Public Health and Environment CFR Code of Federal Regulations COGCC Colorado Oil and Gas Conservation Commission DAF dissolved air floatation EPA U.S. Environmental Protections Agency FRP Facility Response Plan IMS Incident Management System MOC Management of Change System OSCP Oil Spill Contingency Plan SPCC Spill Prevention, Control, and Countermeasures STI Steel Tank Institute UL Underwriters Laboratory, Inc. UST underground storage tank WTF water treatment facility iv SPCC Plan - Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 Regulatory Cross Reference Matrix 40 Code of Federal Regulations (CFR) Part Requirement SPCC Plan Section 112.3 (a) Amend plan as necessary per updated regulations 7.1 112.3 (d) Professional engineer certification 1.6 112.3 (e) Maintain a copy of plan at facility (location of plan) 1.7 112.4(d) Report certain discharges to EPA 7.2 112.5 (a) Amend plan following significant changes to the facility 7.1 112.5 (b) Review plan at least every five years and amend if appropriate 7.1 112.7 Management approval of plan 1.4 112.7 Provide a cross reference matrix to regulations 1-1 112.7 Discuss needed facilities, equipment, or procedures not yet operational in separate paragraphs 9.0 112.7 (a)(1) Discussion of facility's conformance with the regulations 9.0 112.7 (a)(2) Equivalent environmental protection is allowed for deviations from portions of regulations. Reasons for non conformance must be stated. 9.0 112.7 (a)(3) Describe the physical layout of the facility. Provide a facility diagram including tanks, underground tanks, storage areas for mobile containers, produced water containers, associated piping, transfer stations, connecting pipes and intra -facility gathering lines. 2.1, 2.5, 2.6, Figure 1, Figure 2 112.7 (a)(3)(i) Plan must include type of oil in each container and capacity of each container 2.2, 2.5, Table 2 112.7 (a)(3)(ii) Discharge prevention measures including procedures for oil handling at loading/unloading areas 4.0, 4.2, 4.3 112.7 (a)(3)(iii) Drainage control around containers and other equipment 2.3, 4.4 112.7 (a)(3)(iv) Countermeasures for discharge discovery, response and cleanup. 5.0, APP B 112.7 (a)(3)(v) Methods of disposal of recovered materials 5.0, APP B 112.7 (a)(3)(vi) Contact list including phone numbers 1.3, Table 1 112.7 (a)(4) Discharge reporting procedures, information to be included 5.0, APP B 112.7 (a)(5) Organize plan to make it useful in an emergency APP B 112.7 (b) Provide an equipment failure analysis including sources, quantity, direction, and rate of flow 2.4, Table 4 112.7 (c) General secondary containment requirement (typical failure mode and most likely quantity) for areas from which a discharge could occur by at least one of eight specified measures 2.3, 2.4, 4.1 112.7 (d) If necessary provide an explanation of impracticability of secondary containment, conduct periodic integrity testing of containers and periodic integrity and leak testing of valves and piping 9.0 112.7 (d)(1) For impracticability, provide an oil spill contingency plan per part 109 APP B 112.7 (d)(2) For impracticability, provide written commitment of manpower, equipment, and materials 5.0, 1.4 112.7 (e) Written procedures for inspections and tests 3.1, 3.1.8 112.7 (e) Records of inspections must be signed and kept with plan for three years 8.0, APP C 1-1 SPCC Plan - Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 40 Code of Federal Regulations (CFR) Part Requirement SPCC Plan Section 112.7 (f)(1) Train oil handling personnel 6.0 112.7 (f)(2) Designate an individual accountable for discharge prevention 1.4 112.7 (0(3) Conduct an annual discharge prevention briefing 6.0 112.7 (g) Security N/A 112.7 (h) Provide sized secondary containment (largest compartment on tanker) for loading/unloading racks 4.1 112.7 (h) Provide systems to prevent truck departure before disconnection 4.1 112.7 (h) Inspect truck prior to filling and departure 4.1 112.7 (i) Evaluate field constructed containers for brittle fracture failure when containers are altered or repaired 3.1.1 112.7 (j) Compliance with State requirements 9.0 112.7 (k) Qualified oil -filled operational equipment - alternative to general secondary containment requirements 2.7 112.7 (k) If no secondary containment -Prepare inspection procedures or monitoring program 2.7 112.7 (k)(2)(ii) If no secondary containment -Provide an oil spill contingency plan per part 109 APP B 112.7 (k)(2)(ii) If no secondary containment provide written commitment of resources 1.4 112.9 (b)(1) Oil production facility drains of dikes must be kept closed. Inspect diked areas before draining water and remove accumulated oil. 4.4 112.9 (b)(2) Inspect field drainage systems, oil traps, sumps or skimmers for oil. Remove accumulated oil 3.1.7 112.9 (c)(1) Material and construction of containers must be compatible with stored material and conditions of storage 2.2 112.9 (c)(2) Provide sized secondary containment (capacity of largest container plus precipitation) for tank battery, separation, and treating facility installations 2.3, Table 3, APP F 112.9 (c)(2) Confine drainage from undiked areas to catchment basin or holding pond 4.4 112.9 (c)(3) Visually inspect containers, foundations, and supports periodically and on a regular schedule 3.1, APP C 112.9 (c)(4) Engineer tank batteries to prevent discharges 3.2.2 112.9 (c)(5) Alternative to sized secondary containment for some flow through process vessels 9.1 112.9 (c)(5)(ii), (iii) Take corrective action as indicated by inspections, tests or evidence of oil, remove or stabilize and remediate any accumulation of oil 5.0 112.9 (c)(6) Alternative to sized secondary containment for some produced water containers 3.1.4, 3.2.1, 112.9 (d)(1) Periodically and regularly inspect aboveground valves, piping, drip pans, supports, and pumps associated with transfer operations 3.1.6, 3.1.7 112.9 (d)(2) Inspect salt water disposal facilities 3.1.4 112.9 (d)(3) For flowlines and intra -facility gathering lines without secondary containment provide: 2.6 112.9 (d)(3)(i) Oil spill contingency per Part 109 and APP B 1-2 SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 40 Code of Federal Regulations (CFR) Part _ Requirement SPCC Plan Section 112.9 (d)(3)(ii) Written commitment of resources 1.4 112.9(d)(4) Prepare and implement a flowline maintenance program including: 3.2.1 112.9(d)(4)(i) Ensure materials are compatible with fluids 3.2.1 112.9(d)(4)(ii) Visually inspect or test flowlines and intra -facility gathering lines on a regular and periodic schedule. For lines not having secondary containment the frequency and type of testing must allow for prompt implementation of the contingency plan. 3.1.6, 3.1.7 112.9(d)(4)(iii) Take corrective action as a result of inspections, tests, or evidence of a discharge 3.1.8, 3.2.1 112.9(d)(4)(iv) Promptly remove or stabilize and remediate oil discharges APP B 112.20 (e) 112.20(0(1) Certification of the applicability of substantial harm criteria 1.5, APP A 1-3 SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 1.0 GENERAL INFORMATION 1.1 INTRODUCTION Encana Oil & Gas (USA) Inc.'s (Encana's) Story Booster Compressor Station is a natural gas compression facility. The Story Booster Compressor Station is comprised of metering equipment, dehydration, separation, above ground storage tanks, an exempt underground used oil storage tank and piping systems. Products related to the operation and maintenance of the facility are stored in above ground storage tanks. Natural gas liquids are occasionally taken from the facility via vacuum tank truck. The facility operates 24 hours per day and is checked by operations on a daily basis. The 003 well production pad and exempt methanol storage tank are located on the same pad and are included in another SPCC Plan. The Oil Pollution Prevention Regulations (40 CFR 112) require preparation of a Spill Prevention, Control and Countermeasure (SPCC) Plan for facilities that have discharged or could reasonably be expected to discharge oil into or on navigable waters of the United States or adjoining shorelines. A SPCC Plan is required to be prepared if greater than 42,000 gallons of oil are stored in buried tanks or greater than 1,320 gallons of oil is stored in aboveground tanks. Because one or more of the tanks at this facility exceeds one or both of the thresholds listed above, a SPCC Plan is required to be prepared and implemented. The purpose of this SPCC Plan (referred to herein as the Plan) is to describe engineering and administrative controls employed at/by a facility to comply with requirements set forth under 40 CFR 112 to prevent the discharge of oil to navigable waters as well as state -specific rules, regulations and guidelines pertaining to oil spill prevention, control and countermeasure. The contents of this Plan include all applicable requirements listed in 40 CFR 112 as noted in the cross-referencing table located in the Plan preface. This Plan has been prepared in accordance with those regulations as amended by the Environmental Protection Agency's (EPA) November 13, 2009 final regulatory action and any more stringent state -specific requirements regarding the prevention, control or countermeasures associated with releases of oil to the environment. 1.2 LOCATION AND DEFINITION OF PLAN AREA This plan covers the Story Booster Compressor Station. The Story Booster Compressor Station includes the metering equipment, dehydration, separation, above ground storage tanks, and 1-4 SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 piping systems. The processes and the inventory stored on site make these operations subject to 40 CFR 112 and, specifically, section 40 CFR 112.9 for onshore oil production facilities. The facility is located at SWSE, Section 3, Township 5 South, Range 96 West. Figure 1 depicts the topographic and geographic location of the facility for which this Plan has been developed and implemented. This property is owned by Encana Oil & Gas (USA), Inc. located at 2717 County Road 215, Suite 100, Parachute, Colorado 81635. 1.3 CONTACT INFORMATION Contact information specific to the Encana Oil & Gas (USA), Inc. facility for which this Plan has been drafted and implemented is provided in Table 1, Contact Information, located in the Tables section of this Plan. Emergency notification procedures (including contact information and phone numbers for the National Response Center, state, local entities, and cleanup contractors) are described in detail in the Oil Spill Contingency Plan (OSCP) located in Appendix B of this Plan. 1.4 MANAGEMENT APPROVAL AND COMMITMENT OF RESOURCES Encana Oil & Gas (USA) Inc. is committed to the prevention of discharges of oil to navigable waters and the environment through the implementation of spill prevention measures. This Plan is one part of that effort. Encana personnel identified below have been provided with specific responsibilities regarding spill prevention, control and countermeasures. As an authorized Encana employee, I approve this Plan and the commitment of resources to implement the Plan at the Story Booster Compressor Station. This resource commitment includes the manpower, equipment, and materials required to expeditiously control and remove any quantity of oil discharged that may be harmful. Encana Oil & Gas (USA) Inc. Signature: Date: Printed Name: _Brad Ankrum Title: Operation Field Leader The designated responsible person for spill prevention and cleanup at this facility is directly responsible for implementing this Plan and communicating the Plan to appropriate Encana 1-5 SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 personnel. The designated spill prevention individual for this facility reports directly to Encana management and is identified below. Signature: Date: Printed Name: _Vance Wilczek Title: _Field Operations Coordinator_ In addition, specific personnel are identified at the operations level as accountable for discharge prevention at this facility. The discharge prevention designee is listed below: Discharge Prevention Designee: Vance Wilczek Title of Designee: Field Operations Coordinator Contact Information for Designee: 970-285-2673 office 970-574-8936 cell 1.5 SUBSTANTIAL HARM CERTIFICATION A facility that could, because of its location, be expected to cause substantial harm to the environment by discharging oil into or on the navigable waters or adjoining shorelines is required to prepare and submit to the EPA Regional administrator a Facility Response Plan (FRP) in accordance with 40 CFR 112.20. The form(s) certifying the applicability of the substantial harm criteria for each facility covered by this Plan has/have been included in Appendix A. As noted in the completed form, the Story Booster Compressor Station does not meet the criteria for substantial harm and thus does not require a Facility Response Plan. 1.6 PROFESSIONAL ENGINEER CERTIFICATION I hereby certify that I am familiar with the provisions of 40 CFR 112, that I have reviewed this Plan and additional information provided by Encana Oil & Gas (USA) Inc., and that I or my agent have visited and examined the facility(s) that falls within the scope of this Plan. I attest that this Spill Prevention Control and Countermeasures Plan has been prepared in accordance with good engineering practice, including consideration of applicable industry standards, and with the requirements of 40 CFR 112, that procedures for required inspections and testing have been established, and that the plan is adequate for the facility(s). I attest that for produced water containers subject to 40 CFR 112.9(c)(6), any procedure to minimize the amount of free -phase oil is designed to reduce the accumulation of free -phase oil and the procedures and frequency for 1-6 SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 required inspections, maintenance, and testing have been established and are described in this Plan. This certification constitutes an expression of professional opinion and does not constitute a l or implied. 6/14/2011 Signature Date James B. Cowart, P.E. 5/31/2013 Printed Name of Registered Engineer SEAL Registration Expiration Date Encana acknowledges that the above certification in no way relieves the company of its duty to prepare and fully implement this Plan in accordance with 40 CFR 112. 1.7 PLAN LOCATION A complete copy of this plan is maintained at the Story Booster Compressor Station Control Room. Also, the Plan is maintained at the nearest field office at 2717 County Road 215, Suite 100, Parachute, Colorado 81635. This Plan is available for on-site review during normal working hours at this location. 1-7 SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 2.0 FACILITY DESCRIPTION This section provides detailed information regarding oil storage at the Story Booster Compressor Station. Figure 1 depicts the geographic extent of the scope of this Plan and Figure 2 shows the facility layout. 2.1 PHYSICAL LAYOUT, OPERATIONS, AND FACILITY DEFINITION The Story Booster Compressor Station is a natural gas compression facility. This facility transports 3-phase fluids (natural gas, produced water, and condensate) from the well pads to the Story Booster Compressor Station through flowlines, gathering lines, performs the initial liquid - gas separation, and then treats and compresses the natural gas for sale. The facility includes the metering equipment, dehydration, separation, above ground storage tanks, an exempt buried double -walled tank, and piping systems. A detailed facility diagram for this facility is provided as Figure 2. 2.2 BULK STORAGE CONTAINER DATA Bulk storage containers are used at this facility for the storage of oil and the container material and its construction are compatible with the material stored and the conditions of storage. The primary bulk storage tanks for the facility include a 400 bbl produced water/condensate tank, a portable compressor lube oil tank, and an exempt 50 bbl used oil tank (buried, double walled). Table 2, Bulk Storage Containers, provides specific information regarding the containers in service at this facility and includes the type of oil in each fixed container and its storage capacity. All tables referenced in section 2.0 are located at the end of the Plan. 2.3 SECONDARY CONTAINMENT AND DRAINAGE CONTROL General secondary containment is required, at a minimum, to contain the contents of the largest container inside the containment area, plus (if exposed to the weather) enough freeboard to hold a 24-hour, 25 -year storm event. General secondary containment at this facility is achieved through utilization of compacted earthen berm(s), retention swales, and other best management practices (BMPs). The bulk storage container(s) are located within synthetically lined steel vessel(s). Drip pans are used at the truck loading/offloading areas. The secondary containment calculation for the synthetically lined steel wall containment is provided in Appendix F. Sorbent material is stored on the facility to mitigate spills of oil from portable sources. The containment systems and procedures utilized are designed to be capable of containing oil and have been 2-1 SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 constructed so that any discharge from a container, such as a tank, will not escape the containment system before cleanup occurs. Table 3, Secondary Containment provides information regarding the types and capacities of secondary containment structures in place at the facility. Figure 2 shows the locations of all secondary containment structures and the general flow of surface drainage. Drainage from undiked areas within any tank battery, separation, and/or treating facility installations is confined in a berm, catchment basin or holding pond until inspected and managed. 2.4 ANALYSIS OF EQUIPMENT FAILURE Where experience has indicated a reasonable potential for equipment failure, an analysis of the typical modes of each type of major equipment failure has been performed. The results of the analysis have been recorded Table 4, Analysis of Equipment Failure. Although spills that occur within diked areas would likely be contained, predictions in the following table discount the presence of containment structures, per EPA guidance. In determining the method, design, and capacity of secondary containment structures, typical failure modes and the anticipated quantity of oil that may potentially be released were considered. 2.5 TEMPORARY, MOBILE, AND PORTABLE CONTAINERS Mobile, portable, or temporary containers such as frac tanks and drums may be utilized throughout the facility for storage of oil -containing liquids. During standard facility operations, a varying number of containers may be present in any given area. The anticipated capacity of a frac tank is 500 bbl and typically contains condensate or produced water. General secondary containment is provided for portable and temporary containers as required per 112.8(c)(11). The facility diagram provided as Figure 2 mark the storage areas where mobile, portable, and temporary containers are generally positioned when needed. 2.6 INTRA -FACILITY GATHERING LINES This facility utilizes intra -facility gathering lines. The installation of secondary containment may not be practicable at this facility due to the lines covering a large area within the facility and construction activities utilized for these facilities make secondary containment for piping impracticable. As equivalent environmental protection, the lines are routinely inspected, and procedures have been implemented to closely monitor transfer operations. Sections 3.0 and 4.0 of this Plan describe the inspections and monitoring 2-2 SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 program in greater_detail. In addition, an Oil Spill Contingency Plan (OSCP) has been implemented for this facility. 2.7 OIL -FILLED OPERATIONAL EQUIPMENT This facility utilizes oil -filled operational equipment. There are no oil -filled transformers on location. The oil -filled operational equipment maintained at this facility includes lubricating systems for the compressors and line heater(s). This equipment is located within the general secondary containment and site drainage controls and may be located within synthetically lined steel berms and/or steel troughs. The generator on location is powered by natural gas. Routine site visits include general visual inspections and observations. Periodic maintenance for the lubricating systems for the compressors and line heaters are performed on an "as needed" basis and based on the number of hours of operation. Sections 3.0 and 4.0 of this Plan describe the inspections and monitoring program in greater detail. 2-3 SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 3.0 INSPECTIONS, TESTING, AND MAINTENANCE 3.1 INSPECTIONS All inspections conducted to fulfill the requirements of this Plan are performed in accordance with the equipment -specific procedures outlined in the following sections. All inspections are performed by personnel who are knowledgeable in facility operations, the equipment being inspected, and the characteristics of the materials being processed, stored, or transferred. At a minimum, and as applicable to the specific container or pipeline, the following elements are evaluated during regularly scheduled container or vessel inspections: • Visual inspection of the container or vessel for signs of deterioration, leaks, overflows, or other problems • Visual inspection of foundations, supports, bottom seams, patches, flanges, piping connections, sight -glasses, and other openings for leaks, cracks, or other damage • Visual inspection of valves and thief hatches to ensure they are secured in their proper position The following sections describe the periodic inspections to be conducted for specific types of equipment. 3.1.1 Field -Constructed Aboveground Containers Field -constructed aboveground containers are not utilized at this facility. 3.1.2 Shop -Built Containers This facility utilizes shop -built containers that store 55 gallons or more of an oil -containing product or material. Shop -fabricated containers in use at the facility will have routine visual inspections performed at least once per month per the American Petroleum Institute (API) Standard 650, Standard for Welded Steel Tanks for Oil Storage. Once annually, a visual inspection will be performed on each shop -fabricated container subject to the requirements of this Plan. Shop -fabricated containers with over 5,000 gallons capacity shall also have a formal external inspection by a certified inspector at least once every 20 years in accordance with Encana's Integrity Management Program. 3-1 SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 These inspections shall be performed by personnel who are knowledgeable in facility operations, the tanks and associated components, and the characteristics of the liquids stored. The annual inspections are conducted by an interdisciplinary team trained to identify site-specific compliance concerns related to company policy and pertinent regulatory requirements. The EPA issued its SPCC Guidance for Regional Inspectors in November 2005. A section of that document (page 7-21, Section 7.3.4) states that for certain shop -built containers with a capacity of 30,000 gallons or less, the EPA considers visual inspection to be equivalent environmental protection to integrity testing. The containers must not be on contact with the soil; the containers may be elevated to make all sides, including the bottom, visible during inspection or be placed on adequately designed, maintained, and inspected barrier which would insure that a leak would be detected immediately. 3.1.3 Pressure and Flow-through Vessels Pressure vessels and/or flow-through process vessels such as separators or slug catchers, are utilized at this facility. All pressure vessels are visually inspected in accordance with the following procedures. The slug catcher at the Story Booster Compressor Station is visually inspected on a monthly and annual basis. In addition, formal internal and external inspections will be performed according to API 510, Pressure Vessel Inspection Code: Maintenance, Inspection, Rating, Repair, and Alteration, by a certified inspector in accordance with Encana's Integrity Management Program. 3.1.4 Produced Water Pits/Ponds Produced water pits and/or ponds are not utilized at this facility. 3.1.5 Portable Containers This facility periodically utilizes portable containers that have the capacity to store 55 gallons or more of an oil -containing product or material such as diesel trailers or frac tanks. Portable, mobile, and temporary containers including frac tanks are often used to store condensate and produced water at the facility. When in active use, portable containers will be visually inspected on a daily or weekly basis and, for longer-term projects, monthly basis in accordance with the inspection procedures described in Section 3.1.2 for shop -built containers. 3-2 SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 3.1.6 Above -ground Piping External visual inspections of facility piping including gathering lines and produced water delivery lines will be performed on a regular basis for aboveground portions of the lines. Appurtenances associated with the lines, such as pipe supports, valves, and rod stuffing boxes, are also evaluated during the line inspections. The above -ground piping, both temporary and permanent, that are actively being utilized to transfer oil -containing product or material will be inspected on a routine basis. Daily inspections occur by operations personnel to observe the lines and associated structures and equipment for conditions that could lead to a discharge. Underground sections of pipelines will be visually inspected whenever exposed during excavation work. General procedures used during the above -referenced inspections include a visual evaluation of the lines and associated structures and equipment for: • leaks or other oil discharges • signs of corrosion • loose bolts or missing plugs • accumulation in drip pans • general physical condition of the equipment. 3.1.7 Field Drainage Systems Field drainage systems such as road ditches and drainage ditches, including any oil traps, sumps, or skimmers, will be inspected at regular intervals by operations personnel. Drainage ditches and other drainage -related structures, including catchment basins, weirs, culverts and sumps, as applicable, will be inspected for any problems that may impede drainage of storm waters and for any accumulations of oil. Accumulations of oil will be removed promptly. Facility drainage system inspections will be recorded, and the records maintained per the requirements of Section 8.0 of this Plan. 3.1.8 Inspection Schedule and Documentation Documentation for individual equipment items will be maintained at Encana's Parachute, Colorado office. Completed inspection records will be maintained with a copy of this Plan in accordance with Section 8.0 and will be available for review at Encana's Parachute, Colorado office. Corrective action will be taken when deficiencies are noted during any inspection or if 3-3 SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 evidence of a discharge is observed. All observed oil discharges will be promptly removed. Releases noted during routine inspections will be documented in Encana's Incident Management System (IMS). In response to a discharge, facility personnel utilize Encana's IMS to document and track the event. The IMS is a web -based application for reporting and managing all incidents electronically, including injuries, spills, motor vehicle accidents, and most other types of occurrences. IMS facilitates the centralized first report, the workflow process for investigating incidents and assigning corrective actions, and generates reports for analyzing the occurrence of incidents so that risks can be analyzed and preventive measures can be put in place. 3.2 MAINTENANCE AND TESTING 3.2.1 Above -ground Piping Maintenance and Monitoring To reduce the potential for discharges, Encana operates a program of above -ground piping monitoring and maintenance. These lines are maintained in accordance with established facility integrity management protocols. Such management practices include standards for the selection, installation, monitoring, and maintenance of above -ground piping as well as associated valves, flanges, and other equipment. All maintenance activities are performed by personnel who are knowledgeable in facility operations and the equipment being maintained. Procedures for the maintenance of the above -ground piping subject to the requirements of this Plan include the following. • Prior to installing, replacing, or repairing lines, valves, or associated equipment, facility personnel must ensure compatibility with the materials to be transferred and address potential concerns involving corrosive production fluids, volumes, pressure, and other conditions expected in the operational environment. • Above -ground piping is identified on facility maps and are clearly marked in the field to facilitate access and inspection by facility personnel. • Where practicable, pipeline pressure is monitored during transfers by personnel having the ability to remotely close isolation valves in the event of an emergency. • As soon as practicable following the detection of a leak, the affected portion of the line is isolated and repaired or replaced. 3-4 SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 The maintenance and testing procedures referenced above are performed on individual sections of lines at a frequency determined by the facility mechanical integrity team. The frequency for maintaining and testing lines located within secondary containment is based on several factors, including the age of the pipeline, known or suspected corrosion issues, materials used in construction, number of elbows, expansions, contractions, etc. The frequency and type of testing prescribed for above -ground piping that have not been provided with secondary containment will be executed so that the Oil Spill Contingency Plan (OSCP) located in Appendix B may be effectively implemented. In the event that an inspection or test identifies either the need for repair or evidence of a discharge, corrective action shall be implemented accordingly. For example, any oil discharges associated with pipelines or associated equipment shall be promptly removed. 3.2.2 Container Maintenance and Testing The installation of new tank batteries or other containers subject to the requirements of this Plan, as well as updates to existing oil containers tanks must be performed in accordance with good engineering practice to prevent discharges. At least one of the following shall be provided for new containers or when updating existing containers: • Container capacity adequate to assure that a container will not overfill if a pumper/gauger is delayed in making regularly scheduled rounds, • Overflow equalizing lines between containers so that a full container can overflow to an adjacent container, • Vacuum protection adequate to prevent container collapse during a pipeline run or other transfer of oil from the container, or • High level sensors to generate and transmit an alarm signal to the computer if the facility is subject to a computer production control system. 3.2.3 Maintenance and Testing Schedule and Documentation Maintenance and testing schedules for individual equipment will be maintained at Encana's Parachute, Colorado office. Records of inspections, tests, and corrective actions will be maintained as described in Section 8.0 of this Plan. Releases resulting from the failure of containers, pipelines or other equipment will be documented in Encana's Incident Management System (IMS). 3-5 SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 4.0 OIL HANDLING PROCEDURES The following sections describe the discharge prevention measures that have been established and implemented at this facility to aid in preventing oil releases. 4.1 LOADING AND UNLOADING AREA(S) This facility does utilize a loading and/or unloading area to periodically recover produced water from the bulk storage tanks. 4.2 LOADING AND UNLOADING PROCEDURES When possible, loading and unloading areas located at the side where tank trucks deliver and pick up product, produced water, and condensate will be provided with general secondary containment. General procedures implemented at the facility(s) for the routine loading and unloading of oil products (fuel, lubricating oils, etc.) and oil -containing materials (produced water, condensate, etc.) into and out of cargo vehicles are described below: • Park vehicle (upwind, if possible) and set brakes • Use wheel chocks or equivalent measures to prevent unexpected movement • Connect ground cable to unpainted surface on vehicle frame • Check hoses and couplings for damage • Connect loading/unloading hose and vent line to vehicle; if vent line is absent, open all appropriate valves in storage tank and trailer • Position spill bucket or similar drip catch • Close valve to storage tank • Loosen loading hose to allow enough air to drain loading hose dry • Ensure that any drips from the hose drain into the spill bucket or drip catch • Disconnect loading hose completely, close load valve, plug and fasten securely • Ensure that any drips from the hose drain into the spill bucket or drip catch • Close all valve caps, disconnect hoses, and safely manage any remaining liquids 4-1 SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 • Replace all valve caps after pumping is finished and make sure all connections are isolated and capped, and install any required seals • Disconnect ground cable • Inspect lowermost drains and valves of the vehicle for discharges/leaks and ensure that they are tightened, adjusted, or replaced as needed to prevent discharges while vehicle is in transit • Inspect truck and unloading area to ensure that there have been no spills and the truck is ready for departure 4.3 INTRA -FACILITY TRANSFER PROCEDURES General procedures implemented at the facility for the routine transfer of oil products (fuel, lubricating oils, etc.) and oil -containing materials (produced water, condensate, etc.) into and out of cargo vehicles are described below: • Prior to transferring material from one vessel to another, check level readings to ensure there is adequate space available in the receiving tank • Monitor all material transfer operations closely (checking lines, pumps, hoses, etc. for proper operation and signs of leakage) • Prior to, during, and following their use, produced water delivery lines are inspected for leaks, oil discharges, corrosion, and other conditions that could lead to a discharge • Use absorbent pads, pans, buckets, etc., as needed to prevent drips from contacting the ground. 4.4 DRAINAGE CONTROL PROCEDURES Following a significant storm event, to ensure adequate capacity is available to contain a release operators overseeing processes where sized containment areas are present work to minimize (to the maximum extent possible) the presence, extent, and duration of standing water within the structure. Procedures implemented at the facility for the routine drainage of secondary containment structures and equipment includes the following: • Prior to releasing accumulated water to the ground, field drainage system, or other location external to facility operations, visually inspected the water for signs of possible contamination (an accumulation of oil, visible sheen, unusual color change, etc.). If 4-2 SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 accumulated oil is observed, remove the oil and return it to storage or dispose of it in accordance with legally approved methods (water containing oil must not be released). • Manually control and secure secondary containment drainage valves (where present) in the closed position until a release has been authorized by a responsible member of management. Reseal bypass valves immediately following completion of drainage. • Maintain adequate records of diked area drainage events. • Manage material collected in portable secondary containment equipment such as drip pans and buckets appropriately and do not released to the ground. • Facility drainage from undiked areas subject to spill events should if possible, flow into holding ponds or catchment basins designed to retain spills or return them to the facility. Catchment basins should not be located in areas subject to flooding. • At tank batteries and separation and treating areas where there is a reasonable possibility of a discharge, maintain closed and sealed drains for dikes, ponds, sumps, and other such containment structures; except when draining uncontaminated water. 4-3 SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 5.0 COUNTERMEASURES AND SPILL RESPONSE Facility -specific procedures for discharge discovery, response, and cleanup are provided in the Oil Spill Contingency Plan (OSCP) located in Appendix B of this Plan. The OSCP provides information and procedures for reporting a discharge, for taking initial actions to mitigate the effects of the discharge, to determine if evacuation is needed, and for ensuring that recovered materials are disposed of in accordance with applicable legal requirements. Finally, the OSCP also identifies the person at the facility who is accountable for discharge prevention and who reports to facility management. 5-1 SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 6.0 TRAINING Encana field staff receives general awareness training regarding oil spill prevention, control, and countermeasure planning as part of the company's orientation program for all new employees and contractors. In addition, facility management has identified personnel who, at the facility level, transfer or otherwise manage produced water or condensate, lubricating/compressor oils, used oil, or any other oil as part of their job function. Such employees have been designated as "oil -handling personnel" and are provided with additional training in the following: • The operation and maintenance of equipment to prevent discharges • Discharge procedure protocols • Applicable pollution control laws, rules, and regulations (including local, state, and federal requirements) • General facility operations • The contents of this SPCC Plan. In addition, at least once per year, oil -handling personnel are required to attend a discharge prevention briefing. The briefing must highlight and describe any known discharge that has occurred at the facility within the past year, equipment failures, malfunctioning components, and any recently developed precautionary measures. For purposes of this briefing, a discharge relates to the release of oil in sufficient quantities to cause a violation of water quality standards, results in a visible sheen on the surface of the water, or causes an emulsion or sludge to be deposited beneath the water. This briefing is intended to assure adequate understanding of the purpose, content, and use of this Plan. Training is conducted through EnCana's training and recordkeeping system, eCademy. Training records are maintained in the eCademy system for general awareness and oil -handling personnel training, discharge prevention briefings, or any additional training events performed in accordance with the requirements of this Plan. 6-1 SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 7.0 PLAN MAINTENANCE 7.1 AMENDMENTS BY OWNERS OR OPERATORS This Plan will be amended whenever there is a change in facility design, construction, operations, or maintenance that materially affects the facility's potential for a discharge. An amendment to this Plan shall be prepared within 6 months of the change and implemented as soon as possible, but not later than 6 months following preparation of the amendment. This Plan shall be reviewed and evaluated at least once every 5 years and amended to include more effective prevention and control technology, if such technology will significantly reduce the likelihood of a discharge event and has been proven in the field. Any amendment made for the reasons described in the prior sentence must be implemented as soon as possible, but not later than 6 months following preparation of the amendment. The completion of all reviews and evaluations must be documented with a signed statement. The amendment log located in Appendix D shall include a statement that the reviewer has completed a review and evaluation of the SPCC Plan for the given facility on a specific date and that the Plan will or will not be amended as a result. All technical amendments made to this Plan shall be certified by a registered Professional Engineer. Plan reviews and amendments to facility specific documentation will be recorded in Appendix B and scheduled and tracked using Encana's IMS. 7.2 AMENDMENTS BY REGIONAL ADMINISTRATOR If either of the following occurs: • The facility discharges more than 1,000 gallons of oil into or upon navigable waters or adjoining shorelines in a single event or • The facility discharges more than 42 gallons of oil in each of two discharge events within any 12 -month period, The facility will submit within 60 days of the above event(s) the following information to the U.S. EPA Regional Administrator and the Colorado Department of Public Health and Environment (CDPHE): 7-1 SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 • Name of facility • Your name • Location of facility • Maximum storage or handling capacity of the facility and normal daily throughput • Corrective action and countermeasures you have taken, including a description of equipment repairs and replacements • An adequate description of the facility, including maps, flow diagrams, and topographical maps, as necessary • The cause of such discharge, including a failure analysis of the system or subsystem in which the failure occurred • Additional preventive measures you have taken or contemplated to minimize the possibility of recurrence • Such other information as the Regional Administrator may reasonable require pertinent to the Plan or discharge. This Plan shall be amended as required by the Regional Administrator as a result of review of the information submitted. 7-2 SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 8.0 RECORDKEEPING Written procedures associated with the inspection and testing activities conducted per the requirements of this Plan will be maintained within or as an attachment to this Plan. Along with the referenced procedures, records of inspections and tests required by this Plan will be signed by the appropriate supervisor or inspector and retained for a period of three years as routine and customary business practice. Inspection records and associated information will be maintained with a copy of this Plan at Encana's Parachute, Colorado office. Records of training events conducted in accordance with the requirements of this Plan are maintained in Encana's eCademy system. 8-1 SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 9.0 CONFORMANCE WITH 40 CFR 112 AND STATE SPCC REQUIREMENTS AND NEEDED MODIFICATIONS This section includes a discussion of the overall conformance of the facility and Plan with the requirements of 40 CFR 112 and any state rules, regulations, and guidelines pertaining to oil spill prevention, control, and countermeasure that provide additional or more stringent requirements than the federal rules. 9.1 CONFORMANCE WITH RULE REQUIREMENTS AND NEEDED MODIFICATIONS The structures, equipment and operations associated with the facility identified in Section 2.1 of this Plan. The operations and equipment covered under this SPCC Plan comply with the requirement stated in 40 CFR 112, the Colorado Department of Public Health and Environment, and the Colorado Oil and Gas Commission. The Oil Spill Contingency Plan for the Story Booster Compressor Station and the BMPs put in place for surface drainage control are sufficient alternatives to address potential oil discharges and spills. 9.2 CONFORMANCE WITH STATE -SPECIFIC SPCC REQUIREMENTS Some states have established requirements applicable to SPCC that are more stringent than federal standards or require additional measures to be taken. In the State of Colorado, no state agencies govern the SPCC activities of the oil and gas industry. However, the COGCC provides specific guideline for secondary requirements for oil storage containers located in "high" density area. The requirement for secondary containment in high density areas is 150 percent compared to 110 percent for EPA SPCC. The Story Booster Compressor Station is not located in a high density area. 9-1 SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 TABLES SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 Table 1 — Contact List Contact List Encana's 24 -Hr Environmental On- call Service Personnel must immediately report all spills and conditions which could lead to a spill to Encana's 24 -hr Environmental On-call number. 970-319-9173 Encana's 24 -Hr Safety On-call Service Personnel must immediately report all incidents and conditions which could lead to an injury to Encana's 24 -hr Safety On-call number. 970-210-8755 Facility STORY BOOSTER COMPRESSOR STATION Facility Supervisor VANCE WILCZEK 970-285-2673 970-574-8936 CELL SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 Table 2 — Bulk Storage Containers Story Booster Compressor Station Bulk Storage Container ID Location Contents Volume (barrels)* Construction Materials** Overfill Protection TANK #1 SOUTH OF PRODUCED 400 STEEL HIGH ALARM WATER/ COMPRESSORS VISUAL PART OF CONDENSATE GAUGE GAUGE USED OIL NEAR USED OIL 50 STEEL/DOUBLE HIGH ALARM TANK COMPRESSORS WALL (BURIED) VISUAL (EXEMPT) GAUGE LUBE OIL NEAR LUBE OIL 12 STEEL VISUAL TANK COMPRESSORS GAUGE METHANOL NEAR WATER METHANOL 12 PLASTIC VISUAL TANK CROSS-OVER GAUGE (EXEMPT) SKID ANTIFREEZE NEAR ANTIFREEZE 12 PLASTIC VISUAL TANK COMPRESSORS GAUGE (EXEMPT) * If units differ (i e. gallons vs. barrels), specify in each individual cell, or convert all to the same unit for the facility. ** Oil storage containers must be constructed appropriately and of materials that are compatible with the material stored and the conditions of storage. *** The methanol, underground used oil, and antifreeze tanks are listed but are not SPCC regulated. Table 2A — Flow Through Pressure Vessel (Slug Catcher) Story Booster Compressor Station Bulk Storage Container ID Location Contents Volume (barrels)* Construction Materials** Overfill Protection SLUG NORTH PRODUCED 80 STEEL HIGH ALARM CENTRAL WATER/ VISUAL CATCHER PART OF CONDENSATE GAUGE FACILITY SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 Table 3 — Secondary Containment (Oil -containing only) STORY BOOSTER COMPRESSOR STATION Secondary Containment Structure Containers Available Capacity (Bbls) Construction Material BULK STORAGE PRODUCED 786 BBLS STEEL (LINED) WATER/CONDENSATE CONTAINMENT A (TANK #1) BULK STORAGE — OIL USEDUSED 50 DOUBLE- OIL (EXEMPT) WALLED TANK BULK STORAGE — 8' LUBE OIL 16.3 STEEL DIAMETER STOCK (UNLINED) TANK * Available capacity must account for freeboard for 24 hour, 25 year storm event ** Containment not sufficient SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 Table 4 - Analysis of Equipment Failure STORY BOOSTER COMPRESSOR STATION (400 BBL TANK) Potential Failure Spill Direction (Cardinal Direction) Potential Total Volume Released [gallons] Potential Spill Rate [gallons/minute] Catastrophic failure of full tank South -Southwest 16,800 4000 Partial failure of tank South -Southwest 2,000 200 Tank overfill South -Southwest 200 20 Pipe fitting failure South -Southwest 50 15 Leaking fitting or valve South -Southwest 50 15 STORY BOOSTER COMPRESSOR STATION (SLUG CATCHER) Potential Failure Spill Direction (Cardinal Direction) Potential Total Volume Released [gallons] Potential Spill Rate [gallons/minute] Catastrophic failure of slug catcher South -Southwest 3,360 1000 Partial failure of tank South -Southwest 1,000 200 Tank overfill South -Southwest 200 20 Pipe fitting failure South -Southwest 50 15 Leaking fitting or valve South -Southwest 50 15 STORY BOOSTER COMPRESSOR STATION (LUBE OIL) Potential Failure Spill Direction (Cardinal Direction) Potential Total Volume Released [gallons] Potential Spill Rate [gallons/minute] Catastrophic failure of slug catcher South -Southwest 500 500 Partial failure of tank South -Southwest 100 50 Tank overfill South -Southwest 10 5 Pipe fitting failure South -Southwest 10 5 Leaking fitting or valve South -Southwest 10 5 SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 FIGURES SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 Figure 1 — Facility Location Map A03 CDP 1 A03 003 (Story Booster CS) Story Booster Compressor Station (003 Well Pad) 01 OA T005S-R095W T005S-R096W D19A K22 L J22 J22B fie d 1?« r n t '�� Access Road EnCana Pipeline Route C3 EnCana Site Boundary Township Boundary Parcel Boundary Surface Ownership EnCana (transparent) BSM (transparent) MFWTF (Upper.Level) encana. natural gas 0 2,100 4,200 1 inch = 3,000 feet r Story Booster Compressor Station North Parachute Properties Garfield County, Colorado Revised: May, 2011 Jnr C04 SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 Figure 2 — Facility Layout Diagram Q a m c Pad Boundary o (Includes earthen a) berm and retention swales) v) a1► 0 Z fo1 co 50 bbl used oil t. k a a2C`y (double -walled, b ied) oc yco 0 � Qw 003 well heads' and 3-I .. o� �m 0 phase gathering system Containment A UOa U h covered under/separate I (2.5' Tall 0m I SPCC Plan I Metal berm) Control Room Pad Boundary 'p Water Cross -Over Skid Well Heads Generator (natural gas powered) e// p aas- .c 0 U Revision Date: 04/24/2011 Drawing Not to Scale Liquids-to,3-Phase Gathering stock tanks (2' depth) RTU to T1 — 400 BBL (12' x 20') Produced Water/Condensate 8S63201-08 Story Booster Compressor Station/ 003 Well Pad SWSE - Section 3 - T5S/R96W - 6th PM Garfield County, CO SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 APPENDIX A CERTIFICATION OF THE APPLICABILITY OF SUBSTANTIAL HARM CRITERIA SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 CERTIFICATION OF THE APPLICABILITY OF THE SUBSTANTIAL HARM CRITERIA CHECKLIST FACILITY NAME: STORY BOOSTER COMPRESSOR STATION FACILITY ADDRESS: SWSE Section 3, T5S, R96W, 6th PM 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 oil 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 formula in Attachment C -III, Appendix C, 40 CFR 112 or a comparable formulal) 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 I, II, and III to DOC/NOAA's "Guidance for Facility and Vessel Response Environments" (Section 10, Appendix E, 40 CFR 112 for availability) 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 (Attachment C -III, Appendix C, 40 CFR 112 or a comparable formulal) 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 SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 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, I believe that the submitted information is true, accurate, and complete. Name (please type or print): Signature: Title: Date: Footnotes: From 40 CFR 112 Appendix C, Attachment C -II 1. If a comparable formula is used, documentation of the reliability and analytical soundness of the comparable formula must be attached to this form. 2. 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). SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 APPENDIX B OIL SPILL CONTINGENCY PLAN Encana DI & Gas (USA) Inc.. Oil Spill Contingency Plan - Story Booster Compressor Station Oil Spill Contingency Plan (Oil Pollution Prevention — 40 CFR Parts 109 and 112) Story Booster Compressor Station Parachute Creek Surface Water Supply Area — Colorado River DeBeque Surface Water Supply Area — Colorado River Piceance Creek Surface Water Supply Area — White River Encana O I & Gas (USA) Inc. 2717 County Road 215, Suite 100 Parachute, CO 81635 April 20, 2011 encana Encana Oil & Gas (USA) Inc. Oil Spill Contingency Plan _. Story Booster Compressor Station Table of Contents Table olContents List of Tables List of Figures List of Appendices ii INTRODUCTION 1 ENCANA'S MANAGEMENT COMMITMENT 1 OIL SPILL RESPONSE PROCEDURES .. 2 Response Management Structure 2 Spill Response Procedures 2 Table 1 - Oil Spill Response Procedures 4 OIL SPILL REGULATORY NOTIFICATION PROCEDURES 6 Verbal Notifications to Government Agencies 6 Information to Provide During Verbal Notifications ,.. 7 Written Notifications to Government Agencies 8 Stale Agencies 8 Federal Agencies 9 CONTACT INFORMATION AND NOTIFICATION PROCEDURES 10 RESOURCES, EQUIPMENT, AND SUPPLIES FOR OIL SPILL RESPONSE 15 INCIDENT TERMINATION. ............... 15 ENCANA'S NOR`FH PARACHUTE PROPERTIES WATER QUAILITY PROGRAM.... 16 List of Tables Table I - Oif Spill Response Procedures Table 2 - Equipment Shutdown Procedures Table 3 - Notification Procedures and Contact Information Table 4 - Contractor Contact information Table 5 - Additional Government Agency Phone Numbers Table 6 - Additional Encana Personnel Contact Information encana Encana Oil & Gas (USA) Inc Oil Spill Contingency Plan - Story Booster Compressor Station List of Figures Figure I - North Parachute Properties - SPCC Location Map with Spill Trailer and Spill Drum Kit Locations List of Appendices Appendix A - Spill '1 -railer Inventory and Spill Drum Kilt Inventory Appendix H - References (1 ncana's Spill and Fnvirnnmental Release Reporting Practice) C ncana ii Encana Oil & Gas (LISA) Inc. OH Spill Contingency Pian — Story Booster Compressor Station INTRODUCTION The Oil Spill Contingency Plan (OSCP) was prepared to meet the requirements of the Environmental Protection Agency's (EPA) Oil Pollution Prevention regulations codified in 40 CFR Parts 109 and 112. The purpose of this OSCP is to define procedures and tactics for responding to unintended discharges of oil originating from bulk storage containers, oil -filled and Clow -through equipment, and flowlines within Encana 011 & Gas (USA) Inc.'s (Encana) Story Booster Compressor Station. The Story Booster Compressor Station is located northwest of Parachute, Colorado and its geographic location is shown on Figure L These procedures are implemented whenever a discharge of oiI occurs. For the purposes of this Plan. the term "`oil" refers to oil -containing liquid (which could include but not limited to produced water, condensate, hydraulic fluids. compressor oil, etc.). The objective of these procedures is to protect the public. Encana personnel, and other responders during oil discharges. In addition. the procedures are intended to minimize damage to the environment. natural resources, and facility installations from a discharge of oil. ENCANA'S MANAGEMENT COMMITMENT Encana is committed to promptly respond to any oil spill which may occur at the Story Booster Compressor Station. This commitment includes both containment and cleanup of any spilled oiI with an emphasis on protection of the environment. including surface waters. As an integral part of the Spill Prevention, Control, and Countermeasure Plan (SPCC). this Oil Spill Contingency Pian is one part of that effort. ] approve this Gil Spill Contingency Plan and the commitment of resources needed to implement the plan. This resource commitment includes the properly trained personnel, equipment. and materials required to control and remove any quantity of nil discharged that may be harmful (40 CFR 1I2.7(d)). So mature: Date: Printed Name: Title: April 20. 201 1 l ncc'3na 1 Encana Oi! & Gas (USA) Inc. Oil Spilt Contingency Plan - Story Booster Compressor Station OIL SPILL RESPONSE PROCEDURES Response Management Structure The Environmental Compliance Group (ECU) on behalf of Encana is responsible for implementing response procedures in the event of an oil spill or environrnental release. These personnel have the authority to commit the resources necessary to carry out a response, and have training and experience in coordinating and managing spill response and clean up efforts. ECU personnel are trained on the Environmental Release Response Standard Operating Procedures (SOP), and have a minimum of 2 weeks "shadowing" experienced ECU personnel responding to incidents. The Environmental Release Response SOP is available at Encana's Parachute field office. All oil handling personnel for the Story Booster Compressor Station receive training on spill prevention. mitigation. and response, and are familiar with spill reporting and containment objectives. Training records are maintained at Encana's Parachute field office. For most spills the designated. Spill Coordinator will be the representative from Encana's ECU who is currently on call. If a spill falls outside the scope of a normal response (i.e. has impacted or threatens to impact waters of the state, has caused a fire, or poses an imminent threat to the safety of Encana personnel or the public): the Authorized Facility Representative may designate a senior Encana employee to act as the Incident Commander. and Encana's Emergency Response Plan (ERP) would supersede the Oil Spill Contingency Plan (Emergency Spill Response Program). The ER# is available in Encana's Parachute field office. Should a spill reach waters of the state, Encana's ECG will provide initial containment and clean up consistent with Encana's Oil. Spill Response Manual (available in the Parachute field office)_ and will coordinate with local, state, and federal agencies should a more extensive effort be required. Spill Response Procedures Spills are generally discovered during normal operations or during the formal inspections carried out in compliance with Encana's Annual Regulatory Compliance (ARC) Inspections. In addition to the ARC inspections, Encana's facilities are routinely monitored as part of various tasks (stormwater inspections. maintenance, security checks, etc.). In the event of a spill, all Encana employees and contractors are required to call the Environmental 24-hour On -Call Number (970.319.9173) and their supervisor immediately. If there is an immediate threat to the safety of the public or to operating personnel. local emergency response (911) and Encana-s Safety On - Call (970.21(1.8755) should be notified first. When reporting a spill. personnel should be prepared to supply the information detailed in the "Environmental On -Call Reporting Requirement" portion of Table 1. This inforn-ration %;ill allow the on call representative from Encana's Environmental Compliance Group (ECU), now the Spill Coordinator. to make an over - April 20, 201 1 Encana GSI & Gas (USA) Inc 011 Spill Contingency PIan -- Story Booster Compressor Station the -phone assessment of the magnitude of the spill, The Spill Coordinator, will make required notifications to the Encana management structure, and mobilize any additional resources which may be required to respond to the spill appropriately. After required notifications have been made to Encana management, the Spill Coordinator may travel to the spill location to provide a more comprehensive assessment of the situation; mobilize additional resources if necessary; and. provide guidance to clean up crews. Table 1 provides the basic steps in Encana's Oil Spill Response Procedures. The response action taken may vary depending on the severity of the oil spill. Stopping or shutting down the source of the spill is a prince factor in gaining control and mitigating the environmental incident. Equipment must be shut down promptly (such as shutting in a well supplying oil to a flowline or tank battery). Temporary land-based containment measures include putting up berms or dikes across low areas, digging diversion ditches or trenches to intercept overland oil clow or putting barriers or weirs across stormwater ditches. Every effort will be made to keep oil from reaching surface waters. In the event that oil reaches surface water. boons or barriers can be placed to collect oil and prevent further impacts. Impounded oil can be removed by skimming with sorbent pads or by vacuum trucks. A large uncontrolled spill that has the potential to reach surface water may necessitate securing contactor resources with specialized equipment fbr an effective response. Table 2 references the general shut down procedures based on various sources of a spill or discharge. Equipment shut -down operations may only be carried out by personnel qualified to operate the affected equipment. 'The employee or contractor who reports the spill, must, depending on circumstances, be present at the site, or available by cell phone, when the Spill Coordinator arrives on scene. All operating personnel have been trained on spill containment techniques, and the deployment of spill response equipment and materials to provide initial spill response and management until the Spill Coordinator arrives. April 20, 2011 encana Encana Gil & Gas (USA) Inc. OH Spill Contingency Plan — Story Booster Compressor Station Table 1 — Oil Spill Response Procedures Spill Discovery and Initial Response Spill Containment, Clean Up, and Reporting 1. If no immediate threat to safety is present and the source of the release is still present; stop the source of the release using the Equipment Shutdown Procedures detailed in Table 2 and call the Encana Gas Control number (976.285.2615) 2. Contain the release using available materials and methods. Including berms. dykes, and spill kit materials. 3. Restrict ignition sources if the material is flammable, 4_ Secure the area as off limits_ 5. In the event that the spill poses an immediate threat of fire, explosion, or other imminent threat to public safety: call local emergency response (911y_ DO NOT HANG UP after completing the report, let the dispatcher hang up first. 6. Report the spill to the Environmental 24hr On -Call Number (970.319.9173). The on- call member of the Environmental Compliance Group is the Spill Coordinator. Be prepared to provide the following information. 7 Has the spilt reached, or does It threaten to reach, waters of the state? 8 Where is the spill (nearest pad/facility and field)? Be prepared to provide directions. 9. Which personnel were present at the time of tl»e spill'? 10. What activities caused the spill? 11 When did the spill occur? 12 What is the material spilled? 13,. Whal volume has spilled? 14. The employee or contractor who reports the spill, must, depending on circumstances, be present at the site. or available by cell phone, when the Spill Coordinator arrives on scene. 15. The Spill Coordinator will notify Encana management of the spill and may mobilize response resources based on the scope described In the initial report. 16, The Spill Coordinator will travel to the incident location and conduct a comprehensive assessment of the spill, and coordinate clean up efforts_ 17. If necessary, a follow up report to Encana management, and verbal notification of government and municipal agencies and other appropriate entities will be made. 18. Should additional remediation efforts be necessary, the Spill Coordinator will contact one of Encana`s designated spill remediation contractors. 19. If the spill is determined to be of a reportable quantity or character, the Spill Coordinator will complete required verbal notifications and submit appropriate written notifications and reports to appropriate agencies as outlined below in notification procedures. 20. The Spill Coordinator will enter the incident into Encana's Incident Management System, and identify appropnate follow up activities and/or corrective actions April 20. 2011 encana Encana Oil & Gas (USA) lrc. Oil Spill Contingency Plan — Story Booster Compressor Station Tahle 2 — Ega<r,Pmein Shutdown Procedures Source Action Manifold, transfer pumps or hose failure Have a qualified person shut in the well supplying oil to the tank battery if appropriate. immediately close the headerlmanifold or appropriate valve(s). Shut off transfer pumps_ Tank overflow Have a qualified person shut in the well supplying oil to the tank battery. Close headerlmanifold or appropriate valve(s). Tank failure Have a qualified person shut in the well supplying oil to the tank battery. Close inlet valve to the storage tanks. Flowline rupture Have a qualified person shut in the well supplying oil to the ftowline. Close nearest valve to the rupture site to stop the flow of oil. Flowfine leak Have a qualified person shut in the well supplying oil to the flowiine_ Immediately close the nearest valve to stop the flow of oil to the leaking section_ Explosion or fire Immediately evacuate personnel from the area and secure the area from entry by the public or other personnel. Have a qualified person immediately shut in all wells if safe to do so. If possible. close all manifold valves. If the fire is small enough such that it is safe to do so, attempt to extinguish with available fire extinguishers. Equipment failure Have a qualified person immediately close the nearest valve to stop the flow of oil into the leaking area. April 20.20 I 1 encana S Encana Oil & Gas (LISA) Inc Oil Spill Contingency Plan - Story Booster Compressor Station OIL SPILL REGULATORY NOTIFICATION PROCEDURES This section provides reportable quantities for exploration and production (E&P) waste_ In the event of a release, government agencies may need to be notified. ;411 verbal and written notifications are to be made by the Envirorunental Compliance Group or designate(s). As a practical matter, an evaluation of the specifies of each spill and a determination of reporting requirements will be made. If there is any question about reporting, Encana will over -report rather than under -report. Table 3 provides an overview of reporting requirements, procedures, and contact information for Encana departments and relevant government agencies_ Verbal Notifications to Government Agencies Encana's policy is to report all spills on public lands administered by the Bureau of Land Management (I3LM) or US Forest Service (USPS) to the affected agency as soon as practicable. If a release has reached, or has the potential to reach. waters of the state, or a municipal drain or storm sewer; verbal notifications must be made as soon as possible to Local Emergency Response (411), the National Response Center (NRC) Hotline, Colorado State Patrol, Local Emergency Planning Commission (LEPC), Colorado Oil and Gas Conservation Commission (COGCC). Colorado Department of Public Health and Environment (CDPI-IE) - Colorado Water Quality Control Division, and any potentially affected landowner, municipal water company, or sewer authority and wastewater treatment plant. In the event of a spill/release which may threaten a residence, occupied structure, livestock, or public right-of-way; verbal notifications must be made as soon as practicable to Local Emergency Response (911), the COGCC, CDPI-IE, and any potentially affected landowner. In addition. the COGCC further requires verbal notification within 24 hours for spills/releases of exploration and production (E&P) waste which exceed 20 barrels. April 20, 2011 encana 6 Encana Oil & Gas (USA) Inc. OH Spill Contingency Plan - Story Booster Compressor Station information to Provide During Verbal Notifications When notifying a government agency of a release, the following information should be gathered as soon as possible and provided as necessary: 1. Name and location of the facility. Be prepared to provide directions to the scene. 2. Specific location where the discharge occurred, 3. Your name. position, and telephone number. 4. Name and address of the owner/operator 5. Date and time of the discharge. 6. Information on the discharge: • Type of material discharged (e.g., diesel), • Source of discharge (e.g., aboveground storage tank), • Estimated total quantity discharged_ including the estimated total quantity discharged to navigable waters or adjoining shorelines, • Danger or threat posed by the release / discharge. • Weather conditions, • Cause of discharge, • Affected media (e.g., soil, surface water), and area of impact, • Damages or injuries caused by the discharge_ • Response actions being used to stop, contain, mitigate, or clean-up the discharge, • Time to contain the discharge, • Whether the discharge has been stopped_ and • Whether an evacuation may be needed. 7_ Names of other individuals or agencies that were contacted. 8. Other information that may help emergency personnel prepare for, and respond to the incident. 9. Navies and titles of government agency personnel who have reported to the scene_ Record the following information when making a notification: • Name and position of person contacted_ • Agency contacted_ • Date and time of notification. • Information provided to agency. April 20, 2011 encand 7 Encana fail & Gas (USA) inc. Oil Spill Contingency Pan - Story Booster Compressor Station Written Notifications to Government Agencies If a verbal notification has been made under any of the conditions provided above; a follow up written report will be submitted to the notified agency, following the guidelines provided in Table 3. Written reports will be made utilizing the agencies own reporting formats, when available. When a standard format is not provided by the agency being reported to; Encana will provide a report with the information mandated by the Environmental Protection Agency's (EPA) spill reporting requirements. In addition to follow up reports to verbal notifications, the Colorado Cil and Gas Conservation Commission (COGCC) requires written reports for spilled quantities less than those mandating verbal notifications, Those reporting requirements are detailed in COGCC Rule 906, and in the following section. State Agencies All spills and releases of E&P waste exceeding 5 barrels, including those contained within secondary containment. shall be reported in writing, within 10 days, to the COGCC using the Spill/Release Report (Form 19), Completed reports will be emailed to the appropriate COGCC regional representative or sent to the address provided in Table 3. All spills and releases of hazardous materials which exceed the Reportable Quantity (RQ) identified by CERCLA (Comprehensive Environmental Response. Compensation. and Liability Act) will be reported to the National Response Center (NRC) and CDPHE Hazardous Materials and Waste Management Division_ April ?ti,20tI encana B Encana Oif & Gas (USA) Inc OiI Spill Contingency Plan — Story Booster Compressor Station Federal Agencies 1n accordance with 40 CFR 112.4(a) a spill report will be submitted to the U.S, Environmental Protection Agency (EPA) Region 8 Administrator if either of the following conditions is met: • A single discharge, into or upon navigable waters of the United States, of more than 1,000 gallons of oil, or • A discharge, into or upon navigable waters of the United States, of more than 12 gallons of oil in each of two events within any 12 month period. The spill report to the EPA must be submitted within 60 days of the release and contain the following information: 1. Name of the facility. 2. Name of the owner/operator of the facility. 3. Location of the facility. 4. Maximum storage or handling capacity of the facility and normal daily throughput. 5. Corrective actions and countermeasures taken., including a description of equipment repairs and replacements. 6. An adequate description of the facility, including reaps, flow diagrams, and topographic maps, as necessary. 7. The cause of the discharge, including a failure analysis of the system or subsystem in which the fai l ure occurred. 8. Additional preventive measures taken or contemplated to minimize the possibility of recurrence. 9. Such other information as the U.S. EPA Regional Administrator may reasonably require pertinent to the SPCC Plan or discharge. A copy of the above information also must be submitted to the Colorado Department of Public Health and Environment (CDPIIE) in accordance with 40 CFR 112.4(c). Contact information is provided in Table 3. April 20, 2011 encana 9 Encana Oil & Gas (USA) lnc. Oil Spill Contingency Plan -- Story Booster Compressor Station CONTACT INFORMATION AND NOTIFICATION PROCEDURES Operating personnel tnust immediately report all spills to Encana's 24 -Hour Environmental On - Call Phone. Encana's Environmental Compliance Group (ECG) will determine the appropriate level of response, notify the Authorized Facility Representative, and if necessary, contact appropriate government agencies and assist in mobilizing resources. Environmental On -Call (24 hours) Safety On -Call (24 hours) Gas Control (24 hours) Public Relations / Land Department On -Call (24 hours) Doug Rosa — Authorized Facility Representative Local Emergency (fire, explosion, or other hazards) Table 3 — Notification Procedures and Contact Information 970319.9173 970.21 0.8755 970.285-2615 970.285.2777 970.285.2686 911 Agency 1 Organization Agency Contact 1 Circumstances When to Notify Federal Agencies National Response Center (NRC1 800.424.88]2 Discharge reaching waters of the state, or a municipal drain or storm sewer, or of releases of hazardous materials in excess of the Reportable Quantity (RO) Immediately (verbal) EPA Region VIII (Hotline) 800 227.8914 Discharge reaching waters of the state, ar a municrpal drain or storm sewer. Immediately iverbal) EPA Region VIII Regional Administrator 999 18"'' Street. Suite 500 Denver, CO 80202-2466 r8eis e a gov p' Follow up report to verbal notification' Discharge, into or upon navigable waters of the United States, 1.000 dischargesdiscussion gallons or more; or 2 of 42 gallons ar more within a 12 - month period. Written notification within 60 days (see the related above) Bureau of Land Ivfanagement (81111)GSEC}) 970.244.3070 (Grand Junction Field Office - GJFO) 970.947 5200 (Glenwood Springs Energy Office 970.878.3870 (White River Field Office — WRFO) Mater Undesirable Events immediately (verba)) Discharges on BLMIUSFS lands • > 100 BBL of liquids, 500 MCF gas, andlor . any release in a sensitive area (perks, ie[: areas, refuges. water bodies, l April 20. 2011 erc aria 10 Encana Oil & Gas (USA) Inc. Oil Spill Contingency Plan — Story Booster Corepressor Station Agency/Organization Agency Contact Circumstances When to Notify BLM Giro 2815 H Road 2815 Grand Junction. CO 81506 GSEO 2425 S, Grand Avenue, Suite 101 Glenwood Springs, CO 81601 WRFO 220 E. Market Street Meeker, CC 81641 Major Undesirable Events He an "Undesirable Event Form" with appropriate personnel at the affected Field Office. and Other-Than-Attaior Undesirable Events • following any verbal notification, or • Discharges on BLM1USFS lands: "J > 10 BBL of liquids. or o > 60 MCF of gas. BLM GJFO 2815 H Road Grand Junction, CO 81506 GSEO 2425 S. Grand Avenue, Suite 101 Glenwood Springs, CO 81601 WRFC] 220 E. Market Street Meeker, CO 81641 Spills or discharges in nonsensii#ve areas involving less than 10 BBL of liquid or 50 MCF of gas. Volume and value of losses must be reported on the "Oil and Gas Operations report" and on the "Report of Sales and Royalty Remittance" Agency t Organization 1 Agency Contact Circumstances When to Notify State Agencies Colorado Oil and Gas Conservation Commission iCOGCCl Environmental Release / Incident Discharge which reaches or threatens to reach waters of the state, a municipal drain or storm or any surface water supply area or intake (317B) Or which impacts or threatens to impact a residence/occupied structure, livestock, or public byway Immediately (verbal) Immediately Report Hotline 877.518.5608 and Chris Canfield 970.625.2497 (office) 970.216.6832 (cell) or Linda Spry O'Rourke 970.625,2497 (office) 970.309.3356 (cell) COGCC Chris Canfield Discharges of >20 bbls of Exploration and Production (E&Pl waste, or >25 gallons of refined hydrocarbons Within 24 hours 970.625.2497 (office) 970.216 6832 (cell) or Linda Spry O'Rourke 970.625.2497 (office) 970.309.3356 (cell) COGCC Chris Canfield Any discharge or release of E&P waste exceeding 5 bbls Written notification within 10 days using SpilltRelease Report IFarn 19) (lits Cartf#elrJgsteit co us or Linda Spry ()'Rourke Lk11343 S{r .1'0Ei 1WMit State- L>>_LIE COPHE 2d! }aur Emergency SpItllRelease Reporting Hotline 877 424 8832 Any discharge of hazardous materials in excess of the reportable quantity (RQ), or any arnourrt reaching waters of US, or a municipal drain or storm sewer. Verbal or written within 24 hours April 20, 2011 encana Encana Oil & Gas (USA) Inc. Oil Spill Contingency Pan — Story Booster Compressor Station Agency 1 Organization Agency Contact Circumstances When to Notify CDPHE 4300 Cherry Creek Drive South Denver, CO 80246 -1530 Follow up to verbal notification Discharge limits identified by the EPA. Submit duplicates of any report submitted to the EPA. Colorado State Patrol (CSP) 303.239.4501 Discharge reaching waters of the state, or a municipal drain or storm sewer, or directly affecting a public byway Immediately (verbal) Local Agencies Emergency Response 911 Discharge reaching waters of the state, or a municipal drain or storm sewer. If there is an immediate threat to the safety of the public or operating personnel Immediately (verbal) Mesa County Emergency Planning Committee (LEPC) Horace Sessions 970.245 8148 npr4ce.5e5slorsrtu ler cone Discharge reaching waters of the state, ora municipal drain or storm sewer in Mesa County. Immediately (verbal) Written follow up within 7 days. PD Box 2242 Grand Junction, CO 81502 Garfield County Emergency Planning Committee (LEPC) Chris Bomholdt 970.945.8020 chornholdti ctarfield-countv_c' rn Discharge reaching waters of the state, or a municipal drain or storm sewer in Garfield County. immediately (verbal) Written follow up within 7 days. 109 8111 Street, Suite 300 Glenwood Springs, CO 81601 Rio Blanco County Emergency Planning Committee (LEPC) John Hutchins 970.878 5023 Jhutch nsi co rtc•blanco.co_us Discharge reaching waters of the state, or a municipal drain or storm sewer in Rio Blanco County Immediately (verbal) Written follow up within 7 days_ PO Box 647 Meeker, CO 81641 Puthc Water Intakes / Surface Water Supply Areas Parachute Public Warks {Parachute Creek Colorado River) Emergency - 24 hr. Discharge which impacts or threatens to impact any surface water supply intake (317B) in the Parachute Surface Water Supply Area. Immediately (verbal) 970.285.7630 Mark King or 970-285.7630 Bill Rose PO Box 100 Parachute CO 81635 Parachute Creek/ Colorado River Emergency - 24 hr_ Discharge which impacts or threatens to impact any surface water supply intake (3176) in the Colorado Surface Water Supply Area Immediately (verbal) 970.464.5563 Water treatment Plant 560 25 Road Grand Junction. CO 81505 April 20. 201 1 encana I' Encana Jif & Gas (USA) Inc Oil Spill Contingency Plan - Story Booster Compressor Station Agency 1 Organization Agency Contact Circumstances i When to Notify De Beque Public Water - Colorado River Emergency —24 hr. - Discharge which impacts or I threatens to impact any surface water supply intake (3178) in the De Beque Surface Water Supply Area Immediately (verba$) 970.250.846S Coe Latham or 970.216.4885 Isaac lnsker p 381 Minster Ave. PO Box 60 De Beque, CO 81630 Piceance Creek/ White River Emergency — 24 hr. Discharge which impacts or threatens to impact any surface water supply intake (317B) in the White River Surface Water Supply Area. immediately (verbal) 970 675.2221 Water Treatment Plant 209 East Main Street Rangely. CO 81648 Others In the event that a discharge requires notification of landowners_ The Spill Coordinator will contact Encana's Community Relations On -Call Phone (970 285.2777) to make those notifications. Table 4 — Contractor Contact fnfor►nation Contractors Water Hauler Resources — Coordinate with Pumper or Facility Operator for first available. Knowles Enterprises, LLC 970.434.1912 Arrested Oil Field Services. Inc. 970.371.4164 970.539.5266 Arnett Trucking LLC 970.878.5015 Big H Water Service, Inc. 970.309.8162 Summit Trucking 970.361.1730 Trinity Water Services, Inc 970.985.0510 Beaver Creek Water Hauling 970.618.9735 Earth Work 1 Excavation Resources Tamarrel Excavation 970 379.5780 Moody & Sons Excavation 970.379.5121 Roustabout Resources WCO 1 970.556.0885 Advanced Oil Field Services jj 970.625.9704 Water Pumping Resources Western Pump and Dredge, Inc. 970.244.9097 Rain for Rent 800.742.7246 Environmental Consulting Resources HRL Compliance 970.243.3271 (office) April 20, 2011 enc ana I; Encana Oil & Gas (USA) Inc. Oil Spill Contingency Plan — Story Booster Compressor Station Contractors ECOS 970.704.9128 (On-Cali/Office) 888.375.3267 Table 5 —Additional Government Agency Contact lnforma!ion Colorado Oil and Gas Conservation Commission (COGCC) 303.894.2100 303.860,1435 COGCC 24 -Hour Hotline Division of Oil and Public Safety (Dept. of Labor and Employment) 303.318.8547 Colorado State Patrol Hazmat Service 970..242.7283 St. Ma Hospital — Grand Junction 970.244.2273 Grand River Medical Center- Rifle 970.625.1510 Mesa County Sheriff 970,244.3200 Garfield County Sheriff 970.945.0453 Table 6—Additional Encana Personnel Contact Information Scott Parker— Field Construction Leader Carl Tumipseed — Production Coordinator Tom Cogbum — Automation Coordinator Bruce Neatherlin — Drilling Superintendent Clyde Marks — Completions Supervisor Brant Gimmeson — Group Lead, EHS South Rockies Kevin McDowell — Water Systems Engineer 970.285.2787 (office) 970.379.9796 (cell) 970.285.2609 (office) 970.930.5057 (cell) 970.285.2683 (office) 970.260.0161 (cell) 970.285.2710 (office) 970.309.7015 (cell) 970.285.2681 (office) 970.309.3061 (cell) 720 876.5030 (office) 303.819.7323 (cell) Brad Ankrum — Midstream Field Operations Leader 720.876.5836 (office) 303.968.9658 (cell) 970.285.2630 (office) 435.260.1673 (cell) Vance Wiczek — Feld Operations Coordnator Floyd Alvey — Field Operations Coordinator (West of Parachute) Rocky Erb — Field Operations Coordinator (East of Parachute) Greg Gohn — Field Operations Coordinator Kathy Friesen— Environmental Field Lead Brett Middleton — EHS Field Coordinator (Spill Response) Chris Hines — Contract EHS Field Coordinator (SPCC/Spill Response) Kathy Kiloh — Surface Management Coordinator Brad Mallory — Safely Field Lead 970.285.2673 (office) 970.574.8936 (cell) 970.285.2679 (office) 970.319.0357 (cell) 970.285.2639 (office) 970.210.8571 (cell) 970.319.7506 (cell) 970.285.2665 (office) 970.319.2270 (cell) 970.285.2739 (office) 970 987 4850 (cell) 970.285.2653 (office) 970.261.1127 (cell) 970.'285.2626 (office) 970.456.6406 (cell) 970.285.2709 (office) 970 309.7510 (cell) April 20. 201 1 enc Ina 1.1 Encana Cil & Gas (USA) Inc_ Oil Spill Contingency Plan — Story Booster Compressor Station Dan Prokop — Contract EHS Field Coordinator (Spill Response) 975.790 5907 (office) 815.790.5907 (cell) Charles Jensen —Contract EHS Field Coordinator (SPCC /Spill 970.285.2735 (office) Response) 970.712.6987 (cell) RESOURCES, EQUIPMENT, AND SUPPLIES FOR OIL SPILL RESPONSE As part of the OSCP, Encana has committed the necessary resources to address and mitigate any spill or discharge of oil. The resources available include the following: ▪ Procedures -- Encana personnel are required to immediately report all spills to the Environmental On -Call Phone (970.319.9173). • Personnel - The Spill Coordinator is the qualified person from the Environmental Compliance Group (ECG) responsible for the Environmental do -Call Phone at the time of an incident. The Environmental On -Call Phone is a 24-hour "hotline" for receiving calls regarding any spill, or environmental incident that occurs within the Story Booster Compressor Station facility. In addition, Encana provides additional resources (other personnel, specialized contractors, etc_) necessary to mitigate any spill. • Equipment -- Personal Protective Equipment (PPE) - Encana supplies the appropriate PPE to don while in the field. The standard PPE includes a hard hat, steel toed boots, fire or flame resistant coveralls/clothing, and safety glasses. Additional PPE is provided based on the level of hazards anticipated. • Equipment - Spill Drums and Environmental Response Trailer(s) -- Encana supplies and inventories spill drums (kits) and response trailers to assist in the mitigation ofa spill. The spill drums are typically 95 -gallon immediate response spill kits. The trailers may have spill drums) and additional supplies for larger spills. Appendix B has a detail inventory list of the spill drums and trailers_ Figure 1 shows the locations of the spill drums/trailer(s) for the North Parachute Properties (NPP). • Training - All Encana field personnel are required to complete environmental, health and safety training, including SPCC awareness, and spill response and reporting. Training records are kept on file in the Parachute Field Office. INCIDENT TERMINATION Once a release has been contained and cleaned -up. recorded in Encana's Incident Management System (IMS), and any required verbal and written notifications have been made. the Spill Coordinator will take the fallowing actions: L If the spill was a reportable release, into or upon navigable waters ot`the United States, prepare a spill report and file it with the SPCC Plan. 2. If necessary, verify that spill equipment has been re -stocked. April 20. 2011 encana 15 Encana nil & Gas (USA) Inc. Oil Spill Contingency Plan - Story Booster Compressor Station 3. Verify that the used oil is properly containerized, labeled, and stored for disposal. Review the cause and response to the release with supervisors, witnesses, and contractors, if appropriate. Determine additional requirements necessary to prevent recurrence of the incident, and discuss those measures with facility personnel during regularly scheduled briefings and trainings. Amend the SPCC Plan if necessary. ENCANA'S NORTH PARACHUTE PROPERTIES WATER QUAILITY PROGRAM The North Parachute Ranch (NPR) water quality monitoring program began in the fall of 2004. The ongoing program is designed to complement any spill prevention program by tracking surface and groundwater quality throughout the North Parachute Properties (NPP). The water quality data can identify a spill or discharge of oil not visible through general field observations. Since the fall of 2004, water samples have been collected to establish baseline water quality and monitor water quality during construction of facilities and development of the natural gas resource. Initial characterization of water quality included sampling surface water and springs along the mainstems of East, West, and Middle Forks of Parachute Creek. Additionally, nine groundwater monitoring wells are sampled to characterize and monitor shallow, alluvial groundwater quality along the East, West. and Middle Forks. During 2005, the study area expanded to include surface water and springs along tributaries of the East, West. and Middle Forks as well as the North Parachute Mountain area of the NPP. Two additional monitoring wells were installed to characterize and monitor shallow groundwater quality upgradient and downgradient of the Middle Fork pond (produced water storage and recycling facility). In 2010, an additional monitoring well was added west of the Middle Fork Pond_ The vast majority of the NPR contains ephemeral drainages which flow in response to spring snowmelt and intense precipitation. The primary source of water in area drainages is natural springs. Water quality monitoring, including surface water. springs. and shallow ground water is conducted on a quarterly basis for the Middle_ West, and East Fork areas and twice and year for the North Parachute Mountain area. Figure 1 shows the sample locations for the water quality program for NPP (sample point labeled " ENPR, ' 1 - April 20.201 1 encana 16 Encana Oil & Gas (USAN Inc. Oil Sall Contingency Plan - Story Booster Compressor Station Appendix A Spill Trailer Inventory Spill Drum Kit Inventory encana ENC ANA.. EnU:;rna Oil & Gas (USA) fnc. SPILL DRUM INVENTORY Document No: Revised By - Date: Reviewed By - Date: Approved By - Date' Spill Drum # Inventory Done By: Inventory Date: ut o # Inventory List Equipment Description ❑ 100 18" x 18" Pads ❑ 25 17.5" x 17.5' ! 15 3' x 4" DikesJSocks ❑ 10 3" x 10" Dikes/Socks ❑ 2 SilverShield Gloves, Size L 2 Nitrite Gloves. Size 10 ❑ 2 Goggles • 2 Tychem QC Coveralls. Size XL ❑ 1 Floor -Stand Spill Sign ❑ 6 33' x 60' Haz-Mat Disposal Bags • 1 Spill Response Pocket Guide • 1 Saftey and Cornpliance Directory 1 DOT Emergency Response Guidebook ! 1 DOT Label Pkg. 0 ! 0 ■ IN■ 0 ! ! ! 0 0 • • 0■ 0 ENCANA En[ana {J I & Gas (USA) Inc. ENVIRONMENTAL RESPONSE TRAILER INVENTORY Document No: Revised By - Date_ Reviewed By - Date: Approved By - Date: Spill Trailer # Inventory Done By: Inventory Date: Equipment Type Requi red Amou nt Need Notes 1 Manditory Equipment Porta berm 1 Spall Kit drams 2 Oil adsorbent Pads (cube) 2 3" x 4' Booms 8 5°' x10° Booms 2 8" x 20' Booms 2 Absorbent (bag) 6 Acid Neutralizer (bag) Over Pack Drum 1 Shovels 8 Brooms 4 Saftey Glasses/Goggles 10 Nitrile Sample Gloves (box) 4 Chemical Gloves (paw) 25 Saranex Coveralls (box) 4 Boot Covers 20 Dust masks Reflective Vests 6 Flashlights 4 _ Fire Extinguisher (30 Ib) 1 Drum and Tank repair kit 1 Caution Tape (roll) 2 Emergency cones 6 Flex Pak 1 Remediact (35 lbs bucket) 1 25 Stakes (wood) Heavy Duly Trash Bags (box) 2 25' x 30" Pit Liner 2 Trailer Spare Tire 1 Encana Dil & Gas (USA) Inc. Oil Spill Contingency Plan — Story Booster Compressor Station Appendix B References encana E NCANA EnCana Ott Z. Gas {USA} Inc SPILL AND ENVIRONMENTAL RELEASE REPORTING PRACTICE Document No: E-005 Revised By/Date: FGC 2/11/2010 Reviewed By/Date: FGC 2111(2010 Approved By/Date: J. Thatcher/ 2/28/2010 1 Spills Required to be Reported in IMS EnCana Oil & Gas (USA) tnc_ (EnCana) employees and non-EnCana employees who work under contract for EnCana shall report into IMS any spill or environmental releaser caused for any reason (including contractor or third -party actions) at EnCana operations. Spills that meet the following description must be reported into IMS_ A spill is any unpermitted quantity of liquid or solid substance that is partially or wholly outside of its primary containment (e,g., tank. drum, truck, pond, pit, storage sack, rig trench), excluding beverages, food items, and potable water. A. Purpose for Reporting EnCana strives to operate our facilities in a prudent and environmentally responsible manner Consistent spill reporting allows us to measure and minimize our impact on the environment_ EnCana uses the criteria in Section LA of this guidance for reporting of spills, in order to: • Ensure that the environment is protected by: Reducing the overall number of spills, Identifying areas or trends where controls should be implemented, and Encouraging controls to be established to mitigate any environmental impact of spills; • Foster a culture of active spill mitigation; • Standardize the reporting process across the Division, and • Make a clear and concise definition that is easy to apply,3 B. Applicability to Drilling and Completion Activities Drilling and completion activities must follow the above criteria in reporting spills. Upon discovery of a spill, EnCana employees and non -employees must identify the source of the spill, act to prevent any further spillage or impacts to the environment. and immediately remediate or clean up the soil or surface impacted by the spill. These actions must be taken with consideration to safety. C. Applicability to Transportation Spills that occur related to transportation activities at EnCana operations are required to be reported into !MS_ If a spill occurs during the loading of the produced water, it must be reported into IMS. If the spill occurs outside of the physical EnCana operation after the material being transported has left EnCana's 'An environmental release is an emission or spill that is either. Outside (in any manner) of impervious engineered controls (e.g., drip pans, pop-up pools, fined lank ring), or ▪ Has an impact (e_g., air. soil, groundwater, surface wales, or wildlife) Po the natural environment Gaseous environmental reteases are to be reported in IMS under the sub category of 'gaseous substance' For IMS purposes, s1 pills are considered an environmental release aniy if outside of secondary containment (with direct effect on water or land) or have an effect on wildlife or air. Regardless of secondary containment, some states require reporting o! !arae quantity spalls See Appendices for specific details Unperrnitted gaseous releases are not required to be recorded as a spdl Data related to gaseous emissions may be recorded in other existing databases Unpermitted gaseous releases may be required to be reported to a regulatory agency pursuant to a permit, regulation. nr law t of31 Uncontrolled when printed_ custody, it is still required to be reported to IMS, unless the hauler is contractually obligated to take ownership of the material. Leaks generated by equipment associated with the transportation of the material during transport are not required to be reported into IMS and is the responsibility of the transporter (i.e.. if there is a leak from a gas tank or radiator that is the responsibility of the transport company). TI. Reporting Spills to Agencies The requirement to report spills into IMS is equivalent to or more stringent than Iocal, state and federal requirements. Reporting requirements to Iocal, state and federal agencies for each jurisdiction where EnCana operates is included in Appendices A through C in this guidance. 111. Primary Containment The following are examples of equipment that are considered primary containment for purposes of this spill reporting guidance: • Storage: tanks, drums. totes, authorized pits, and storage sacks; • Transportation: trucks and pipelines; and • Process Equipment' separators, dehydrators, heater treaters, gun barrels, and water treatment facilities. IV. Engineered Controls Engineered controls must be impervious in order to prevent potential impacts to state and federal waters. The following are examples of equipment and technologies that are considered engineered controls for purposes of this spill reporting guidance: • Steel, plastic, or fiberglass containment tubs; • Stock tanks; • Poly-lined metal containment dikes; • Drip pans, bucket and basin. • Inflatable and rubber truck containment. • Containment pallets; • Buildings with built in containment skids. • Concrete unload areas with trenching to sump, • Pop-up pools; • Lined tank rings; and • A system by which a volume of liquid can be held for an indefinite amount of time without any Toss of volume to the surrounding environment (excluding evaporation). The following are examples of equipment and technology that are not considered engineered controls- • Earthen or gravel berms, and • Controls that are full of water or accumulated leaks such that the actual containment is compromised. V. Examples of Reportable and Non-Reportable Spills The following are examples of spills that must be reported in IMS. • If at a drilling operation. a spill of water-based drilling mud has occurred and is still contained within the drill pad, it must still be reported to IMS. • If an engineered control does not adequately prevent pollutants from escaping the equipment or technology to the natural environment, then the incident must be reported as a spill. For example, a spill has occurred if an engineered control is full of rain water and polluted water overflows from the engineered control. The following are examples of events that do not need to be reported in IMS 2 of 31 Uncontrolled when printed Stained soil does not need to be reported if there is not an identifiable source of the materials and it is cleaned up within 24 hours of the discovery of the stain. If a source of the stain can be identified, the employee or contractor should treat it as a spill VI, Spill Reporting Procedures Spills shall be reported and responded to consistently with EnCana's "Reporting Guide for Environment. Safety, and Security Incidents iritp Hecn encarla corn/arty+Curoornteldocs/f pc,rt,;n°' 2"GJ 1e.L:fj and applicable Emergency Response Plans for the affected facility. In Appendix D are detailed procedures for different roles (EH&S coordinator, manager, pumper) of where and how to capture spill information and timeline for reporting; definitions of responsibilities and accountabilities for spill reporting: and how to manage cumulative events like repeated drips. or continuing leaks inside earthen containment. VII, Effective Use of Spill Information EnCana will regularly review information reported into IMS in order to. • Identify and examine common occurrences to determine if procedural or mechanical changes need to occur to reduce the number and size of spills; • Trend operational performance; • Encourage transparency and goodwill with stakeholders; • Recognize EnCana employees and non -employees that appropriately report and respond to spills; and Increase EnCana's knowledge in order to improve environmental performance, reduce risks and minimize liability related to spills Appendices Appendix A A 1 Reoulatorily Required Spill Reporting Matrices for Mid -Continent Business Unit A_2 Inc :!?r! Reoor":iN_71 Matrix A. .., f 3 Links Appendix B B.1 r r. r _ r R.eluired =t ' i '•,'portio.:1 Matrices for North Rockies Business Unit B.2 J Dui Reaortrrto Guideline anu Table B_3 Links B 4 NRBU DeFinih,_ ^ .gin Notiricatror of Suill : Le,k Appendix C C.1 Reaulaton .s, Required St7ill Reyortiiaq Matrices for South Rockies Business Unit C 2 3rill Reporting Flow Chart — DJ Basin, Prceanc Paradox Colorado C.3 Spill Reporting Flow Chart — Paradox -Utah 4 Spill Reporting Flow cOhart — South arc,' West Texas C 5 SRBU Requiatory Lr Bks Appendix D Roles and Responsibilities in Spill Incidents Appendix E Fructuently Ash..1 Questions Appendix F Calculations for 40 rl.FR 302, i F,epertat le Quantities 3 43131 Uncontrolled when printed APPENDIX A.1 REGULATORILY REQUIRED SPILL REPORTING MATRICES FOR MID-CONTINENT BUSINESS UNIT Note: The use of these Spill Reporting Documents does not preclude the use and Importance of each field's Emergency Management Plan Spin Reporting Documents (matrices/flowcharts) are updated by BU EH&S personnel on a monthly basis and all potential spill response personnel and other affected personnel are notified if an actual change is made to the document or the location of the document is changed. 4of31 Uncontrolled when printed. inrxlnnr Arpnnir i PARTIM levet w APPENDIX A,2 MCBU INCIDENT REPORTING MATIRX SO Identifier Supervisor 1.1.1 ua Prod Coordinator Construction Coordinator / D&C Supenntendant Fed Operations Construction f D&C Grflup Lead rr.M rtottrepartaWB soils a EhtS Field Coordirrator Safety Group Lead Env. Field Coordinator • Environmental Group Lead •r u1 Tears Lead '°I Signe-nary & Outside ager}c- El-IS Group Lead VP, MCBU Report to an Outside Agency? First Report Spill Internally -Arr]1 Pura or `\ r+az SLestan[e )+1 e4cee'c RCY7 Yes Lenermlre agertzt to contact Production Fluids Reportable Quantity IRO} Outside Agency Texas Loulsian DiI Produced Water a5bbi Only if w> ss of US aflectUS affected a1bbl a 1 bbl Natural Gas VOC (C3+I I -12S a 100 tb I7I lO -et ¢ 'MON rCTh 1MMct a 5000 lb a 5000 Ib Select Hazardous Substances Reportable Quantlgi (ROl Ethyl Goyim IEG) Mercury Meinand TEG Barium Iydrocnionc Acta I.H+ I, Texas or Louisiana Land 5,000 lb (1000 gall 0061L1 ©zi 5,000 Ib i7 HO gal) 5,000 Ib (1 000 gal) 100 lb 5000 10 Navigable Water i00 lb i,20 gal i 0.06/till cz) tap lb (15 gal tJO 11)1'20 gal i 100 Ib IR lb Outside Agency Reportable Incident type Teras Produced water or lOil released greater Man PO Near or in environmentally sensitive area or RRC ILau isiana Stale Police' LDEQ RRC 'MEC) St31ePoh:e' LDEO Navigable water release or Hazareous Substance vat greater Than RG RRC TCEC NRC Stale Police' LDE6J NRC • Report within 60 min.. of event. ll possible 5of31 Uncontrolled when printed. APPENDIX A 3 MCBU REGULATORY LINKS Texas Regulatory Links Field Guide for the Assessment and Cleanup of Soil and Groundwater Contaminated with Condensate from a Spill Incident t'p irwwwrrc.state.tx.uslenvironmen°.l pillslspillcdeanr�p.php Texas Railroad Commission Cleanup of Soil Contaminated by a Crude Oil Spill t[: .11: CJs state tx.u$/p:'sfput:?feadtac •:t T;cPaye?Rupp='yup :, r=E p floc=8,p floc=&p rloc= ci-"t c-&tw-16&ept-i&d[-3&i-71 Field Guide for Reportable Surface Releases of Crude O11 in Non -Sensitive Areas -,ttp:llwww rrc s'ote tx us/environmental, _ ,ilsrs _•llinc. ler:t : hi Louisiana Regulatory Links Louisiana Oil Spill Coordinators Office t 'tp .//www losco state la us/ Louisiana Oil Spill Prevention and Response Act of 1991 (amended) http //www.losco.state.la.usipdf_docs/OSPRA_2003 pdf State Spill Notification Regulations tp /'www lose° 3t _]:e.la '. 'f]: ' igcs:/St7iteYaU.Jvill`:+ 2C'YJC' llc:Yil(]ri%2QRequiaiions Ti Le%2O333.pot All Louisiana Acts, Regulations, Guidelines. and Plans flttp;rwww losco.state_la uslregulatlons.hrrr, 6 of31 Uncontrolled when printed. APPENDIX 1 REGULATORILY REQUIRED SPILL REPORTING MATRICES FOR NORTH ROCKIES BUSINESS UNIT Note: The use of these Spill Reporting Documents does not preclude the use and importance of each fields Emergency Management Plan Spill Reporting Documents (matrices/flowcharts) are to be updated by BU EH&S personnel on a monthly basis and all potential spill response or affected personnel notified if an actual change is made to the document or its location is changed 7 af 31 Unconlrolied when printed APPENDIX S.2 NRBU SPILL REPORTING GUIDELINE AND TABLE The fallowing guidance is to be used by NRBU locations for internal and external reporting of spills. There are two general classifications of spills- • Spills required to be reported internal to EnCana via the Incident Management System (IMS) • Spills required to be reported to regulatory agencies Internal Reporting EnCana is using the CMS as a tool to track and trend spills and thew causes SO systemic problems can be realized and preventative measures can be determined. Tracking of spills and their causes is important not only because of environmental concerns, but also for loss prevention. External Reporting Individual agencies have different reporting requirements, although some spills may need to be reported to more than one agency Reporting requirements are summarized in the table below and the actual regulations are included later in this guidance. For Wyorning, agencies that may need to be notified based on the criteria outlined in the table include: • Wyoming Department of Environmental Quality (WDEQ) • Wyoming Oil and Gas Conservation Commission (WOGCC) • Bureau of Land Management (BLM) for spills occurring on federal leases • United States Environmental Protection Agency (USEPA) Wvorino Department of Environmental Quality The Wyoming DEQ spill reporting information is available on the following web page: This website also contains • spill reporting forms that can be downloaded • a list of contractors providing emergency response services • Phone number of emergency response coordinator for questions on what needs to be reported 307-777-5885 -*Interpretation from DEC?: Regardless of containment, report any spill quantity of produced water or condensate over 10 barrels or 25 gallons of other manufactured or refined materia! Wvominq Oil and Gas Conservation Commission The WOGCC rules for spill reporting are currently undergoing revision and are expected to be more stringent_ The spill reporting requirements for the Wyoming Oil and Gas Conservation Commission Rules Chapter 4 Environmental Rules, Including Underground Injection Control Program Rules For Enhanced Recovery And Disposal Projects, Section 3 Accidents, Spills and Fires Chapter 4, Section 3 (6) states - Uncontained spills or unauthorized releases of produced fluids, drilling muds. produced water. hydrocarbons, or chemicals which enter, or threaten to enter, waters of the state must be verbally reported to the Commission no later than the next business day following discovery of the incident. Spills of less than ten (18) barrels (420 gallons) of crude oil, petroleurn condensate, produced water, or a combination thereof which occur on a lease. unit, or communitized area and do not physically enter waters of the state and are immediately contained, removed, and disposed of properly are not required to be reported_ The owner or operator shalt file a written report within fifteen (15) working days. An example of the information normally required by the Commission for reporting spills is included in Appendix E. The Commission accepts copies of reports prepared to satisfy the requirements of the Department of Environmental Quality or the Bureau of Land Management. h ,p ;r.a,_ 1cc.state vry usicrai_ _p�ll.htrrf 8 of 31 Uncontrolled when pnnfed. APPENDIX 3.2 NRBU SPILL REPORTING GUIDELINE AND TABLE Bureau of Land Management The BLM spill reporting requirements are stated in Notice to Lessees document NTLA-3A, Reporting of Undesirable Events_ This document can be found at: http ,!www blm govlwvlstlenlprogramslenergv/Oil and Gas/docslntl 3a.htnii Notify BLM verbally immediately on Federal leasesoil, produced water, or toxic liquid exceeding 100 bbls or any spill which occurs in a sensitive area. Written report within 15 days. Written report to District Engineer for spills or oil. produced water, or toxic liquid that exceed 10 bbts. but less than 100 (non -sensitive) on a frequent bases (contained or uncontained) US Environmental Protection Agency The USEPA requires reporting for oil spills and hazardous substance releases to land, air, or water. Oil Releases Oils spills that require reporting are defined in 40 CFR 110.3 and reporting requirements are in 40 CFR 1105 §110.3 Discharge of oil in such quantities as "may be harmful" pursuant to section 3111b)(4) of the Act. For purposes of section 311(b)(4) of the Act, discharges of oil in such quantities that the Administrator has determined may be harmful to the public health or welfare or the environment of the United States include discharges of oil that: (a) Violate applicable water quality standards; or (b) Cause a film or sheen upon or discoloration of the surface of the water or adjoining shorelines or cause a sludge or ernulsion to be deposited beneath the surface of the water or upon adjoining shorelines [61 FR 7421 Feb 28, 1995] law.tustia cor: ;_: r _` t4e40140-21 0 1 1.6.0.5.3 html §110.6 Notice Any person in charge of a vessel or of an onshore or offshore facility shall, as soon as he or she has knowledge of any discharge of oil from such vessel or facility in violation of section 311(b)(3) of the Act, immediately notify the National Response Center (NRC) (600-424-8802) Hazardous Substances Hazardous Substances and their Reportable Quantities (RQs) are in 40 CFR Table 304.2. RQ's vary by chemical and the list is too extensive to provide here. Reports are made based on individual chemicals not the mixture within a certain product. Therefore, to determine if an RQ has been exceeded, it is necessary to calculate the amount of material that would have to be released to exceed the reportable quantity for any of its constituents. ROs are given in pounds so for liquids. a conversion from pounds to gallons will need to be made, taking into account the specific gravity or specific density of the material. The calculation to determine RQ for a specific material with hazardous substance constituents is as follows.. Amt. of material exceeding RO (gals) = Chemical specific RQ (lbs) Density of material (tblgai) x Arnt of haz. constituent (wt_%) The following table lists the calculated RCIs for several materials used in EnCana Wyoming operations. This list can be revised as needed to incorporate new materials. Materials of greatest concern are those with RQs of 500 gallons or less as that is a feasible quantity that may be spilled. trio M/law;ustia corn us/cfr/title4r 143-21 0 1 1 6.0 6 6 htn+i 9 of 31 Uncontrolled when printed rkIPENUtX NRBU SPILL REPORTING GUIDELINE AND TABLE Wyoming DEQ Wyoming Oil and Gas Conservation Commission BLM USEPA "Interpretation from DEQ; Report by the next business day, all uncontained spills that enter or threaten to enter waters of the state Written report must be filed within 15 days Notify BLM verbally immediately on Federal leases oil, produced water or toxic liquid exs.aNdinc 100 bbls or any spill which occurs in a sensitive area. Written report within 15 days. Report all oil spills to navigable waters or shorelines that - Violate water quality standards - Cause a film or sheen or discoloration of the water or shoreline - Cause a sludge or emulsion to be deposited beneath the surface or on shoreline Regardless of containment, report any spill quantity of produced water or condensate over 10 barrels or 25 gallons of other manufactured or refined tnatenal. Report all spills of the following if they enter or threaten surface water (including wetlands) or groundwater: - Hazardous Substances` (any volume - Greater than 10 barrels of any combination of crude oil, c- 25 gallonsnsate, or moreor of efnde water - 25 or of refined oil products including but not limited to motor oil, lubricating oil, used oil, gasoline, diesel Suspected release from storage tank (not due to load/unload operations) due to structural or operational failure Immediate notification to 307-777- 7781 is required Immediate action to stop and contain release is required Immediate correction of problem that caused spill is required Spills less than "f 0 barrels that do not physically enter waters of the state and are immediately contained, cleaned up, and properly disposed do need to be reported **The WOGCC rules for spin Report all spills to the environment or atmospheric/evaporative releases of Hazardous Substances' that exceed the Reportable Quantity (RQ) for that substancenot WrIiten report to District Entdineei for spills or oil, produced water tar toxic liquid that excutud 10 bbls but less than 100 (non- sensitive) on a frequent bases icontalned or uncontained) Immediate nctification to the National Response Center 800-424-8802 Ask if written follow up is required reporting are currently undergoing revision and are expected to be more stringent. Alf reporting is to district engineer or supervisor as directed by the district office Spills Tess than 10 barrels in non - sensitive areas must be included on monthly report of operations Within 7 days file written repot# 'Hazardous substances are described in a separate table. 1flot31 Uncontrolled when printed. Wyoming Regulatory Links WOGCC Spial Information te wy us/cal VVDEO Spill Information ptIlshtm APPENDIX 3.3 NRBU REGULATORY LINKS Requirements for Reporting on BLM Land . t eniprograms/energylOil and Gasidocsinti 3a htmi Selected EPA Regulatory Links Reporting for Oil and Hazardous Substances aw ,,,,tia cornki • 10-2 1 0 16066 htrrl . aw cgrniu. 10-21 0 1 1 606 3 NMI Page 11 of 31 uncontroikaa when printed APPENDIX 8 4 NRBU DEFINITION AND NOTIFICATION OF SPILL OR LEAK *ALL AGENCY NOTIFICATIONS TO BE DONE BY EH&S COORDINATOR OR FIELD OPS MANAGER* I?i. fe �x'= 'r ='-.15ib" 1--n7-_L = _E1 �Je 117r:45731- J= _ sd rap -4_ wrlamiw•rte - ar{A 5P)L1. DEFIM1]'1U$ it y wgpErmhted 5.2+143 stir4sance that is pa*teatfj ssr WOW" auto -de -34 -1-r/ c44441311..414ent It I- UAW dila% !TWA Pc,i '.rt. uotage SAO, •tg trea<,:ttt. aswfurs,ng - e+ages rw3'tetras. And pvtnblr eater Notitication (By Aoenci). DEQ_ All spills of the following if threatening surface or ground water Hazardous substances Mare than lObbis of any crude ort oOndensateproduced water or combo Interpretation: Regardless of oontarnment. any spill of produced water or condensate SOhbis or greater. 25 gals or more of refined crude oil product, hazardous substance or any amount or any substance that might threaten to enter waters of the stale muss be reported- WVOGCC- 14v nest business day, all spills that threaten to enter waters of state BLM Verbal report within 24 hours on Federal leases of oilproduced water or toxic liquwd exceeding 100obis or any Spill which occurs In a sensitive area EPA: All 011 spills to navigable waters orshorol+nes that opiate water qualify standards cause a Ulm or sheen, cause a sludge or emulsion Report all spills of Hazardous substances that et ceed Reportable Quantities. Page 12of3t Llnconitolled when pnnteo APPENDIX C.'1 REGULATORILY REQUIRED SPILL REPORTING MATRICES FOR SOUTH ROCKIES BUSINESS UNIT Note: The use of these Spill Reporting Documents does not preclude the use and importance of each field's Emergency Management Plan Spill Reporting Documents (matrices+flowcharts) are to be updated by BU EH&S personnel on a monthly basis and all potential spill response or affected personnel notified if an actual change is made to the document or its location is changed Page 13 0131 Uncontrolled when printed APPENDIX C.2 SPILL REPORTING FLOWCHART— DJ BASIN, PtCEANCE, PARADOX, COLORADO Regardless of quantity has the release reached or sloes 11 have lite potential to Immediately reach waters of the State? 1 YES Is the release greater than the FSU (see er..3I1)ple$ bercm) or any release that NO Causes +Itiurykleat It property damage >$50 00) > 1 hour evacuation of the general public %huts down major transportation mottles or involves Iadloat:tr,e or irdectlo.is stfbstances7 linnlediate verbal tenon to— Supervisor & Environmental Staff who will (as appropriate) contact EnCana management l`1RC (for hydrocarbon or hazardcus substance fisted rn CWA, CDPHE (any release] local communities and sewer authority and any affected MVP ELM ACOE local emergency responders (911) and landownerr,$) Verbal notification as soon as practical to the COGCC Written notification to CDPHE within 5 dans YES NO —1 Immediate verbal report to— Supervisor & En.+rronmental Staff who will determine if notilkarton needs to be made to FIRC local emergency responders (911) CO Slate Patrol (Incl CDOV) nearest lave enforcement office i if hazardous waste & a vehicle involved) COGCC_ CDPHE and landowners) Vrniten rlohtl'c auctn to US DOT 4vrthin 30 days and also to CDPHE (if HV'' rrreolved) EXAMPLES CF REPORTABLE QUANTITIE OF HAZARDOUS SUBSTANCES Condensate Produced Wale'. Frac fluids Gasoline Diesel Hydraulic oil Ethylene Glycol (EG) IVelhanol Tnetliylene Glycol tTE3,1 (RO) 5 Rini 1210 Gallons, 5 Blot 1210 gallons) 5 Bbl (210 gallons) 25 gallons 25 gallons 25 gallons iStatlonary so!II'c 5.000 lbs 153S gallons( 5 000 I'hs 1757 gallons) no listed reportable quantity - follow guidance above in floss+ chart Now Any sprltrrelease of E&P waster,rncludrmg produced fluids! 55 barrels including those within unlined berms must be reported to COC,CC using Form 19 within 10 days oFdtscovery of the spill+release In addition ANY spill/release '20 barrels of E&P vaste shall be reported verbally to the COGCC wrihin 24 hours Storage. tank Ieleases and pipeline releases have unique requirements—refer to Internet resources Page 14 of 31 Uncontrolled when printed Regardless of quantity is release to or near an environmentally sensitive area (r e ovlll it cause adverse public landowner and or media response)? YE S NO Immediate verbal report to-- Supervtsor & Environmental Staff who will ras appropriate) contact BLM [itpotential 10 impact BLM land) COGCC and landowner(s) Incident report to be completed in IMS within 24 hours Any other spill Report verbally to Supervisor & Environmental staff ASAP wt,u will notify EnCana management and landowfterr,$) as appropriate and complete incident report In IP IS Regardless of quantity, has the release reached, or does rt have the potential w isurnediatlp reach, waters of the Siete' 1 YES NO Is spill •_ -'� gel or ties It violate Clean Water AM'? Immediate vetb4l spat to— Supervronr $, EHS Stan. vNtovvlll i onsets NRC (for hNdrecarton or haat dous substance listed in CWA), Division of Uyater Duality (any release iohi::h may pollute vvelers cit the !date), lo;ar communtlee end eve et1 dhortly end any affected WW1 W, BLM and CO Of applicable) and local ernergenuy reespondere (911). 11S3r, Fe,Urr! Hvar.v.pJ r--PEND1X C.3 SPILL REPORTING FLOWCHART -PARADOX, UTAH NO --i YES ' 15 the release greater than the RQ (ae exarnglles 17e1aw), or airy n±la+rae tluil reuses ugmyldeath, prrlpetty damage >$50,0IJ0, > 1 hour evaruatiori of the general public, shuts dawn sissies 11anspodation sautes or urwhves radioactive of infectious substaiuet0 Nath/ ,u22 1101 C' m daub ental Ekspunvar 40iia Rernedith n within 24 hour,. Notify C1t vazn of Eiwu mrerda1 witha w7dten iiratita wgkrat 15 davkr YES 110 Immediate verbal trier! to. Supennsrrr t Env Staff, who wilt drtcrmine if nouns. atiurs nee 4.s ru he mads to NR', local emergency responders (91 I), Utah Erry rotorrentel Response arm:i Fanledrelil',11(CERCLPr1EF'CFA J-1ax, Substance at Petroleum Produf Is not effecting water), rueasvi1I law enforcerrrant ofIrce (if Itexaalotis waste a vehicle involved)Alen Ilirtdi'c.tilcill to 1,15 C'..;(1; within 30 drys If spill cif 1 kg of Acutely lid waste, 100 kg of other ftW or HW that enter: waters') YES Notify Dirurned Salm awing?. mute trameatrateiY, with a woad eta sierra withal 15 days. RegarUIBi£ Of quantity, is IBIeate in or near ail environmentally 110 media response)? YES EXAMPLES OF REPO RI RULE ()UANTIIIES (Rol OF HAZARDOUS SUBS1ANCES C o n d5115 ate Produced Water Ethylene Glycol (EG) Mercury Methanol Trlathylene C ryI tri (TEO) €1bl 5 Fibs 1 n oz 210 gal 21D gal 545 gal TSU gal no reportable quantity - fo,low guidance above in slow Chari 5,000 lbs 1 Ib 5,000 lbs Dote Div. of Warier Oualty. Spills et sthstarcm v f Ich could poilute waters as the slate Diu. of Enviranwxttol Response end R i-whatpn Spill over 25 gallons, causes o sheen on surlocewater , mere than la0 ora CER CLA hasa doss substerre to ere, fronrrier1 or violates Clean Water Acct Div. of Environmental ental txi Iltys Used ole splits grease than :5 geHor ur pater -real Wrest to humeri nealth or environment. Div. of Solid and Hazardous Waste: Spill at one kg of "aoirtery hazardous materiel", 100 kg or other Irrerdous Amore, iewel tivaritrty that lea threat to envlronrrlenl. Immediate rloltf Lentil vddti o vc IIlef i trail n vwttt do il•a BLM. Verbal report within 24 hod's; on Fadere4 lease 01 oil, produced water or toxic IiGluad e,�ceeding 100IihIE u arm • spill vr,Alich exous in n serclll^re area EPA: All oil spills to navigable wader sor shorelines That violate water yuallty standarrl3,cause afilin or sheen, cause a sludge c* emulsion Report all apllls or Naznrdous substances that exceed Reportable auentitlec Page 15 of 31 Uncontrolled when printed Immediate etliali mottle; Supervisor&Etiv1tafi who will contact L'LM Of BLIVI land cif Ata, potential to impact ni1V1 Land) and ] m°uotunaoii i Respottsa and R.eledrelion(CERCLAIEPCR.A l -fat ,",t {gt cr PetroleumPrrducL not affecting water) 4;14;4. '3,1.1.tib + irlikl" trd,ir, IMS wit ki 14 hours NO Hmv e, other spill Report vetbeJ y to Supervisor & Environmental aieff ASAP. who will Itotlty t nCmva inane g7etrretit end lanclow'nens) ea appiapnete ns¢1 complete rruridea report ur )NIS Regardless of quantity nas the retease reached or does rt have the patentsal Io immediately reach waters? YES APPENDIX C.4 SPILL REPORTING FLOWCHART - SOUTH & WEST TEXAS NO ( Could this release Cause (see examples below) or any release that causes snturyrdealh properly damage 450 000 >I hour eM acuabon of the general public shulsdown major i.ransportation routes or ,nvolves radioactive or infectious substances? Immediate verbal report to - Supervisor & Environmental Staff who Nilt 135 appropnatef contact EnCana management TX RRC local emergency responders (911) and landowner(s) V ntten notification to TX RRC within 7 days ' YES NO --1 Immediate verbal report to-- Superrisor & En iimnmerrral Staff who will itrrteriiririe it notification !reds 10 be made to TX RRC local emergency responders (9111 nearest law enforcement office (if hazardous waste & a vehicle Involved) and landownerfs) Condensate spills exceeding five barrens shalt be rnmediafely reported to the Conunissson Ab spills of condensate line water must be immediately reported to the Commission Page 16 of 31 Uncontrolled when pnnted Regardless of quantity is release In of near ah envrronmanially sensreie area +i a wit a cause adverse public landowner andfor media resr�onse)? YES i Jrnmediate verbal report to - Supervisor is Environnierttal Staff, who will (as appropnate) contact TX RRC and landowi eris) Incident report to be completed rn IMS within 24 hours NO Anv other spll V Report vernally to Supervisor & Environmental Staff ASAP who will notify EnCana management and landowner(s) as appropriate and complete incident report in IMS APPENDIX C.5 SRBU REGULATORY LINKS Colorado Regulatory Links Spilt Guidance Document http ne ;e.co uslrvufWhatsNew/SpillGutdanceDocument.pdf Environmental Spill Reporting Brochure http .. c- phe.state.co.usrl-r;ispiiirennrtinabrocn.pdf Spill Release Rules to 'coq to co. us/ (under rules: 200 series. 300 series, 600 series. 900 series) Reportable spills and reporting requirements for spills/releases (COGCC Rule 906 b) (1) Spills/releases of E&P waste or produced fluid exceeding five (5) barrels, including those contained within lined or unlined berms, shall be reported on COGCC Spill/Release Report, Form 19. (2) Spills/releases which exceed twenty (20) barrels of an E&P waste shall be reported on COGCC Spill/Release Report, Form 19. and shall also be verbally reported to the Director as soon as practicable, but not more than twenty-four (24) hours after discovery. (3) Spills/releases of any size which impact or threaten to impact any waters of the state, residence or occupied structure. livestock, or public byway shall be reported on COGCC Spill/Release Report, Forrn 19. and shall also be verbally reported to the Director as soon as practicable. but not more than twenty-four (24) hours, after discovery. (4) Spills/releases of any size which impact or threaten to impact any surface water supply area shall be reported to the Director and to the Environmental Release/Incident Report Hotline (1-877-518- 5608) Spills and releases that impact or threaten a surface water intake shall be verbally reported to the emergency contact for that facility immediately after discovery (5) For all reportable spills. operators shall submit a Spill/Release Report. Form 19, within ten (10) days after discovery. An 8 1/2 x 11 inch topographic map showing the governmental section and location of the spill shall be included Such report shall also include information relating to initial mitigation, site investigation, and remediation. The Director may require additional information (6) Chemical spills and releases shalt be reported in accordance with applicable state and federal laws, including the Emergency Planning and Community Right -to -Know Act, the Comprehensive Environmental Response. Compensation, and Liability Act, the OiI Pollution Act, and the Clean Water Act, as applicable. Texas Regulatory Links Field Guide for the Assessment and Cleanup of Soil and Groundwater Contaminated with Condensate from a Spill Incident tl a flwww rrc state tx . n.^ rr,, n rtal :o IIs:php Texas Railroad Commission Cleanup of Sail Contaminated by a Crude OiI Spill http ifinfo.sos.state tx usrrilsia.bfreadtacSext-acPaoe `',1=R&app=9&p :lir=3p rloc=&p tlac=8,p ploc=&pq= 1 &p tai =ut,= ,opt 1 &ch,3&r1-91 Field Guide for Reportable Surface Releases of Crude Oil in Nan -Sensitive Areas h'?p tiwww rrcstate .tx.uslenvironmentsllsoillsrsDtllincident php Page 17 of 31 Uncciniroiied when onnied APPENDIX C.5 SRBU REGULATORY LINKS Utah Regulatory Links Utah Department of Environmental Quality Environmental Laws I {i; _,_Ot:: - - h:m A Summary of Utah State and Federal Hazardous Substance/Waste/Material Environmental Regulations Requiring Immediate to Within 24 Hour Notification of Utah DEO or EPA hp_Ilwww.superfund utah.go1r pdf Page 1$ of 31 Unconrrolled when pnnreo APPENDIX t7 Roles and Responsibilities in Spill Incident Employee/Contractor that discovered spill Report to supervisor If safe. take action to contain or stop the spill/leak Any individual can report and incident to IMS- • Supervisor Receives initial report Responsible for Incident Investigation At least one corrective action must be taken Notify EH&S Field Coordinator • EH&S Field Coordinator or Production Coordinator or Environmental Field Coordinator Responsible for the Investigation Review Notify Environmental/Safety/Field Otos Group Lead = Notifications to agencies for significant/reportable spills. if needed • Environmental Group Lead or Safety Group Lead or Field Ops/Construction/D&C Group Lead Notify Team Lead or EH&S Group Leads if reaches Level 3 incident Notifications to agencies for significant/reportable spills. if needed EH&S Group Leads or Tearr Leads - Notification to VP of Business Unit for significant/reportable spills - Business unit assigns appropriate personnel to review and close incident when all corrective actions have been closed_ • VP Business Unit Knowledge of significantireportable incident Business unit assiirts appropriate personnel to review and dose incident when all corrective actions have been closed. Reportable Spills for IMS The reportable spills/environmental releases in this document go above and beyond that defined at the Corporate EH&S level, this is to ensure employee and contractor responsibility to the environment_ !leen encana.coni ehs/Corti tat :... f . Where and How to Capture Spill Information IMS can be filled out by any individual. Once the Supervisor received the Initial report. they are responsible for the incident investigation. where at feast one corrective action must be taken. Further information located in the IMS User Guide (link on the EH&S homepage} http +fecr+ encana corn/ells/ Timeline for Reporting IMS should be reported to immediately or within a reasonable amount of time after spill discovery_ For spills reportable to the state, BLM, etc, the timeline varies by reporting agency See the spill response flowcharts for each Basin/Business Unit Page 19 of 31 Uncontrolled when printed APPENDIX E FREQUENTLY ASKED QUESTIONS What air emissions are included in `environmental releases'? Fugitive emissions are not included. Emissions to an environmental release include evaporation of toxic chemicals to the air from a spilled substance, within secondary containment or outside of it_ Do the spill flow charts override the Emergency Response Plans? No. The Emergency Response Plans for all fields come first. The flow charts are a guide to snootier level spills and reporting to IMS and outside agencies. What are Reportable Quantities? 40 CFR 302.4 table, see next page for calculated volumes based on fluids commonly used in our field operations. Reportable quantities are defined on pages 11-12 in the Wyoming guidance. What are common contaminants found in our field operations that are on the Reportable Quantities list? What are their Reportable Quantities? • Benzene 100 pounds • N -hexane: 5000 pounds • Methanol: 5000 pounds • Toluene: 1000 pounds • Xylene: 100 pounds Who contacts the agencies, if needed? This task is done by the EH&S Field Coordinator_ How are cumulative events, such as drips or leaks, rnanaged? Fix repeated drips or leaks as soon as possible to avoid a reportable spill Page 20 or 31 Uncontrolled when pnntea APPENDIX F CALCULATIONS FOR 40 CFR 302.4 REPORTABLE QUANTITIES Use the Zink below to access a calculating tool for a material's reportable. quantity HA, 1 .,1 ,1.ActiJll=biowse&solirznaTt+C+&vieyvivi.te l Material Hazardous Constituent CAS Number Hazardous Constituent (wt %) Haz2irdous Constlltuent RQ (I bs) Specific Gravity Specific Density (1blgal) Density of Water (IbigaI) Material RQ (gals) Material RQ (bbl) OTHER Condensate (Sweet) n -Hexane 50 51300 0.75 - 8.33 1.301 38.11 Benzene 1 1 00 0,75 - 8.33 1,601 38.11 Condensate (Sour) n -Hexane _ 50 51300 0.7 - 8.33 1,715 40.83 1 Benzene 1 1 00 0.7 - 8.33 1,715 40.83 Hydrogen Sulfide 0.0002 100 0.7 - _ _8.33 8,574,359 204,163.:01 Produced Water (sour) n -Hexane 1 5000 1.1 - 8.33 54,567 1,299.22 Benzene 1 _ 1 00 1 1 - 5.33 1,391 25.913 Hydrogen Sulfide 01 100 1 15,33 10,313 259.84 Produced Water (Sweet - Deep Gas) n -Hexane 1 51300 1 1 - 8.33 54.567 1,299.22 Benzene 1 1 00 1 1 8.33 1,091 ' 25.9B MultiChem DF7120 Defoamer Emulsion Breaker Xylene` 0.0001 1 00 0 875 8.33 13,7134,112 326,288.38 Multichem FA -4001 Foaming Agerlt/Corrosion inhibitor Ethylene Glycol 58 5000 1.056 8.33 i R80 23.33 Methanol 8 5000 1,056+ - 8,33 1,106 169.17 Multichem FA -4013 Foaming Agent/Corrosion inhibitor Methanol 26 61000 0.954 - 14.33 2,440 58.10 Multichem FA -4500 Low Temperature Foamor Ethylene Glycol 60 5000 - Methanol 10 51300 - Multichem HI -1000 Hydrate Inhibitor Methanol 40 5+700 8.28 8.33 1,510 35.94 Page Z1 of 31 Unrontrolied when printed Page 22 of 31 Uni ontrolled when printed Ethylene Glycol 15 51)00 - 8.28 8.33 4.026 95.85 Multichem MX365-4 Foaming Agent Methanol 25 5000 6.05 6.33 2.484 59,15 Multichem P-3139 ParaffinfAsphlatone Dispersant 1 oluene 1000 _ 0.77 1 Multichem P-3319 Paraffin Inhibitor toluene 1000 0.8659 Multichem 5-2008 Scalp inhibitor Methanol 30 5000 0,995 - 8.33 2,011 47.8.8 Multichem S-2009 Scale Remover IHydrochtoric acid 3 5000 1,086 - 8.33 _ 18,424 438,66 Ethylene Glycol 50 5000 1.086 - 8.33 1.105 26.32 Carolina, unleaded Benzene 4.9 100 0.78 - 8.33 314 7.48 Ethyl benzene 3 1000 0.78 - 8.33 5,130 122.15 n-riexane 4 5000 0.78 8.33 19,238 458.00 Methyl tert- butyl ether 15 1000 0.75 - 8.33 1,026 24.43 Toluene 25 1000 0.78 - 8.33 616 14.66 Xylene 15 100 0 73 - 8.33 103 2,44 Multichem P-3200 Xylene - 8p 1 00 0.8681 - 8.33 17 0.41_ Ethyl benzene 15 1000 0.8681 - 8.33 922 21.95 Multichem WC-7579 Water Clarifier Ethylene Glycal 70 5000 1-136 8.33 755 17.47 Methanol Methanol _ 100 5000 0.7918.33 759 18.07 OSW5200 Oxygen Scavenger Ammonium bisulfate 100 5000 1.347 - 8.33 446 10.61 Nickel sulfate _ 1 _ 1 00 1.347 6.33 891 21.22 Trotolite RBW264 Wator Clarifier Ethylene Glycol 30 51300 1 1558.33 1,732 41.25 Triothylone Glycol Ethylene Glycal 0,1 5000 1.1 - 8.33 545.673 12.992,21 Ethylene glycol Ethylene Glycol 90 5000 1.135 8.33 568 13.99 Multichem EB-1410 Emulsion Breaker Xylene 26 100 0.8915 - 8.33 52 1-23 Mercury In lhermemeters Mercury 100 1 13.59 - 8.33 0.009 0,0002 Polyken 1027 Primer Toluene 12 11700 1.03 - 8.33 1171 23.13 Methanol 1.5 5000 1,03 - 8.33 38,550 925.01 COMPLETIONS CHEMICALS Water Friction- Reducing Agent B400 Ammonium chloride _ 12125-02-9 5 51700 - 11 813 90,909 2,164.50 Page 22 of 31 Uni ontrolled when printed Page 23 of 31 Un'cnnlrolied when printed u1:lly{1: II^•I .1 I 11 I 11• 1 1 1-,III„',1i. ,i.' I, 111 1 1: 1111 1 pr.: RII 11 1.11 11 II I '1:.111 111 Ii 111111 11, _ 1 1 .I' I 1 111` 11 •1 1 1 1 .. 1 1., .11 11 :fl7,t I,. 1.1 II • . 1 1 1 Non -Emulsifying Agent W54 Meth 1ncrl 67.56-1 70 5000 0.9 8.33 7,937 188.96 1 ' I ...1 Ir•f,•II 1 II I 11 I'. J920 Component. Activator M7 Sodium hydroxide 1310-73-2 60 1000 1.5 8.33 1,111 26.46 ... 1 i -.-'i_„ 1, 1 •.I 1. Page 23 of 31 Un'cnnlrolied when printed Page 24 of 31 Uncontrolled when printed Y:- Flu,. i 111,11..1,• I , 1.,1',r Hi... ,. •. I, 11.,1 „.. 1 4 1 Caustic Soda, Liquid Sodium Hydroxide 1310.732 50 1000 l 5'l 8.33 157 3.74 1 .I I.. 1 , , 11; 1 I l:•. ,, i. ,, , ,, ,I, I'. 1II!,1. I ., 1.1 .11,111 ;1 L11, 1 .1 ,..c,., - 1 1 ,1 I'I'I,.,I,i e 1„1111 ,i1i li,_ p; ,. 1 _ NE -94D Methanol 67-56.1 00 5000 0.88 8.33 1,137 27.07 . t:711i!11E?,1111!, )1,4 rI1. . , •, I illi . ,•:i. _ , .. •. .. Page 24 of 31 Uncontrolled when printed Page 25 of 31 Uncontrolled when printed 11 _. II' I I Naphthalene 91-20-3' 1 100 0.86 - 8.33 1,364 32.48 I. 1 ,,,•1'' ,I,, .,1, '1 XLW-32 Methanol 64-56.1 90 5000 0.885• 8.33 754 17.94 Napa Antifreeze Cnolant NP001 Ethylene Glycol 107-21-1 100 5000 - 9 41 8.33 531 12.65 II I II 1'.11'.. • .I •.• Irl. .I I. Arctic -therm E-50 Ethylene Glycol 107-21-1 50 5000 1.068 - 8.33 1.124 28.76 II .,,I.. `-1•. 1.1 r•I NAPAJCRC Brakleen Brake Parts Cleaner- Non-chlorinatod Condensate (Sweet) Acetone 67.64-1 5000 60 0.811 8.33 1.234 29,37 Toluene 108-88-3 35 1000 0,8118• 33 423 10.07 Methanol 87-56-1 25 5000 0.811- 8.33 2.960 70.40 Hi, • ,I. ' ' l n•Hexane 110-64-3 50 5000 0.75• 8.33 1,601 38.11 Benzene 71-43-2 1 10 0.15 _ - 8.33 160 3.81 I. ,,l.11t;u I .. ... II .Ili_ Page 25 of 31 Uncontrolled when printed Page 26 of 31 Un controlled when printed Diesel #1 1 n1 Toluene 105.88-3 0,6 1000 0.5 - 8.33 26677 i 635,17 Napthalene 91-20-3. 0.6 100 0.9 - 8.33 2668 63.52 r� Diesel #2 A,;:� I' .. •I I ., Toluene 108-88.3 0.5 1000 0,9 - 8:33 26677 635.17 Napthalene 91-20-3 0.6 100 0.9 - 8.33 2,668 63.62 1 Kloan-Break :, 1 1. Methanol 67.56-1 13 5000 0.86 - 8.33 5,360 127.83 1 . 1111 I:• I'I I i 1. I 1 1 Page 26 of 31 Un controlled when printed Page 27 of 31 Unr.ontrolled when printed 1: t:11,Th t, , I, l it 6.174 - 1'. 11, I`a � ,,," 1•. l:Il.:, Biocide MC B--8630 Acetone 67-64-1 40 51010 0.9868 - 8.33 1.521 36.21 MC FA -4600 Foaming Agent . ','. 111' 1 a d. Ethylene Glycol 107-21-1 33 51300 1.084 - 8.33 1,378 39.95 MC DF -7120 DefoanteriEmulsion Breaker .1 Xylene 1330-20-7 25 100 0.876 - 8.33 55 1.31 „. 1.. ,,,;1 +1, ,`II„ I „ ,IIT .:I I . MC FA -4001 Foaming Agent/Scale & Corrosion Inhlbitor Combination Ethylene Glycol 107-21-1 58 5000 1.056 8.33 380 23.33 frL,, ,1,,11;'1 Methanol 67-56-1 8 51700 1.056 - 8.33 7,105 159.17 MC FA -4013 Foaming Agent/Scale and Corrosion Inhibitor 1 . r 1, .1:, 1 1 Melllanol 67-5U-1 25 51100 0984 - 8.33 2.440 58.10 1 Page 27 of 31 Unr.ontrolled when printed Page 28 of 31 Un:ontrolled when printed 11•'1--.., MC FA -4295 Foemer Methanol 67-58.1 25 5000 0.9677 8.33 2,481 59.07 1 ' 11„111.. , .1 . .•. .1 S.i Ethylene Glycol 107-21-1 5 5000 0.9677- 8.33 12,405 295.37 1 1. 11.:,:,1 1 1, MC WC -7579 Water Clarifier Ethylene Glycol 107-21-1 70 5000 1.136 -- 8.33 755 17.97 Methanol Methyl Alchal 67-56-1 99.8 5000 0.7803 - 8.33 762 18.14 Pipe Dope 2000 1.1 .,• '' 1 ,1 1;11 ,. Page 28 of 31 Un:ontrolled when printed Page 29 of 31 Uncontrolled when printed Copper 1111+ :+..1. 7440-50-8 7 51000 1.2 8.33 7,146 170.14 I I Produced Water Sweet From Crude 011 or Deep Gas Production) I,I i.. 11 1 , n -Hexane 110-54-3 1 513pfl 1.1 - 8.33 54.567 129922 Benzene 71-43-2 1 10 1.1 - 8.33 109 2.60 Pyroll Premium Starting Fluid 2.,i _ ii' Ethyl Ether 60-29-7 30 1 00 - 5,89 8,33 57 1.35 I.,+il i,on D4 12 I n A -"a- t !:III• 1 .•;•IW i l,•p l A[i.,001L,l n-tnJ 1.1+... 1..: ., .,• ., I'r".l1 I ill. r. I I -, '. I , . I Iv'',;iI I11._ •._1,•,d 111mo,. I. Chevron Regular Unleaded Gasoline r+.: ;, 1. 1 Page 29 of 31 Uncontrolled when printed Page 30 of 31 Uncontrolled when printed Benzene 71-43-2 4.9 10 0.8 - 8.33 31 0.73 Ethyl benzene 100-41-4 3 11000 0.8 - 8.33 5,002 119.10 Naphthalene 91-20-3 2 1 00 _ 0.8 8.33 750 17.86 11..11.1 Methyl tert- butyl ether {MTBE) 1834-04.4 15 1,000 0.8 - 8.33 1,000 23.82 _., I.II 1 , . .: is ,-� .. -r. 1 1 WSP 9030 1:. X11. 1.1. Methanol 67-56-1 70 51000 0:962 - 8:33 591 21.22 Ethylene Glycol 107-21-1 70 51000 0.982 - 8.33 B91 21,22 WFT 9527 Toluene 108-88.3 7 11000 0.89 - 8.33 1,827 45.88 Xylene 1330-20-7 70 100 0.89 - I 8.33 19 0.48 Methyl Isobutyl Ketone 108-10-1 5 51000 0.89 8.33 13,489 321.16 WET 97112W (W - CAP) Methanol 67.56-1 40 51000 1 - 8.33 1,501 35.73 Page 30 of 31 Uncontrolled when printed AFT 9785 (Mufti- tunettonal Foaming Agenty Muthaho 67-56-1 30 5000 1.03 - 8.33 1,943 48,25 WSP 9201 Methanol 67-56.1 40 5000 0.15527 I 8.33 1.780 41,90 _ Page 31 of 31 Unoon1rollea when pnnlen SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 APPENDIX C INSPECTION FORMS SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 Inspection Date: Area: Tanks Inspected: Monthly Visual Inspection Checklist Inspector: Signature: Item Yes No Remarks Is there any sign of leakage? Is the external coating damaged? Is the tank rusted, pitted, or deteriorated? Are there shell distortions? Are welds cracked? Has the foundation settled or eroded? Have tank supports deteriorated or buckled? Are valves, fittings, or other appurtenances leaking? Has the secondary containment been damaged? Is there oil in secondary containment? Is there debris in secondary containment? Is there water in secondary containment? Are the drain valves for the secondary containment operable and in a closed position? Are valves locked if not in use? SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 Other Comments: SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 Inspection Date: Area: Annual Inspection Checklist Tanks Inspected: Inspector: Item Yes No Remarks Evidence of paint failure? Evidence of corrosion or cracking? Any noticeable distortion, buckling denting, or bulging? Holes in roof? Standing water on roof? Vents free of obstructions? Is the liquid level gauge, if present, operable? Is the containment structure in satisfactory condition? Are the containment drainage valves and pipes fit for service? Evidence of tank settlement or foundation washout? Is there cracking or spalling of concrete pad? Are tank supports in satisfactory condition? Is water able to drain away from tank SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 within containment? Is grounding strap secured and in good condition? Is associated piping in good condition? Is there any sign of leakage from the tank or associated piping or valves? Is piping properly supported? Other Comments: SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 Inspection Date: Portable Container Monthly Inspection Checklist Drum Storage Areas Inspected: Inspector: Item Yes No Remarks Any visible sign of leakage from containers? Any oil within containment area? Noticeable container distortions, buckling, denting, or bulging? Are container lids secured? Is there water in the secondary containment? Are there drain valves for the secondary containment operable? Are the drain valves in a closed position? Is there debris in containment or storage area? Other Comments: SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 APPENDIX D PLAN REVIEW AND AMENDMENT LOGS SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 Log of SPCC Plan Reviews By signature below, the undersigned agree to the following: "I have completed a review and evaluation of the SPCC plan on the date given below and the SPCC plan will or will not be amended (as indicated below) as a result of that review." Review Date Reviewer Signature Will Plan be amended? (Y/N) 6/14/2011 James B. Cowart, P.E. No SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 Log of SPCC Plan Amendments Amendment Date Summary of Modifications Management Approval (Signature) PE Certification (as needed) SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 APPENDIX E SPILL HISTORY LOG SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 Spill History Log Story Booster Compressor Station Date of Spill Structure and Volume Spilled Actions Taken (control measures, agencies notified, etc.) Reference Documentation 12/1/2010 See Attached See Attached See Attached encana rj�'arr�l S First Report Incident Title Incident Report Near Hit Hazard Identification Production_O03 lNPM]_Produced VN''ater (300B8L) Number: 12010-02070 Status: Investigation Review Person Involved: Murray, Lewis Description Received approval' to drain a slug ca°cher into a produced water tank. Tank level measurements showed tank level to be only at 4 feet While draining the slug catcher. the produced water tank overflowed The tank level measurement system was nol operating properly The produced water was shut in and vacuum trucks were secured to evacuate the containment The release was limited to the synthetically lined containment 2-7-2011 Brant 0 cahnged the area of this incident from E&P to Facilities Incident Types Injury Fire/Explosion ,/ Equipment Failure Community Affairs Occupational Illness ,/ Environmental Release/Spill Location & Date Motor Vehicle Security Property Damage Regulatory Citation Region USA Division Business Unit Southern Rockies Business Unit Sub Business Unit N Piceancp Area Facilities Site Activity Pipeline and Compressors WellIRig/Mile Post Marker 003 well pad Occurred on Company Yes Premises Equipment lank level equipment failure Gate of Occurrence 12/1/2010 Time of Occurrence 3.00 AM Person involved Person Involved Murray. Lewis Relationship to Company Employee EnCana Supervisor Wilczek. Vance Date Shift Began 12/112010 Time Shift Began 12:00 AM Incident Relationship Encana Description of Task or Activity at Time of Incident Received approval to drain slug catcher into tank Tank "radar"' showed only 4 fool of water in tank 'Radar' system +vas not operating properly Draining the slue catcher caused the tank to overfill Describe Physical or Immediate Causes of incident False tank level measurement, track of visual backup check All overfill water was contained within the containment. Approxunatety 300 BBLs of water in containment immediate Action Taken Vacuum trucks were secured to pump out the containment Pace 1 of 3 Witness Information Follow Up Responsibilities Responsible for investigation Jensen Jr., Charles H_ Reported By Reported By nvestigation Jensen Jr_, Charles H. Reportable Spill/Environmental? Yes Date Reported 12/1/2010 Agency External Party or Agency External Report ©ate Name/Contact Number Reported State Oil & Gas COGCC/Chris Canfield Form 19 12/1/2010 Commission Insurance Group Notified No PPE Worn? Yes PPE Worn Hard Hat, Hearing Protection, Safety Glasses, Steel -toed Boots. Fire Retardant Clothing Was a drug test performed? No Was an alcohol test No performed? Environmental Release/Spill Information Substance Type Liquid CAS Number Commodity Produced Water Source Tank impact To Land Quantity Escaped 300 bbis Quantity Recovered 300 bbls Onsite Area Affected 500 sq ft Offsite Area Affected 0 sq ft Duration of Release 3 h Weather Conditions Clear Rentediatiuri Required No Equipment Failure information Equipment Class Instrumentation Equipment Tag # Equipment Type Tanks Equipment Sub Type Cause OUT OF CALIBRATION Action Taken Costs Cost Type Amount Description Severity Level Seventy Level Minor A level of Minor will be defined as First Aid minor environmental damage (less than 10 bblsl production and equipment loss less than S100.000 A level of Moderate will be defined as Restricted work medical treatment other than first aid, moderate environmental damage (spill greater than 10 bbls). production and equipment loss greater than S100,000 A level of Major will be defined as. Lost time Injury. short-term health impact severe short-term environmental damage, production and equipment foss greater than 51 MM Page 2 of 3 A revel of Serious will be defined as Fatality, long-term health impact, permanent disability severe long-term environmental damage. or production and equipment toss greater than $10 MM Root Cause Analysis Human Performance Difficulty Quality Control' Quality Control Needs Improvement In techniques need improvement Follow Up Responsibilities Responsible for Investigation Review Responsible for Incident Closure Corrective Actions Corrective Action Tank level measurement repair Person Responsible Person Delegated Due Date Priority Status Murray. I._ewts Ankrum Brad ibankrum) Procedure review/possible visual Wilczek. Vance Ankrum. Brad check as backup tbankrum} Resize Story Booster Slug Catcher Pump Supplementary Information Notes Jensen Jr Charles H Valentine. Mike 02112 .,2010 0612/201U 2 2$11212010 4 Closed Ciosed Closed 2010-12-01 14.42 - Jensen Jr Charles H - Description when submitted 'Received approval to drain a slug catcher into a produced water tank. Tank level measurements showed tank level to be only at 4 feet White draining the slug catcher. the produced water lank overflowed The tank level measurement system was not operating properly The produced water was shut in and vacuum trucks were secured t0 evacuate the containment The release was limited to the synthetically tined containment' 2010-12-01 14-42 - Jensen Jr Charles H. - Immediate Action Taken when submitted 'Vacuum trucks were secured to pump out the containment ' Generated May 26 2011 9 32A MST Page 3of3 SPCC Plan — Story Booster Compressor Station Encana Oil & Gas (USA) Inc. June 14, 2011 APPENDIX F SECONDARY CONTAINMENT CALCULATIONS These are the only areas that need to be filled in for these calculations. Secondary Containment Capacity Calculation (Pill Shape) Facility Name: Story Booster CS (003 Well Pad) Radius Width 25-year 24-hour precipitation event: 2.2 inches Tank Information Length Largest Tank (bbl) Tank Diameter (ft) Tank Deduction (bbl) Containment Dimensions 400.0 12.0 Tank #2 (bbl) Tank #2 Diameter (ft) Tank #2 Deduction (bbl) Containment Radius (ft) 0.0 15.00 Tank #3 (bbl) Tank #3 Diameter (ft) Tank #3 Deduction (bbl) Containment Width (ft) 0.0 30.0 Tank #4 (bbl) Tank #4 Diameter (ft) Tank #4 Deduction (bbl) Containment Length (ft) 0.0 40.0 Containment Height (ft) Tank #5 (bbl) Tank #5 Diameter (ft) Tank #5 Deduction (bbl) 2.5 0.0 Effective Containment Height (ft) (less 25-yr 24-hr Storm) Tank #6 (bbl) Tank #6 Diameter (ft) Tank #6 Deduction (bbl) 2.32 0.0 Tank #7 (bbl) Tank #7 Diameter (ft) Tank #7 Deduction (bbl) Containment Capacity 0.0 Tank #8 (bbl) Tank #8 Diameter (ft) Tank #8 Deduction (bbl) Gross Containment Capacity (bbl) 0.0 786.8 Net Containment Capacity (bbl) Total Tank Deduction (bbl) 0.00 786.8 Is Secondary Containment Adequate for the Largest Vessel = Yes These are the only areas that need to be filled in for these calculations.