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HomeMy WebLinkAbout1.1 Application Cont. Ursa Operating Company LLC Oil Production Facility SPCC Plan 11 1.3 Substantial Harm Certification Example Form The below form will be completed for each facility subject to the SPCC regulations. Site specific forms are included in the following subsections. Facility Name: Facility Location: The mailing address of the facility is: 1050 17th Street, Suite 2400 Rifle, Colorado 81650 1. Does the facility have a maximum storage capacity of oil greater than or equal to 42,000 gallons and do the operations include over water transfers of oil to or from vessels? Yes _____ No 2. Does the facility have a maximum storage capacity of oil greater than or equal to one million (1,000,000) gallons and is the facility without secondary containment for each aboveground storage area sufficiently large to contain the capacity of the largest aboveground storage tank within the storage area? Yes _____ No 3. Does the facility have a maximum storage capacity of oil greater than or equal to one million (1,000,000) gallons and is the facility located at a distance such that a discharge from the facility could cause injury to an environmentally sensitive area? Yes _____ No 4. Does the facility have a maximum storage capacity of oil greater than or equal to one million (1,000,000) gallons and is the facility located at a distance such that a discharge from the facility would shut down a public drinking water intake? Yes _____ No 5. Does the facility have a maximum storage capacity of oil greater than or equal to one million (1,000,000) gallons and within the past 5 years has the facility experienced a reportable spill in an amount greater than or equal to 10,000 gallons? Yes _____ No Note: Tanks which store non-petroleum related liquids have not been included in the maximum storage capacity 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. Authorized Management Representative: S i g n a t u r e : D a t e : Name: Title: r Ursa Operating Company LLC Oil Production Facility SPCC Plan 12 1.3.1 Battlement Mesa Substantial Harm Certifications Ursa Operating Company LLC Oil Production Facility SPCC Plan 16 1.3.2 Castle Springs/Wolf Creek Substantial Harm Certifications Ursa Operating Company LLC Oil Production Facility SPCC Plan 27 1.3.3 North Gravel Trend/Roan Substantial Harm Certifications Ursa Operating Company LLC Oil Production Facility SPCC Plan 28 1.3.4 Gravel Trend Substantial Harm Certifications Ursa Operating Company LLC Oil Production Facility SPCC Plan 71 1.4 Plan Review and Amendments LOG OF PLAN REVIEW AND AMENDMENTS NON TECHNICAL AMENDMENTS • Non-technical amendments are not certified by a Professional Engineer. • Examples of changes include, but are not limited to phone numbers, name changes, or any non- technical text change(s). TECHNICAL AMENDMENTS • Technical amendments are certified by a Professional Engineer. • Examples of changes include, but are not limited to, commissioning or decommissioning containers; replacement, reconstruction, or movement of containers; reconstruction, replacement, or installation of piping systems; construction or demolition that might alter secondary containment structures; changes of product or service; or addition/deletion of standard operation or maintenance procedures related to discharge prevention measures. It is the responsibility of the facility to determine, and confirm with the regulatory authority as necessary, what constitutes a technical amendment. The preamble of the rule states that an amendment is required only “when there is a change that materially affects the facility’s potential to discharge oil” (67 FR 47091). • An amendment made under this section will be prepared within six (6) months of the change and implemented as soon as possible but not later than six (6) months following preparation of the amendment. • Technical Amendments affecting various pages within the plan can be P.E. certified on those pages, certifying those amendments only, and will be documented on the log form below. MANAGEMENT REVIEW 1. Management will review and amend this SPCC Plan at least each five (5) years or when there is a change in the facility design, construction, operation, or maintenance that materially affects its potential for a discharge. The review will be documented on the form below. 2. Management will review and amend this SPCC whenever there is a discharge of more than 1000 gallons of oil into or upon navigable waters in a single discharge or a discharge of more than 42 gallons of oil in each of two discharges occurring within any twelve month period. The Plan will be submitted to the Regional Administrator within 60 days. REVIEW AND AMENDMENT LOG Review/ Amend Date Signature * (Specify) Amend Plan (will/will not) Description of Review Amendment Affected Pages or Section PE Certification (Y/N) October 2013 Will Addition of Site Specific SPCC Plans (Dever C and Norcross A, both within the Gravel Trend Field) Appendix A Yes December 2013 Will Addition of Site Specific SPCC Plan, Castle Springs Compressor Station Appendix A Yes    Ursa Operating Company LLC Oil Production Facility SPCC Plan 72 REVIEW AND AMENDMENT LOG Continued Review/ Amend Date Signature * (Specify) Amend Plan (will/will t) Description of Review Amendment Affected Pages or Sections PE Certification (Y/N) February 2014 Will Addition of Site Specific SPCC Plans, Speakman A, McLin B, McLin C, non- technical amendments Appendix A, Certification of Harm pages, Updated notification numbers, reporting table, inspection form, 3.1.3.a., Yes *Typically signed by Manager, Professional Engineer or plan reviewer. Ursa Operating Company LLC Oil Production Facility SPCC Plan 73 2.0 FACILITIES, PROCEDURES, METHODS, OR EQUIPMENT NOT YET FULLY OPERATIONAL This SPCC Plan is being drafted in accordance with federal, state and local regulatory requirements. Per site inspections completed by a third party consulting group, deficiency items must be addressed to obtain compliance with federal, state and local SPCC regulations and requirements. Ursa is aware of the non-compliance items and is making the necessary efforts to address the compliance items defined in Table 5 of the Site Specific SPCC Plans (Appendix A). Ursa Operating Company LLC Oil Production Facility SPCC Plan 74 3.0 SPCC PLAN POLICIES AND PROCEDURES This SPCC Plan, hereinafter referred to as ‘the plan’, is a carefully conceived document prepared to address onshore production facilities in Colorado operated by Ursa Operating Company LLC (Ursa) which are subject to the federal SPCC regulations. There are several additional State of Colorado SPCC-related requirements which are supplemental to the EPA oil pollution prevention regulations (40 CFR 112). The applicability of these regulations will be discussed in the site specific spcc plans contained in Appendix A. This plan was developed to satisfy the applicable state and federal requirements. Specifically, this plan was developed to: • Communicate pollution prevention requirements to Ursa employees. • Document Ursa’s SPCC procedures and measures. • Enable Ursa employees to report a spill and provide all the necessary information in the event of a release. • Assist Ursa in contacting and reporting pertinent information to the appropriate agencies. • Provide site-specific information in a simple way. Based on the type of respective operating facilities, the plan addresses both the general plan regulatory requirements specified in 40 CFR 112.7 and those specific to onshore production facilities 40 CFR 112.9. To ensure coverage of applicable regulations, a Regulatory Cross Reference was provided at the beginning of this plan. It identifies salient sections of the regulation in accordance with the plan section in which it is addressed. General requirements applicable to each facility and to the overall management of SPCC-related activities are included in the main text portion of the plan. Appendix A provides site specific information for each individual facility covered by the SPCC plan. This information includes a site layout, description of equipment, volume and type of material stored, surface water flow directions, and spill prevention controls. Technical amendments, such as addition of hydrocarbon storage containers, to this plan will be issued within 6 months as mandated by 40 CFR 112.5. Such amendments will be certified by a professional engineer if the amendment is considered to be technical. In accordance with pertinent regulations, non-technical Plan amendments/reviews and revisions will also be issued on a timely basis by personnel with the appropriate level of authority. This plan conforms to the SPCC Regulations and was developed in accordance with sound engineering practices. Any deviations from regulatory requirements that were noted during the development of this plan are noted on Table 2. A complete copy of the SPCC Plan is maintained at the Rifle Field Office and at the Denver Corporate Office. Ursa Operating Company LLC Oil Production Facility SPCC Plan 75 3.1 Owner Information Name: Ursa Operating Company LLC Address: U.S. Operations 1050 17th Street, Suite 2400 Denver, CO 80265 Regional Address: 792 Buckhorn Drive Rifle CO, 81650 Company Contacts: Robert Bleil, Ursa Regulatory & Environmental Manager Tara Mall, HSE Facility Location: This SPCC Plan is applicable to onshore production facilities operated by Ursa in Colorado. Site specific information is located within the Appendix A of this plan. 3.1.1 Facility Layout Details for each facility covered by this plan are provided in Appendix A of this plan. In general, the physical layout of an onshore production facility is associated most often with a well pad. Equipment associated with the well pad includes, but is not limited to, separators, dehydrators, wellheads, above/below ground piping, produced water tanks, condensate tanks, methanol tanks, production pits, and miscellaneous storage. The equipment on the well pad is typically organized in a manner which facilitates safe and efficient automobile navigation. The valves associated with tanks, holding either oil or other chemicals, are kept in the closed and locked position to help ensure unintentional flow does not occur when the tank is not being actively used. The area around the tanks is kept free and clear of debris that could pose a safety hazard (e.g. fire, traffic). Storm water which flows across uncontained portions of the site is not anticipated to come into contact with hydrocarbons. Visual inspections of the entire location are performed by designated personnel or third party contractors as described in Section 3.3 of this plan with regards to SPCC requirements and the Storm Water Management Plan with regards to storm water management. 3.1.2 Tanks, Piping and Equipment The condensate and produced water tanks (tanks) are considered bulk storage tanks/containers under the SPCC regulation. All tanks were built in accordance with API Specification 12F Shop Welded Tanks for Storage of Production Liquids design. All enclosed tanks are equipped with gas vents to relieve any pressure that might build up inside the tank, and are also equipped with vacuum protection that prevent over or under pressuring of the tanks. All tanks are equipped with hatchways for venting, gauging and/or access. All tanks should have stairways and hand railings to facilitate worker safety when the gauging operations are underway. The tanks have been sized to provide sufficient capacity to prevent overfilling. Tanks are gauged periodically to Ursa Operating Company LLC Oil Production Facility SPCC Plan 76 monitor the oil level to ensure that sufficient tank capacity is available for storage of produced water or condensate. It should be noted that separator units are also considered to be bulk storage containers and are subject to sized secondary containment and periodic inspection. As described in Section 3.3, tanks are visually inspected on a regular basis for leaks, corrosion, and any other malfunctions or deterioration. The tanks are also integrity tested prior to placement at the facility. The equipment and associated hose is compatible with the fluids stored and storage conditions such as pressure and temperature. Any flowlines are to be compatible with the materials being transferred through them. Flowlines shall be powder coated and/or painted. 3.1.3 Containment Structures Corrugated steel containment structures or earthen berms are present to provide secondary containment for bulk storage structures. The storage volume of the respective secondary containment is large enough to contain the entire capacity of the largest single container in the secondary containment plus sufficient freeboard to allow for precipitation taking into account for displacement as applicable. Additional storage volume may be required in the event the facility is located in a Colorado Oil and Gas Conservation Commission (COGCC) high density area or the intermediate or internal 317B buffer zone. Locations located within setback areas are also subject to additional containment requirements. Section 3.1.3.a provides the respective information. In addition, many of the facilities have a perimeter earthen berm around the well pad which can provide secondary containment for separators, and condensate and produced water loading and unloading activities. Should a release occur, the earthen berm will prevent migration of the spilled material away from the site and allow Ursa to control and mitigate the release in a timely and efficient manner. If a site perimeter berm is utilized as secondary containment, a waterbar should be installed at the pad’s entrance, and any storm water diversion features should drain to a catchment basin. These structures help to ensure releases of produced water (i.e. oil) at facility on the surface are contained. In some areas, there may be additional secondary containment requirements. Please see below for additional requirements which may be applicable to facilities subject to this spcc plan. 3.1.3.a Additional Regulatory Requirements: COGCC: For facilities located in a Colorado Oil and Gas Conservation Commission (COGCC) high density area, and/or a 317B Area, additional stipulations pertaining to SPCC requirements will apply as provided below: COGCC 317B.d Requirements for Drilling Completions Production and Storage Operations at New Oil and Gas Locations in the Intermediate Buffer Zone: The following shall be required for all DCPS Operations at New Oil and Gas Locations within a Surface Water Supply Area and in the Intermediate Buffer Zone as defined in Table 1. (1) Pitless drilling systems; (2) Flowback and stimulation fluids contained within tanks that are placed on a well pad or in an area with down gradient perimeter berming; (3) Berms or other containment devices shall be constructed in compliance with Ursa Operating Company LLC Oil Production Facility SPCC Plan 77 Rule 603.e.(12) 605.a.(4)1 and 906.e.(1)1 around crude oil, condensate, and produced water storage tanks COGCC 604. Setback and Mitigation Measures for Oil and Gas Facilities, Drilling, and Well Serviceing Operations Exception Zone Setback. No Well or Production Facility shall be located five hundred (500) feet or less from a Building Unit except as provided in Rules 604.a.(1) A and B, and 604.b. Buffer Zone Setback. No Well or Production Facility shall be located one thousand (1,000) feet or less from a Building Unit until the Operator certifies it has complied with Rule 306.e. and the Form 2A or Form 2 contains conditions of approval related to site specific mitigation measures as necessary to eliminate, minimize or mitigate potential adverse impacts to public health, safety, welfare, the environment, and wildlife. High Occupancy Buildings. No Well or Production Facility shall be located one thousand (1,000) feet or less from a High Occupancy Building Unit without Commission approval following Application and Hearing. Exception Zone Setback mitigation measures pursuant to Rule 604.c. shall be required for Oil and Gas Locations within one thousand (1,000) feet of a High Occupancy Building, unless the Commission determines otherwise. Designated Outside Activity Areas. No Well or Production Facility shall be located three hundred fifty (350) feet or less from the boundary of a Designated Outside Activity. The Commission, in its discretion, may establish a setback of greater than three hundred fifty (350) feet based on the totality of circumstances. Buffer Zone Setback mitigation measures pursuant to Rule 604.c. shall be required for Oil and Gas Locations within one thousand (1,000) feet of a Designated Outside Activity Area, unless the Commission determines otherwise. Maximum Achievable Setback. If the applicable setback would extend beyond the area on which the Operator has a legal right to locate the Well or Production Facilities, the Operator may seek a variance under Rule 502.b. to reduce the setback to the maximum achievable distance. Mitigation Measures. The following requirements apply to an Oil and Gas Location within a Designated Setback Location and such requirements shall be incorporated into the Form 2A or associated Form 2 as Conditions of Approval. Leak Detection Plan. The Operator shall develop a plan to monitor Production Facilities on a regular schedule to identify fluid leaks. Berm construction. Berms or other secondary containment devices in Designated Setback Locations shall be constructed around crude oil, condensate, and produced water storage tanks and shall enclose an area sufficient to contain and provide secondary containment for one-hundred fifty percent (150%) of the largest single tank. Berms or other secondary containment devices shall be sufficiently impervious                                                              1 The regulatory references are not currently finalized. Upon finalization, the text will be updated. Ursa Operating Company LLC Oil Production Facility SPCC Plan 78 to contain any spilled or released material. All berms and containment devices shall be inspected at regular intervals and maintained in good condition. No potential ignition sources shall be installed inside the secondary containment area unless the containment area encloses a fired vessel. Refer to American Petroleum Institute Recommended Practices, API RP - D16. Tank specifications. All newly installed or replaced crude oil and condensate storage tanks shall be designed, constructed, and maintained in accordance with National Fire Protection Association (NFPA) Code 30 (2008 version). The operator shall maintain written records verifying proper design, construction, and maintenance, and shall make these records available for inspection by the Director. Only the 2008 version of NFPA Code 30 applies to this rule. This rule does not include later amendments to, or editions of, the NFPA Code 30. NFPA Code 30 may be examined at any state publication depository library. Upon request, the Public Room Administrator at the office of the Commission, 1120 Lincoln Street, Suite 801, Denver, Colorado 80203, will provide information about the publisher and the citation to the material. Exception Zone Setback. Within the Exception Zone Setback, the following mitigation measures will be mandatory: . All mitigation measures required pursuant to subsection 604.c.(2), above, and Berm Construction: i. Containment berms shall be constructed of steel rings, designed and installed to prevent leakage and resist degradation from erosion or routine operation. ii. Secondary containment areas for tanks shall be constructed with a synthetic or engineered liner that contains all primary containment vessels and flowlines and is mechanically connected to the steel ring to prevent leakage. iii. For locations within five hundred (500) feet and upgradient of a surface water body, tertiary containment, such as an earthen berm, is required around Production Facilities. iv. In an Urban Mitigation Area Exception Zone Setback, no more than two (2) crude oil or condensate storage tanks shall be located within a single berm. COGCC 605. Oil and Gas Facilities Atmospheric tanks used for crude oil storage shall be built in accordance with the standards specified with the respective regulation. (2) Tanks shall be located at least two (2) diameters or three hundred fifty (350) feet, whichever is smaller, from the boundary of the property on which it is built. Where the property line is a public way the tanks shall be two thirds (2/3) of the diameter from the nearest side of the public way or easement. A. Tanks less than three thousand (3,000) barrels capacity shall be located at least three (3) feet apart. B. Tanks three thousand (3,000) or more barrels capacity shall be located at least one-sixth (1/6) the sum of the diameters apart. When the diameter of one tank is less than one-half (1/2) the diameter of the adjacent tank, tanks shall be located at least one-half (1/2) the diameter of the smaller tank apart. (3) At the time of installation, tanks shall be a minimum of two hundred (200) feet from any building unit.(4) Berms or other secondary containment devices shall be constructed around crude oil, condensate, and produced water tanks to provide secondary containment for the largest single tank and sufficient freeboard to contain precipitation. Berms and secondary containment devices and all containment areas shall be sufficiently impervious to contain any spilled or released Ursa Operating Company LLC Oil Production Facility SPCC Plan 79 material. Berms and secondary containment devices shall be inspected at regular intervals and maintained in good condition. No potential ignition sources shall be installed inside the secondary containment area unless the containment area encloses a fired vessel.(5) Tanks shall be a minimum of seventy-five (75) feet from a fired vessel or heater treater.(6) Tanks shall be a minimum of fifty (50) feet from a separator, well test unit, or other non-fired equipment.(7) Tanks shall be a minimum of seventy-five (75) feet from a compressor with a rating of 200 horsepower, or more.(8) Tanks shall be a minimum of seventy-five (75) feet from a wellhead.(9) Gauge hatches on atmospheric tanks used for crude oil storage shall be closed at all times when not in use.(10) Vent lines from individual tanks shall be joined and ultimate discharge shall be directed away from the loading racks and fired vessels in accord with API RP 12R-1, 5th Edition (August 1997, reaffirmed April 2, 2008). Only the 5th Edition of the API standard applies to this rule; later amendments do not apply. The API standard is available for public inspection during normal business hours from the Public Room Administrator at the office of the Commission, 1120 Lincoln Street, Suite 801, Denver, Colorado 80203. In addition, these materials may be examined at any state publication depository library. (11) During hot oil treatments on tanks containing thirty-five (35) degree or higher API gravity oil, hot oil units shall be located a minimum of one hundred (100) feet from any tank being serviced. 906.e.(1) Spill/Release Prevention Secondary containment. Secondary containment that was constructed before May 1, 2009 on federal land, or before April 1, 2009 on other land, shall comply with the rules in effect at the time of construction. Secondary containment constructed on or after May 1, 2009 on federal land, or on or after April 1, 2009 on other land shall be constructed or installed around all tanks containing oil, condensate, or produced water with greater than 3,500 milligrams per liter (mg/l) total dissolved solids (TDS) and shall be sufficient to contain the contents of the largest single tank and sufficient freeboard to contain precipitation. Secondary containment structures shall be sufficiently impervious to contain discharged material. Operators are also subject to tank and containment requirements under Rules 603. and 604. This requirement shall not apply to water tanks with a capacity of fifty (50) barrels or less. Federal Leases Onshore Order 3 For facilities which are subject to Onshore Order 3 (i.e. assets located on Federal leases, or wells and facilities on State or privately-owned mineral lands committed to a unit or communitization agreement that affects Federal or Indian interests), valves and other points which oil could be loaded out of will be subject required to be marked with a unique identifier called a seal to ensure oil (i.e. condensate) is not unloaded from the equipment without the volume being documented and provided to the respective federal agent (i.e. bureau of Land Management official, or Bureau of Indian Affairs official). For additional information pertaining to the requirements of Ursa Operating Company LLC Oil Production Facility SPCC Plan 80 this regulation please see Attachment 1. 3.1.4 Potential Discharge Volume and Direction of Flow The direction of flow will be specific to the respective location the facility is associated with, and is noted within the site specific plan(s) included within Appendix A. Please see below for examples of potential discharge volumes and causes. One scenario for release of oil is the loss of containment of the largest tank at any particular facility due to rupture (300 bbl. example tank size). This could result in the release of up to 12,600 gallons of oil within one hour. Oil would spill into the secondary containment. In this scenario, oil would be contained within the secondary containment. Another possible scenario would be the release of oil outside the secondary containment during truck loading/unloading activities; such as a ruptured hose connection on water truck. This could result in the release of approximately 150 gallons of oil per minute, until the attendant could access the shutoff valve. The volume of oil released during this scenario is variable. A third possible scenario would be the rupture of a flowline outside of secondary containment due to equipment failure. This could result in the release of approximately 150 gallons of oil per hour, until the failure is noticed during routine inspections. The volume of oil released during this scenario is variable. In all instances, the spill response and notification procedures provided in Ursa’s Spill Prevention and Management Plan would be implemented in an orderly and efficient manner. In addition to the Spill Prevention and Management Plan, an Oil Spill Contingency Plan is included with this plan. 3.1.5 Proximity to Navigable Waters All facilities are located within the Colorado River watershed. The surface water proximity is illustrated within maps and tables contained in Appendix A. In the event of an uncontrolled discharge from a facility, oil would follow the natural topography of the landscape. Additionally, each facility diagram within the site specific plan depicts the anticipated direction of runoff from the facility and the distance relative to the potentially impacted navigable waterway. 3.1.6 Site Specific Facility Diagrams Site specific facility maps and diagrams are included in Appendix A with the following detail and location information as applicable: • Process equipment, • Fixed aboveground storage tanks. • Direction of surface water runoff. • Completely buried and bunkered tanks (including USTs covered under 40 CFR 280 or 281). • Drum and portable container storage areas. • The type of oil and storage capacity. • Material of construction for all containers. Ursa Operating Company LLC Oil Production Facility SPCC Plan 81 • Connecting pipes including intra-facility gathering lines. 3.1.7 SPCC Plan Development Tables Site specific SPCC detail tables were drafted for each facility included in this plan. Details from the development tables such as the number of tanks, capacity, contents, and secondary containment descriptions are provided in Tables 2, 3 and 4 of the respective site specific plans. The development tables were created to standardize SPCC site inspections and maintain a database of information including but not limited to: • General facility information. • Tank information. • Processing equipment. • Containment/loadout information. • Failure information outside of containment. • Facility property information. • Surrounding drainage. • Comments. Ursa Operating Company LLC Oil Production Facility SPCC Plan 82 3.2 General Requirements 3.2.1 Discovery, Response and Cleanup of Releases The respective facilities are inspected routinely as described in Section 3.3.2. In the event a release is discovered, the protocol provided in the Spill Prevention and Management Plan will be implemented. Section 3.5.1 of this plan provides guidance with regards to annual training requirements. It is recommended that oil handling personnel obtain and maintain the appropriate Hazwoper training for their position. All recovered materials will be handled in accordance with all applicable federal, state and local laws and regulations as described in the Spill Prevention and Management Plan and Section 3.4 of this plan. 3.2.2 Notification Contacts Robert Bleil or Tara Mall: - 970-625-9922 – Rifle Office Number - 720-425-0303 – Robert Mobile - 970-618-2155 – Tara Mobile - 720-508-8350 – Denver Office Please see the flowcharts included in Appendix B if the above personnel cannot be contacted, should a release occur, additional information is provided in the Spill Prevention and Management Plan. Prior to any notification to agencies, the Spill Prevention and Management Plan will be utilized to determine the agency notification requirements. 3.2.3 Notification Forms The appropriate forms which must be completed prior to reporting a spill are included in this plan as Appendix D. For additional information, please refer to the Spill Prevention and Response Plan and Appendix B of this plan. 3.2.4 Response Plan General information on the response to, and reporting of, oil discharges can be found in the Spill Prevention and Response Plan. Additional information is located within Section 3.4 of this plan and the attached Oil Spill Contingency Plan, a copy of which is provided in Appendix B. The Oil Spill Contingency Plan describes procedures that will be implemented under various emergency scenarios, including when an oil discharge occurs. The plan is also designed to address releases from areas such as flowlines where secondary containment is not practical. Ursa Operating Company LLC Oil Production Facility SPCC Plan 83 3.3 Routine Facility Operations, Inspections and Maintenance Ursa’s oil spill prevention program is described in this section of the SPCC plan and includes routine facility operations, periodic inspections and maintenance activities. It addresses all routine activities associated with the oil production facilities as required by 40 CFR 112.7 and 112.9. 3.3.1 Facility Operations All equipment is operated and positioned in a way which is designed to prevent and contain releases. Load line and drain valves are maintained in a closed position when not in use. The facility is visited periodically by Ursa personnel. The volume of liquid is gauged and the fluid level in each tank is assessed prior to loading or offloading oil2 when the inventory approaches the tank capacity. The designated personnel also performs a visual inspection of all above ground vessels, tank hatches, valves, and secondary containment features to ensure issues are promptly identified as described in Section 3.3.2. Tank truck loading/unloading occurs at all the facilities covered in this plan. However, the facilities will not have a loading/unloading rack as defined by 40 CFR 112.2. The tanks may be connected to each other via piping, or each tank may be self-contained within the secondary containment area. Trucks used to offload oil are positioned adjacent to the secondary containment structures and are attended by the personnel during all loading and unloading activities. All loading and unloading activities are conducted by qualified contract personnel who are trained in proper loading and spill prevention techniques and procedures. Pumper truck personnel inspect tank truck and transfer lines including drains and outlets on the tank trucks prior to filling and before departure to ensure that there are no leaks or discharges. If necessary, truck personnel tighten, adjust, or replace equipment that is leaking. Premature vehicular departures are prevented with a manual air brake system and oversight. A Summary of Operating Procedures (SOP) can be found in Appendix E. 3.3.2 Facility Inspection Program Tanks containing oil are inspected periodically. Designated personnel are trained to identify and report any leaks or other deficiencies (e.g. compromised secondary containment). Inspections are conducted on a monthly basis and include review of equipment, tanks, valves, hatches, and lines; the site drainage system; and the entire tank battery, including the area within the containment structures and earthen berms. Specifically, each storage vessel, separator, and miscellaneous equipment is visually inspected for deterioration and maintenance needs, including the foundation and support of each tank/container located on or above the ground surface. The inspection also includes visual check of facility transfer equipment including transfer piping and valves, drip pans, pumping well polish rod stuffing boxes, tanks, separators, heater-treaters, valve glands and bodies, pipe supports, and bleeder and gauge valves. Inspection of conditions associated with buried flowlines is accomplished by observing the ground surface above the lines for evidence of leaks on a routine basis. Please see the inspection form included as Appendix D. It should be noted that some locations will have additional inspection requirements                                                              2 Oil means oil of any kind or in any form, including, but not limited to: fats, oils, or greases of animal, fish, or marine mammal origin; vegetable oils, including oils from seeds, nuts, fruits, or kernels; and, other oils and greases, including petroleum, fuel oil, sludge, synthetic oils, mineral oils, oil refuse, or oil mixed with wastes other than dredged spoil.  Ursa Operating Company LLC Oil Production Facility SPCC Plan 84 in accordance with the respective location’s COGCC Form 2A conditions of approval. The approved Form 2A has been included for reference within the respective site specific plans for locations it was available for. In the event additional Form 2A documents are approved, the document shall be included within the site specific plans as soon as practical. During the field inspection, the site drainage systems such as drainage ditches, road ditches, and intermittent creeks in the vicinity of the facility are inspected for accumulations of oil. Rainwater and other precipitation that accumulates within the berm is either allowed to evaporate, infiltrate into underlying soil, or is removed using a vacuum truck. Excess rainwater removed by the vacuum truck is either returned to storage or transported for offsite disposal at a permitted non- hazardous disposal facility. No drains are present in the secondary containment structures or earthen berms. A discharge of rainwater from the secondary containment structures cannot occur unless the structure fails or is breached. Observations made by the SPCC inspector are recorded on SPCC/Containment inspection, which are stored at the Rifle Field Office and the corporate office in Denver. A copy of the SPCC/Containment inspection form is provided in Appendix D. Mechanical integrity and spill- related issues are addressed as they are identified. During the inspection, the site drainage systems such as drainage ditches, road ditches, and intermittent creeks in the vicinity of the facility are inspected for accumulations of oil. Rainwater and other precipitation that accumulates within the berm is either allowed to evaporate, infiltrate into underlying soil, or is removed using a vacuum truck. Excess rainwater removed by the vacuum truck is either returned to storage for use in storage or transported for offsite disposal at a permitted non-hazardous disposal facility. No drains are present in the secondary containment structures or earthen berms. A discharge of rainwater from the secondary containment structures cannot occur unless the structure fails or is breached. Oil accumulating within the secondary containment area is removed using absorbent pads or is removed with excess rainwater using a vacuum truck as described above. Accumulated oil is not discharged outside of the secondary containment area. Evidence of hydrocarbon spills are noted and remediated as appropriate as described in Section 2.4. Please see below for a table which provides guidance with regards to inspection and testing recommendations: Ursa Operating Company LLC Oil Production Facility SPCC Plan 85 3.3.2.a Testing and Record Keeping Guidance General Requirements Applicable to All Facilities Bulk storage with no secondary containment and for which an impracticability determination has been made 112.7(d) Test Integrity testing. Periodically. However, because there is no secondary containment, good engineering practice may suggest more frequent testing than would otherwise be scheduled. Valves and piping associated with bulk storage containers with no secondary containment and for which an impracticability determination has been made 112.7(d) Test Integrity and leak testing of valves and piping associated with containers that have no secondary containment as described in §112.7(c). Periodically. Recordkeeping requirement 112.7(e) Record Keep written procedures and a signed record of inspections and tests for a period of three years. Records kept under usual and customary business practices will suffice, for all actions. Lowermost drain and all outlets of tank car or tank truck 112.7(h)(3) Inspect Visually inspect. Prior to filling and departure of tank car or tank truck. Field-constructed aboveground container 112.7(i) Evaluate Evaluate potential for brittle fracture or other catastrophic failure. When the container undergoes a repair, alteration, reconstruction or a change in service that might affect the risk of a discharge or failure due to brittle fracture or other catastrophe, or has discharged oil or failed due to brittle fracture failure or other catastrophe. Based on the results of this evaluation, take appropriate action. Requirements for Onshore Production Facilities Diked area 112.9(b)(1) Inspect Visually inspect content. Prior to draining. You must remove accumulated oil on the rainwater and return it to storage or dispose of it in accordance with legally approved methods.    Ursa Operating Company LLC Oil Production Facility SPCC Plan 86 Requirements for Onshore Production Facilities Continued Field drainage systems, oil traps, sumps, and skimmers 112.9(b)(2) Inspect Detect accumulation of oil that may have resulted from any small discharge. Inspect at regularly scheduled intervals. You must promptly remove any accumulations of oil. Aboveground containers 112.9(c)(3) Inspect Visually inspect to assess deterioration and maintenance needs. Periodically and on a regular schedule Foundations or supports of each container that is on or above the surface of the ground 112.9(c)(3) Inspect Visually inspect to assess deterioration and maintenance needs. Periodically and on a regular schedule All aboveground valves and piping associated with transfer operations 112.9(d)(1) Inspect During the inspection, assess general condition of flange joints, valve glands and bodies, drip pans, pipe supports, pumping well polish rod stuffing boxes, bleeder and gauge valves, and other such items. Periodically and on a regular schedule. Saltwater disposal facilities 112.9(d)(2) Inspect Inspect to detect possible system upsets capable of causing a discharge. Often, particularly following a sudden change in atmospheric temperature. Flowlines 112.9(d)(3) Inspect Have a program of flowline maintenance to prevent discharges from each flowline. Each program may have its own specific and individual inspection, testing, and/or evaluation requirements and frequencies as determined by the PE. 3.3.4 Maintenance Program Ursa has a robust maintenance program aimed at eliminating releases of oil and minimizing unplanned downtime. Preventative maintenance on mechanical equipment (e.g. pumps) is completed in accordance with manufacturer recommendations to ensure proper operation. Any equipment requiring maintenance that is identified by visual inspections of the facilities are addressed by either Ursa mechanical staff or third party contractors. Equipment repairs are made in accordance with the relevant codes and industry standards. Ursa Operating Company LLC Oil Production Facility SPCC Plan 87 3.4 Response and Reporting Information   Detailed spill reporting and response procedures are provided in the Spill Prevention and Response Plan in addition to the information contained within this section. The specific response protocol utilized will depend on the size and nature of the release. 3.4.1 Spill Response The Incident Commander (IC) (Rob Bleil) and/or Alternate Incident Commander (AIC) (Tara Mall) are responsible for implementing response procedures in the event of an oil spill or discharge emergency. These personnel have the authority to commit the resources necessary to carry out a response. However, all oil handling personnel of Ursa receive training to familiarize themselves with all aspects of the SPCC Plan, facility operations, the location and characteristics of materials handled at the facility, the locations of all records within the facility; and are responsible for proper implementation of response procedures should the IC or AIC be unavailable. 1. Assess the basic situation; 2. If the incident poses an immediate threat of fire, explosion, or other impact to safety, health, or the environment, the local fire department will be contacted at 911 or relay information to dispatch via radio; 3. Call the company personnel; 4. If it is safe to enter the area and the personnel are properly trained and certified, they can protect themselves with personal protective equipment (PPE); 5. Eliminate ignition sources; 6. Restrict access; 7. Stop the source of the release if safe to do so; 8. Contain the spill if possible to safely to so with available spill response inventory items; 9. Report the release to the appropriate authorities listed in Section 8.0; 10. If the spill involves a minor amount of oil, it will be cleaned up by Bargath personnel provided that: a. They have current and appropriate HAZWOPER and applicable OSHA training; b. Appropriate Material Safety Data Sheets (MSDS sheets) are available for the material spilled; and c. Appropriate PPE is available and used. In general, recovered fluids are either returned to an uncompromised tank for storage, or transported offsite for disposal at a permitted commercial disposal facility. Hydrocarbon impacted soil is segregated onsite and is tested to assess the contamination of concern identified in the COGCC Table 910-1. Please see the flowcharts in Appendix B for streamlined spill response protocol. 3.4.2 Spill Reporting As described in the Spill Prevention and Response Plan, Emergency Response Plan and the Oil Spill Contingency Plan, the Incident Commander will be notified in the event of a release. Notification forms are provided in Appendix C. The forms will document the event concisely by identifying information that needs to be obtained. Depending on the size and environmental conditions associated with the spill, the Incident Commander may have to report the release to Ursa Operating Company LLC Oil Production Facility SPCC Plan 88 various state and federal regulatory agencies. For specific reporting information please see the Colorado and Federal Verbal Notification & Written Reporting Protocol Table located in Appendix B in addition to the Spill Prevention and Response Plan. Ursa Operating Company LLC Oil Production Facility SPCC Plan 89 3.5 Spill Response Training 3.5.1 Annual Training Ursa and its contractors provide the following minimum training to oil-handling personnel: • Operation and maintenance of equipment to prevent oil discharges; • Oil discharge procedure protocols; • Applicable oil spill prevention (State & Federal) laws, rules, and regulations; • General facility operations; and • The contents of the facility SPCC Plan. Training is conducted prior to assignment of job responsibilities and then again annually. Training includes oil spill prevention, SPCC Plan requirements, and federal and state pollution prevention and spill reporting/response requirements. 3.5.2 Discharge Prevention Briefings The facility conducts discharge prevention briefings for oil-handling personnel at least once a year to assure adequate understanding of the SPCC Plan for the facility. At a minimum, this is conducted via annual SPCC and spill response refresher training describing the contents of the SPCC regulations and plans, spill response techniques, and a review of federal and state spill reporting requirements. These briefings also include discussion of potential discharges or component failures and precautionary measures. If a spill has occurred, Ursa will also summarize the spill events and the measures implemented to prevent future releases. 3.5.3 Training Records Copies of training and discharge prevention logs can be found in Appendix D. Training records and Discharge Prevention Briefing logs are maintained for a minimum period of three (3) years at the Rifle Field Office. Each contractor organization providing oil-handling personnel maintains training records for its employees. Ursa Operating Company LLC Appendix A   APPENDIX A SITE SPECIFIC SPCC PLANS Ursa Operating Company LLC Appendix B   APPENDIX B OIL SPILL CONTINGENCY PLAN AND EMERGENCY RESPONSE PLAN Ursa Operating Company LLC Appendix B   Oil Spill Contingency Plan This Oil Spill Contingency Plan (Plan) was prepared in accordance with 40 CFR 112.7(a)(5) to address discharges of oil from the facilities covered by the Spill Prevention Control and Countermeasure (SPCC) Plan. It also addresses oil discharges from field operations where secondary containment is impracticable, per 40 CFR 112.7(d). This Plan complements the prevention and control measures presented in the SPCC Plan by defining procedures and tactics for reporting and responding to discharges of oil. The Plan is intended to protect the public and minimize damage to the environment by providing a timely, efficient, coordinated and effective action plan to respond to oil discharges. The plan is consistent with the National Oil and Hazardous Materials Pollution Contingency Plan and follows the guidelines provided in 40 CFR 109. 40 CFR 109.5 (a) Definition of the authorities, responsibilities and duties of all persons. Ursa Management is responsible for: Ensuring the necessary resources for control and cleanup are available Ensuring that personnel are adequately trained to notice, report and respond to oil discharges Ursa’s Field Superintendent (or designate), serving as the Incident Commander, is responsible for: Overall coordination of the control and cleanup of the oil discharge Committing the necessary resources (including monetary) Requesting additional assistance from outside contractors and/or the Federal authorities if necessary Ensuring repairs are made prior to putting equipment back in service Ensuring that proper notifications are made to Federal, State and Local agencies, including any follow up documentation Providing site safety plan if necessary Coordinating disposal of contaminated material Being familiar with the SPCC and Oil Spill Contingency Plans Being alert for oil discharges and responding to them as appropriate Assisting, as required, in the control and cleanup of the oil discharge 40 CFR 109.5(b) Establishment of notification procedures. Ursa owns and operates a number of oil production facilities located in Garfield County, Colorado. Personnel are trained to look for and report any oil discharge. The following is a list of emergency contact numbers. Depending on the size and nature of the oil discharge some or all of these contacts will be notified. Please refer to the flow charts and tables on the following pages for spill response and notification protocol. Ursa Operating Company LLC Appendix B   Colorado Operations I NCIDENT NOTIFICATION & MANAGEMENT PROTOCOL (H&S INCIDENTS, SPILLS, ENVIRONMENTAL/PROPERTY DAMAGE , NOVS) MAJOR INCIDENT VERBAL NOTIFICATIONS If MAJOR INCIDENT AND NO 'H&S Recorda ble In cident (Person Discovering Incident) ..... DIRECT COMMUNICATION, K EEP CALLING DOWN THE CHAIN-NO 'Repo rtabl e Spill I Incident MESSAGES or E-MAILS 'NOV w/ P ote nt ia l Fines ~ J, 'S pill Off-Pad 'Spi ll to Liv e Wate r f+ OPERATIONS PRODUCTION CONTRACTOR 'Me di a Inq uiry Po ssible 'P ropert y Damage Matt Honeycutt Shane Vaug hn ~ INCIDENT? NOTIFY 'L andowner Compl aint RES PON SIBLE ---IMMEDIATE REPORT I I CO NTRAC TOR , TO ENVS Han s W yc hgram Pake Y ounger IMMEDIATELY w w • • • H&S REG I ENVIRONMENT LAND T ara Mall Ro b Bleil Jeff Powers SAFETY/INJURIES TOP PRIORITY INCIDENT MANAGEMENT •••• DISPATCH EMERGENCY, INCIDENT & SPILL RESPONSE CREWS AP PROPRIAT E IG-- -.., H&S I FIRE I SERIOUS INJURY I VEHICLE ACCIDENTS LIFE THREATENTING? (Implement SSERP) I OSHA FIRST AID I REPORTABLE INJURY - TREAT & REPORT I NEAR MISSES-REPORT IF FUTURE RISK OF SERIOUS INJURY I LIFE THREA TENING O PERATIONS (Cell Pl'lo ne) M.Honeycutt (970) 812-2198 S.Vaughn (970) 623-9539 P.Younger (970) 260-2423 H.Wych:g~am (303) 884-9079 H&S T.Mall (970) 618-2155 I w REG I ENVIRONMENT I SPILLS I RELEASES (Implem ent Spill Response Plan) Notify Spill Coordinator I ENVIRONMENT I NATURAL RESOURCES / WILDLIFE IMPACTS (Resolve w/Ops Leads ) I NON-COMPLIANCE I FAILED AGENCY INSPECTIONS & NOVS (Resolve w /Ops Le ads) RE G I EN·V I H&S (Cell) R. Bleil (R/E) (720) 425-0303 S PILL PROGRA M L EA D K.Rowe (970) 261-2015 LAN DI PROPERTY DAMAGE PROP ERTY DAMAGE AN DOWNER MPLAINTS I ATER WELL ONCERN S IL co w c LAND RES PO RESOLVES WITH NSIBLE PARTY & AN DOWNER L LAN D (Ce ll) J. Powers (970) 309-9359 MEDIA/COMMUNITY D. Sjh1pson (281) 467-3-117 NOTE: MEDIA INQUIRIES SHOUL D BE DIRECTED TO DON SIMPSON Ursa Operating Company LLC Appendix B   In accordance with ----1 Section VI. D.2 In accordance with Section VI. G Colorado Operations SPILL RESPONSE PROCESS SPILL DISCOVERY Notify On-Site Supervisor Contain and/or contr?I spill if safe Complete Upper Shaded Section of Ursa Incident Investigation Form ~lotify Ursa Ops Lead ! Contact Spill Program Lead K. Rowe (HRL) Regulatory Agency Noti~cations Responsible Party Detemrination Contractor Ursa i i Remediation Remediation i i Waste Manaqement Waste Manaqement i ! Corrective Action I Corrective Action I Training Training i Documentation Copies Documentation to to Ursa Regulatory Agencies Proiect Closure Proiect Closure Close valves or stop/redirect ftow to prevent spill from getting larger. See Appendix B See Appendix C -Sp ill Notification Protocol COG CC LEPC I Fire Chief CDPHE In accordance with Section VI. D.1 In accordance with Section VI. G Ur s a O p e r a t i n g C o m p a n y L L C A p p e n d i x B   CO L O R A D O A N D F E D E R A L V E R B A L N O T I F C A T I O N & W R I T T E N R E P O R T I N G P R O T O C O L Ch e m i c a l Me d i a Af f e c t e d Mi n i m u m Am o u n t to R e p o r t CO G C C CD P H E BL M NRC/EPA LEPC / Fire Chief Ve r b a l Wr i t t e n Ve r b a l Wr i t t e n Ve r b a l Wr i t t e n Verbal Written Verbal Written No t i f i c a t i o n Re p o r t i n g No t i f i c a t i o n Re p o r t i n g No t i f i c a t i o n Re p o r t i n g Notification Reporting Notification Reporting E& P Su r f a c e w a t e r / Gr o u n d w a t e r An y I m m e d i a t e l y 1 0 D a y s I m m e d i a t e l y 5 Da y s I m m e d i a t e l y 1 5 d a y s I m m e d i a t e l y Upon Request Immediately Upon Request So i l - O u t s i d e Co n t a i n m e n t 1 b b l o r gr e a t e r 24 h r s In i t i a l R e p o r t - 7 2 hr s Fo r m 1 9 - 1 0 D a y s N/ A N / A 2 4 h r s 1 5 d a y s N / A N / A None Emergency E-mail Within 24 hours So i l - I n s i d e Co n t a i n m e n t 5 b b l s . o r gr e a t e r 24 h r s In i t i a l R e p o r t - 7 2 hr s Fo r m 1 9 - 1 0 D a y s N/ A N / A 2 4 h r s 1 5 d a y s N / A N / A >1 0 0 b b l s 2 4 h r s In i t i a l R e p o r t - 7 2 hr s Fo r m 1 9 - 1 0 D a y s N/ A N / A 2 4 h r s 1 5 d a y s N / A N / A No n E & P Hy d r o c a r b o n Ba s e d Su r f a c e w a t e r / Gr o u n d w a t e r An y I m m e d i a t e l y U p o n R e q u e s t I m m e d i a t e l y 5 da y s I m m e d i a t e l y 1 5 d a y s I m m e d i a t e l y Upon Request Immediately Upon Request So i l > 2 5 ga l l o n s N/ A N / A 2 4 h o u r s 5 D a y s 5 N / A 7 2 h r s N / A N / A N / A N / A > 4 2 0 g a l (1 0 b b l s . ) N/ A N / A 2 4 h r s 5 d a y s N/ A N / A N / A N / A N / A N / A > 4 , 2 0 0 ga l ( 1 0 0 bb l ) N/ A N / A 2 4 h o u r s 5 d a y s 2 4 h r s 1 5 d a y s N / A N / A N / A N / A No n E & P Ot h e r Su r f a c e w a t e r / Gr o u n d w a t e r An y N / A N / A I m m e d i a t e l y 5 d a y s 5 I m m e d i a t e l y 1 5 d a y s Upon Request Upon Request Immediately Upon Request So i l Re p o r t a b l e Qu a n t i t y (R Q ) N/ A N/ A 24 h r s 5 d a y s 5 N / A 72 h r ( e m a i l ) 15 d a y s ( N T L - 3A ) Upon Request Upon Request 72 hr email Upon Request <R Q b u t >1 0 b b l s . N/ A N / A 2 4 h r s 5 d a y s 5 N / A 72 h r ( e m a i l ) 15 d a y s ( N T L - 3A ) N/A N/A 72 hr email Upon Request <R Q b u t >1 0 0 b b l s . N/ A N / A 2 4 h r s 5 d a y s 5 2 4 hr s 1 5 d a y s N / A N / A 2 4 h r Upon Request Fo o t n o t e : 1. N o t i f i c a t i o n a n d r e p o r t i n g r e q u i r e m e n t s t h at a r e l i s t e d a b o v e a r e f o r t h e m o s t c o m m o n c h e m i c a l s e n c o u n t e r e d i n d a y t o d a y U r sa o p e r a t i o n s . 2. F o r c h e m i c a l s n o t l i s t e d , c o n s u l t t h e M S D S f o r t h e c h e m i c al o f c o n c e r n o r c a l l a n U r sa e n v i r o n m e n t a l t e a m l e a d . 3. R e p o r t a b l e q u a n t i t i e s t h a t a r e r e p o r t e d b y w e i g h t n e e d t o b e c o n v e r t e d t o a b a r r el o r g a l l o n e q u i v a l e n t f o r F e d e r a l r e p o r t i n g a n d n o t i f i c a t i o n r e q u i r e m e n t s . 4. N o t i f y t h e S t a t e H i g h w a y P a t r o l f o r t r a n s p o r t a t i on r e l a t e d s p i l l s i n v o l v i n g h a z a r d o u s m a t e r i a l s . 5. N o t i f y t h e B u r e a u o f L a n d M a n a g e m e n t f o r s p il l s o n f e d e r a l l a n d s a s a p p l i c a b l e a b o v e . Ursa Operating Company LLC Appendix B   Spill response shall be completed in accordance with the Ursa Spill Response Plan. The following pages contain phone numbers for contractors, regulatory agencies and local emergency contact entities. Water Haulers and Misc. T.D. Productions (970) 230-0704 (Terry Dick) (970) 230-0702 Dispatch (970) 984-2218 Wild Well Control Inc. (281) 353-5481 Hogback (970) 309-6322 (24/7) Redi-Vac trucks (970) 625-0233 office (970) 7561277 cell Lucas Gallegos Dalbo (970) 625-0431 office (970) 625-8659 cell Audie Williams Cascade Tanks (Mountain Water) (970) 948-7262 Mountain Valley (970) 948-7262 cell Branden Speedy (970) 985-9248 Office (970) 309-8154 Cell Tracy J&A Services (970) 434-9435 Travis Payne (970) 590-4560 Cell Travis Anderson Rain for Rent (970) 625-4600 office Well Watchers (970) 309-7313 Cell Dan Mc queen R & W BOP (970) 255-6487 Office Mountain States Pressure Control (307) 362-1903 Office Cudd Well Control (970) 858-8230 office (970) 778-5553 cell Allen Bourgeois Advanced Oil Field Services (970) 625-9704 office Flint Energy (970) 625-4265 office Calfrac – Kathleen Neault, HSE Supervisor (970) 243-7812 office (970) 985-8613 cell Frontier Drilling – James Lynch, Safety Manager (435) 503-5767 Ursa Operating Company LLC Appendix B      AGENCY CONTACT NUMBER E-Mail ADDRESS Local and State Agencies Parachute Fire Chief David Blair 970-285-9119 (o) 970-250-9851 (c) firechief@gvfpd.org 0124 Stone Quarry Rd. Parachute, CO 81635 Rifle Fire Chief Chad Harris 970-625-1243 (o) 970-379-9681 (c) Chad.Harris@crfs.us 1850 Railroad Ave. Rifle, CO 81650 Silt Fire Chief CDPHE Bob Peterson John O’Rourke 970-248-7151(Bob) 719-269-5327 (John) 1-877-518-5608 [24-hr] Robert.Peterson@dphe.state.co.us or John.Orourke@state.co.us 4300 Cherry Creek Drive South Denver, CO 80246 CDNR Assigned at call 1-800-536-5308 Assigned at time of call 1313 Sherman Street, Room 718 Denver, CO 80203 CO Dept. of Transportation Mike Verkitus 970-216-0577 Mike.Verketis@dot.state.co.us 222 South 6th St. Room 100 Grand Junction, CO 81501 COGCC Carlos Lujan (970)-625-2497 or (303) 894-2100 Carlos.Lujan@state.co.us 1120 Lincoln Street, Suite 801 Denver, CO 80203 Garfield County OEM (LEPC) Kirby Wynn (970) 945-0453 kwynn@garfield-county.com Kirby Wynn 107 8th Street Rifle, CO 80751 Garfield County Health Agency Morgan Hill (970) 625-5200 ext 8106 970-379-3826 mhill@garfield-couny.com 195 W. 14th Street Rifle, CO 81650 Pitkin County OEM Alex Burchetta or Cindy Mohat 970-920-5037 alex.burchetta@pitkinsheriff.com Cindy Mohat Emergency Management Cord. Pitkin County sheriff’s Office 506 E. Main Aspen, CO 81611 Silt Public Water Intake Jack Castle Or Gerry Pace 970-876-2353 ext 817 970-876-5444 970-876-0460 jackc@townofsilt.org 231 N. 7th Street PO Box 70 Silt, CO 81652 Rifle Public Water Intake Dick Deussen 970-665-6590 ddeussen@rifleco.org 202 W. Railroad Av. Rifle, CO 81650 Parachute Public Water Intake Mark King 970-285-7630 (office) 970-986-1821 (cell) mking@parachutecolorado.com 222 Grand Valley Way PO Box 100 Parachute, CO 81635 Federal Agencies National Response Center Assigned @ Call 1-800-424-8802 Available 24 hours HQS-DG-lst- NRCINFO@uscg.mil 2703 Martin Luther King Jr Ave. SE, STOP 7713 Washington, DC 20593-7713 US Dept. of Transportation Assigned @ Call (202) 366-4000 N/A 1200 New Jersey Avenue, SE Washington, D.C. 20590 Environmental Protection Agency Assigned @ Call (202) 272-0167 N/A Ariel Rios Building 1200 Pennsylvania Ave., NW Washington, DC 20460 Bureau of Land Management Jim Byers 970-876-9056 (o) 970-319-2532 (c) jbyers@blm.gov 2850 Youngfield Street Lakewood, CO 80215 Ursa Operating Company LLC Appendix B   40 CFR 109.5(c) Provisions to assure that full resource capability is known. All field operation personnel are familiar with the location of spill response equipment and response strategies, and with the SPCC and Oil Spill Contingency Plans. They receive annual training in the deployment of response material and handling of hazardous waste (HAZWOPER). Sufficient equipment to respond to the majority of oil discharges is kept at the Ursa Field Office and is accessible 24-hours a day to field operation personnel. This equipment is verified on a monthly basis by designated personnel and is replenished as needed. Ursa Operating Company LLC Appendix B   Identification and Inventory of Recommended Applicable Equipment 3-Cases 17” x 19” x 3/8” Oil absorbent Pads 1-Case 7” W x 15” L Oil Absorbent Pillows 1-Case 3” x 4’ Mini Booms 1-Case 3” x 8” Oil Absorbent Booms 1 5” x 10’ Oil Absorbent Boom 2-Boxes 36” x 56” 3 mil Trash Can Liners 1 Large Tyvek Coverall 1 Extra Large Tyvek Coverall 1-Bag Size 10 Green Nitrile Gloves 2 Round Point Blade Shovels 2 Square Point Blade Shovels 15 5-1/2 foot Steel Fence Posts 1 Fence Post Driver 1-Roll 16 ga Tie Wire 1-Bundle Wooden Stakes 1 Crescent 148 Piece Tool Set 6 28” Traffic Cones 2-Rolls Duct Tape 2-Rolls 6 mil 20’ x 100’ Plastic Sheeting 3 20 lb. Fire Extinguishers 1 Metal First Aid Kit 2 55 Gal. Poly Drums (Drums contain absorbent booms, pillows and pads) 1 55 Gal Steel Drum 40 CFR 109.5(d) Provisions for well-defined and specific action to be taken after discovery and notification of an oil discharge. Ursa has the primary responsibility to provide the initial response to oil discharge incidents originating from its operations. To accomplish this, Ursa has designated the Regulatory and Environmental Manager, Robert Bleil, as the qualified Incident Commander. Tara Mall will serve as the Alternate Incident Commander. In addition, Ursa maintains an Emergency Response Team, some or all of which may be mobilized depending on the size and nature of the oil discharge. Upon the discovery of an oil discharge the Incident Commander will be notified so that appropriate action can be taken. The Incident Commander has the authority to direct and coordinate response operations and may request assistance from Federal authorities as necessary. Containment and clean-up operations will be managed out of the Ursa Field Office. Operations personnel are equipped with cellular phones to assist with communications. In the event of a discharge, the first priority is to stop the product flow and to shut off all ignition sources, followed by the containment, control, and mitigation of the discharge. Specifically, the following response procedures will be implemented in accordance with the respective personnel’s level of training: Ursa Operating Company LLC Appendix B   Response Procedures Please refer to the Spill Prevention and Response Plan for a definitive guide for response procedures. A. Detection: 1. Notify the Incident Commander that an oil spill has occurred (provide location, source, amount, nearby areas of concern, etc.). 2. Shut off ignition sources (motors, electrical circuits, open flames). 3. Turn off pumping unit that charges or provides flow to the flowlines. 4. Locate the source of flowline leak. 5. Attempt to stop the source of the leak, if it can be done safely. 6. Initiate containment. B. Assessment and Notifications: 1. Investigate the discharge to assess the actual or potential threat to human health or the environment. 2. Mobilize the Emergency Response Team if necessary. 3. Request outside assistance from local emergency responders, as needed. 4. Communicate with property owners regarding the discharge and actions taken to mitigate the damage. 5. Make appropriate notifications to Federal, State, and Local agencies. C. Control and Recovery 1. Prevent the spread of oil by deploying absorbents (i.e. booms), by building diversion structures (i.e. berms), or digging temporary containment pits. 2. Direct clean-up of the oil and oil contaminated material. 3. Arrange to have soil and/or water samples analyzed per COGCC Table 910-1 standards, and/or CDPHE water standards. If contaminants are below the affected agencies allowable concentrations cleanup is complete. 4. Containerize contaminated material (soil, water, absorbent material, etc.). D. Disposal of Recovered Product and Contaminated Response Material 1. Recovered product can either be added to another tank or disposed of at an appropriate disposal site. 2. Properly characterize, label and store all contaminated material. 3. Dispose of contaminated material in accordance with all applicable solid and hazardous waste regulations using a licensed waste hauler and disposal facility. Ursa Operating Company LLC Appendix B   E. Termination 1. Arrange for necessary repairs to equipment or flowlines. 2. Review circumstances that led to the discharge and take necessary precautions to prevent a recurrence. 3. Submit any required follow-up reports to the authorities. 4. Update the SPCC and Oil Spill Contingency Plan as necessary. 40 CFR 109.5(e) Specific and Well Defined Procedures to Facilitate Recovery of Damages An Environmental Incident Report will be filled out by the Incident Commander and maintained on file at the Ursa Field Office. Any other documentation regarding the oil discharge will also be kept on file. Ursa Operating Company LLC Appendix C   APPENDIX C DISCHARGE NOTIFICATION FORMS • COGCC Form 19 Spill/Release Report • Ursa’s Environmental Incident Report • Submittal of Information to Regional Administrator for Reportable Discharge(s) Ursa Operating Company LLC Form 19   Ursa Operating Company LLC Contractor Spill/Release Report   r:;r Ursa , OPERATING •• _-..~"''"'.fir_._ COMPANY I Pad/Location: • Report Date: ---------- CONTRACTOR SPILURELEASE REPORT CONTRACTOR: ENVIRONMENTAL SPILL/RELEASE INVEST/GA Tl ON-COLORADO OPERATIONS O.i::rnrr@d: Tim~: Companv: Phon~: -------- INCIDENT TYPE RELEASE TYPE LANDS AFFECTED MEDIA AFFECTED BIOTA AFFECTED ( ) facility ( ) E&P Waste () Private ( ) Land/Soil ( ) None ( ) Transportation ( ) Non-E&P () Federal ( ) Air ( ) Plar'ltS () State ( ) Waters (U.SJ ( ) Wildlife -Game ( ) Other: ( ) Other: () On-Lease ( ) Wetland/Riperian ( ) Wildlife -T&E () Off-Lease ( ) Ground Water ( ) Wfldlife-Non-game SIGNIFICANT THREAT TO HUMANS OR ENVIRONMENT () No ( ) YES -Implement Emergency Response Plan INCIDENT DESCRIPTION (How incident occurred, type of effluent, emissions, chemical, etc.): ESTIMATED VOLUME/QUANTITY OF RELEASE: !VOLUME RECOVERED: VOLUME REMAINING FOR WASTE MGMT: RESPONSIBLE PARTY: COMPANY ENV. REP: PHONE: EMAIL: ROOT CAUSE CORRECTIVE ACTION CORRECTIVE ACTION CONFIRMED: IDATE: FINAL DISPOSITION OF WASTE (STORAGE, TREATMENT, DISPOSAL) TEMPORARY STORAGE LOCATION: FINAL DISPOSAL LOCATION: PLANS TO IMPLEMENT ADDITIONAL TRAINING (DESCRIBE) DATE: Signature (Env. Rep): Date: THIS REPORT MUST BE FILED AND SUBMITTED WITHIN 24 HOURS OF THE INCIDENT TO THE URSA SPILL COORDINATOR Ursa Operating Company LLC EPA Reportable Discharge Notification Form   Submittal of Information to Regional Administrator for Reportable Discharges In the event of a reportable discharge or discharges, this page can be utilized to provide official notification to the Regional Administrator. If the Facility has had a discharge or discharges which meet one of the following two criteria, then this report must be submitted to the Regional Administrator within 60 days. This Facility has experienced a reportable spill as referenced in 40 CFR Part 112.1(b) of 1,000 gallons or more. This Facility has experienced two (2) reportable spills (as referenced in 40 CFR Part 112.1(b) of greater than 42 gallons each within a 12-month period. Facility Name and Location: Facility contact (Name, Address, Phone Number): Facility maximum storage or handling capacity: Facility normal daily throughput: Describe the corrective action and countermeasures taken (include description of equipment repairs and replacements): Describe the Facility (maps, flow diagrams and topographical maps attached as necessary): Describe the cause of discharge(as referenced in 40 CFR Part 112.1(b)) including failure analysis of the system: Describe the preventative measures taken or contemplated to be taken to minimize the possibility of recurrence: Other pertinent information: Ursa Operating Company LLC Appendix D     APPENDIX D SPCC FORMS • SPCC/Containment Field Inspection • Personnel Training Log Ursa Operating Company LLC Appendix D       Ursa Operating Company LLC Appendix E   SPCC Training and Briefing Log Form SPCC Training/Briefing Log Trainer: Date: Subjects Discussed: Name and Signature: Please note: briefings are to take place on an annual basis at a minimum. All oil handing personnel shall be training in accordance with the criteria specified in 40 CFR 112.7(f)(1). At a minimum, training is to include: a. the operation and maintenance of equipment to prevent discharges; b. discharge procedure protocols; - (addressed during the Ursa Spill Response portion of this training) c. applicable pollution control laws, rules, and regulations; general facility operations; and, d. the contents of the facility SPCC Plan. Ursa Operating Company LLC Appendix E   APPENDIX E SUMMARY OF OPERATING PROCEDURES FLOWLINE MAINTENANCE PROGRAM Ursa Operating Company LLC Appendix E   SUMMARY OF OPERATING PROCEDURES FLOWLINE MAINTENANCE PROGRAM Before any pumper is on location, gas meters must be on and properly calibrated. The following (however not limited to) need to be checked in addition to regular pumper’s responsibility to ensure a safe and normal operation by the production operators/pumpers during their routine checks: 1. Water/oil dump valve and water flow meter malfunction: A. Physically check every separator once every day by isolation/bleed-off method. B. If there is any leak through the dump valve and if it is large, replace the trim or valve immediately, if not, try to fix the problem on site as soon as possible and plan to replace the trim/valve at the earliest opportunity. C. Monitoring SCADA for gas & water flow rate can be used in conjunction with physical check. 2. High/low setting trim troubleshooting: A. Physically check Kimray valve for leak (by listening noise, feeling temperature change on both sides of the valve and looking for frost for high differential minor leaks). B. If leak is suspected, confirm by physically checking separator by blowing separator down, then opening up to flowline to see if any gas is flowing back into separator. C. If leak is identified, replace high/low trim immediately. 3. Water/oil trim hanging open A. Physically check every separator when on a pad by listening for gas blowing through water/oil dump and visually check trim set position, then rectify problem. B. Periodically monitor separator pressures throughout day using SCADA to detect discrepancies, then rectify problem. C. Physically check by-pass valves for leaks by feeling temperature difference on both sides of valve, look for, frost or noise. D. If valves are leaking, take necessary actions and inform Ursa about its replacement. 4. Water Skid Pressures at different areas in the field A. Identify skid pressures that are higher than normal operating range on a daily basis (use best judgment) and report to Ursa. B. Purge gas from water headers to lower skid pressures. Ursa Operating Company LLC Appendix E   5. Operation of Water Network during hydraulic fracturing & flowback using the same system A. When the field lines are being utilized for hydraulic fracturing (frac) & flowback operations, the pump will be operated exclusively by the frac & flowback personnel. If you need to utilize any section of the network for pumping into injection pads or pumping out from any pad to injection pads, communicate this first to the frac/flow back personnel. For your water needs at injection pads, coordinate this with frac/flowback personnel. B. When there is no special operation, the network should be operated at regular regime. C. All operations (operation/cleaning and water pumping etc.) must be carried out with the designated personnel and appropriate controls in place. D. Finally, and most importantly, for any safety/environmental issues (e.g., spillage or leakages) immediately contact your immediate supervisor who in turn shall contact Ursa and offer your best assistance to minimize the impact from the incident to people, environment and assets. If your immediate supervisor or Ursa personnel cannot be reached, please refer to the Emergency Contacts list in Section 3.4.1 of this SPCC Plan for alternate contacts. PLEASE DO NOT LEAVE A VOICEMAIL, talk to the contact directly. *Note: All of the above situations can also be identified through manually shutting water skid off, and seeing if any gas is blowing to the production tanks Ursa Operating Company LLC Appendix E   STANDARD OPERATING PROCEDURE FOR REMOVING PRODUCTION WATER FROM TANKS 1. Pull truck onto the location 2. Inspect the location 3. Note unusual situations and report the issue to the dispatcher 4. Wear appropriate personal protective equipment: fire retardant clothing, hardhat, safety glasses and steel-toed shoes 5. Plan an escape route, park facing the exit 6. When possible park as close to the stairs as possible 7. Observe the area for additional leaks, spills, releases, equipment damage, etc. 8. Gauge the tank. 9. Watch your footing and utilize the handrail 10. Attach the bondstrap as close to the unloading operation as possible 11. Connect the hose to the tank and the truck 12. Break the seal on the tank valve and record the seal number on the field ticket 13. Place the truck pump in the vacuum position 14. Open the valve on the truck first 15. Open the valve on the tank next 16. Ensure that the vacuum on the truck is operating properly 17. Open valve on the truck slowly 18. Remove material from the tank While using the clear site glass note when oil appears or when the tank domes and close the valve on the tank 19. Open the bleeder valve (if present) on the load line 20. Pull material from the hose into the truck 21. If the truck is too full, then push some of the material back into the tank so that the hose can be effectively drained 22. Shut off the pump 23. Gauge the tank again 24. Record the amount of material withdrawn from the tank and document results on field ticket 25. Install new seal on the tank valve 26. Record the new seal number on the field ticket 27. Disconnect the hose from the tank 28. Disconnect the hose from the truck 29. Collect remaining fluids in 5 gallon bucket 30. Inspect the hose, fittings and piping for damage 31. Properly place the hose in trays and secure all fittings 32. Replace the dust caps on the back of the truck valves 33. Remove the bondstrap 34. Leave copy of the field ticket for the pumper 35. Again, note any unusual occurrences 36. Leave location and drive to disposal site Ursa Operating Company LLC Appendix E   STANDARD OPERATING PROCEDURE FOR PRODUCED FLUID TRANSFERS TO TANKS 1. Initial Tank Inspection – Valves and Overflow (Gooseneck) Caps A. Prior to any fluid transfers, the water handling contractor will perform an initial inspection of the tanks to confirm that all valves on tanks are closed and that the overflows (gooseneck) have caps. B. Initial inspection includes the valve which is located at the back of the tank in front of the wheel axles. C. All man hatches will be inspected to confirm that they are tight. 2. Initial Tank Inspection to Confirm Tank Fluid Levels A. Prior to any fluid transfers, identify the full tanks and the empty tanks. B. Tanks with closed thief hatches located at the top of the stairs are considered full. These tanks can’t accept produced fluids. All tanks with produced water should have a closed thief hatch with a carbon blanket installed. C. Fluid Gauges Don’t Work – Check tank status prior to pumping or transferring fluids. D. Make sure that your tank has room before you begin unloading! 3. Visu A. al Tank Inspection after Fluid Transfer Begins Visually check each tank for leaks (valves, overflow/gooseneck caps) immediately after tank filling begins. B. Continue watching the tank until your truck is completely unloaded. C. Tank fluid transfers are immediately stopped if a leak is found or tank is overfilled. 4. Spill Reporting and Cleanup A. If a spill occurs the contractor/driver will contact their immediate supervisor. B. Contractor will stop all fluid transfers during a spill event. C. Truck driver will reverse his pump and begin vacuuming up the free liquids that spilled if transfer by truck. 5. Final Inspection after Fluid Transfer is Completed A. Confirm that tank flex hose is drained of fluids prior to disconnecting the hose from the tanks – Do Not Drain Liquids on the Ground. B. For pipeline fluid transfers, flex hoses must be left connected to the manifold in front of the frac tanks – Flex hoses should not be disconnected. C. Contractor will close the tank thief hatches on the tanks that are full to prevent overfilling. Ursa Operating Company LLC Appendix E   FLOWLINE MAINTENANCE PROGRAM Flowlines and piping at production facilities can be sources of releases. The quantity and rates of such events will vary according to failure mode, operating pressures, current production rates, and duration of the release. Flowlines and intra-facility gathering lines and associated valves and equipment are compatible with the type of production fluids, their potential corrosivity, volume and pressure, and other conditions expected in the operational environment. The majority of the piping in the field is constructed of steel and was installed in 2009 or later. Flowlines are powder coated and/or painted. The steel lines all have cathodic protection. The pressure lines operate between 0 to 600 pounds per square inch (psig), they were designed for 0 to 1440 psig. Flowline construction materials are corrosion resistant to condensate, crude oil, and produced water. Flowlines are sized appropriately for the flow volumes expected at the facility. Aboveground flowlines and associated appurtenances are visually inspected daily during the pumper’s regularly scheduled site visits for leaks, oil discharges, corrosion, or other conditions that could lead to a discharge as described in 40 CFR 112.1(b). Inspection of conditions associated with buried flowlines is accomplished by observing the ground surface above the lines for evidence of leaks on a monthly basis. Records of the inspections are stored at the Rifle Field Office and the corporate office in Denver. Buried flowlines are also inspected whenever they are exposed. Metallic lines have a cathodic protection system which is monitored once or twice a year as deemed necessary. High density polyethylene (HDPE) lines are operated at or below the recommended pressure and pressure tested on a regular basis to check their integrity. The aboveground manifolds are inspected on a monthly basis for conditions, repair, painting, etc. Appropriate corrective actions or repairs are made to any flowline, intra-facility gathering line, or associated appurtenances if evidence of a discharge is present. Evidence of a discharge includes product that has surfaced above the flowline. Suspected releases, including significant loss of pressure in the line or significant reduction in product recovered in the production tanks will be investigated. In the event a leak is discovered, the lines will be replaced with pipe constructed of appropriate materials. All repaired or replaced flowlines are pressure tested prior to being put into operation. Actions are initiated promptly to stabilize and remediate any accumulations of oil discharges associated with flowlines, intra-facility gathering lines, and associated appurtenances. Ursa Operating Company LLC Appendix E   Releases are reported to the appropriate supervisor and cleanup personnel upon discovery. Oil and impacted media are removed or remediated as soon as practicable. Ursa Operating Company LLC Appendix F   APPENDIX F WRITTEN COMMITMENT OF MANPOWER   Written Commitment of Manpower, Equipment, and Materials In addition to implementing the preventive measures described in this Plan, Ursa will also specifically: • In the event of a discharge: 1. Make available all trained personnel and contractors to perform response actions ii. Collaborate fully with local, state, and federal authorities on response and cleanup operations • Maintain on-site oil spill control equipment. • Maintain all communications equipment in operating condition at all times. • Ensure that facilities are accessible. • Review the adequacy of on-site and third-party response capacity with pre- established response/cleanup contractors on an annual basis and update response/cleanup contractor list as necessary. • Maintain formal agreements/contracts with response and cleanup contractors who will provide assistance in responding to an oil discharge and/or completing cleanup. Rob Bleil, Regulatory and Environmental Manager N a m e a n d T i t l e : S i g n a t u r e : ______________ Date: Ursa Operating Company LLC Attachment 1 ATTACHMENT 1 ONSHORE ORDER 3 Ursa Operating Company LLC Attachment 1 I Contents 1.0 Introduction ..................................................................................................................................... 1 Table 1. Well pads which are subject to the requirements of Onshore Order 3 ........................................ 1 Table 2. Specific wells which are subject to the requirements of Onshore Order 3 . Error! Bookmark not defined. 2.0 Definitions ........................................................................................................................................ 2 3.0 Record Keeping Requirements ...................................................................................................... 6 4.0 Seal Requirements .......................................................................................................................... 6 Figure 1. An effectively sealed valve cannot be turned without breaking the seal. .................................. 6 Figure 2. An ineffectively sealed valve, the wheel nut can be taken off and thus product removed. ....... 7 Figure 3. The yellow tag is a federal seal and is a designator of a violation. ........................................... 7 Table 3. Non-LACT System Seal Requirements ...................................................................................... 8 Table 4. LACT System Seal Requirements .............................................................................................. 9 5.0 Site Diagram Requirements ......................................................................................................... 10 Figure 4. Example diagram and valve documentation ............................................................................ 11 Figure 5. Example diagram of a LACT Unit .......................................................................................... 12 6.0 Site Security Inspection Requirements ....................................................................................... 13 Site Security Inspection Form ................................................................................................................. 14 7.0 Seal Tracking Requirements ........................................................................................................ 17 Seal Tracking Form .............................................................................................................................. 18 8.0 Operator and Federal Contact Information ............................................................................... 19 Table 5. Contact Information .............................................................................................................. 19 9.0 Removal of Oil Requirements ...................................................................................................... 20 Removal of Oil Form ............................................................................................................................ 21 10.0 Theft or Mishandling of Oil Protocol .......................................................................................... 22 10.1 Internal Notification Protocol ..................................................................................................... 22 10.2 Federal Notification Requirements: ............................................................................................ 22 Theft of Mishandling of Oil Form .......................................................................................................... 23 11.0 Site Security Plan ............................................................................................................................ 24 Notification to Authorized Representative Form .................................................................................... 25 Ursa Operating Company LLC Attachment 1 1 1.0 Introduction Onshore Order 3 establishes minimum standards for site security with regards to measurement and sales of condensate and/or crude oil for facilities located on all Federal and Indian (except Osage) oil and gas leases. In addition, this regulation is applicable to all wells and facilities on State or privately-owned mineral lands committed to a unit or communitization agreement that affects Federal or Indian interests, notwithstanding any provision of a unit or communitization agreement to the contrary. The following sections of this attachment will provide the basic requirements for ensuring Ursa’s operations remain compliant with the respective regulation. This Order establishes the minimum standards for site security by providing a system for production accountability and covers the use of seals, by-passes around meters, self-inspection, transporters' documentation, reporting of incidents of unauthorized removal or mishandling of oil and condensate, facility diagrams, recordkeeping, and site security plans. Please see Table 1 and 2 of this document for a list of well pads and specific wells which are subject to the regulation. It should be noted that this list will serve as a living document and should be updated when there is a sale or acquisition as applicable. Please note that the BLM is responsible for compliance of Onshore Order 3 if a facility is located on federal land. The BLM and USFS may coordinate efforts when a facility is located on USFS surface land, but the BLM will retain responsibility per BLM Memorandum of Understanding WO300-2006- 07. In order to ensure Ursa remains compliant with Onshore Order 3, personnel involved with oil gauging, loading, and sales should be presented and trained with the required protocol per the regulation. The two most important aspects to retain compliance are proper documentation and ensuring valves are sealed effectively. Ursa Operating Company LLC Attachment 1 1 Table 1. Well pads which are subject to the requirements of Onshore Order 3 1 Pad Name Latitude Longitude Surface Owner Surface Ownership Subsurface Ownership Buckle A Pad 39.525281 -107.670354 BLM Federal Federal Castle Springs A 39.456148 -107.594131 BLM Federal Federal Castle Springs V 39.456172 -107.597724 BLM Federal Federal Castle Springs U 39.463162 -107.599134 BLM Federal Federal Castle Springs T 39.463931 -107.583039 BLM Federal Federal Castle Springs B 39.455007 -107.578976 BLM Federal Federal Castle Springs E 39.458503 -107.559033 BLM Federal Federal Castle Springs D 39.454576 -107.566292 BLM Federal Federal Castle Springs W 39.460108 -107.541391 BLM Federal Federal Castle Springs Q 39.456285 -107.535999 BLM Federal Federal LBCF Pad 39.355612 -107.473103 USFS Federal Federal Dixon Federal B 39.524078 -107.659557 BLM Federal Federal Federal PA 39.447184 -107.942184 BLM Federal Federal 1 This list is to serve as a living document and is to be updated as facilities are constructed or decommissioned. Ursa Operating Company LLC Attachment 1 2 2.0 Definitions Becoming familiar with the below terminology will help ensure that the regulatory requirements are fulfilled with regards to Onshore Order 3. Authorized Officer – means any employee of the Bureau of Land Management (BLM) authorized to perform the duties in Groups 3000 and 3100 of this title [43 CFR 3000.0-5(e)]. Authorized Representative – means any entity or individual authorized by the Secretary to perform duties by cooperative agreement, delegation, or contract (see 43 CFR 3160.0-5). Business Day – means any day Monday through Friday, excluding Federal holidays. By-Pass – means any piping arrangement connected upstream and downstream of a meter which allows oil or gas to continue on to the sales line without passing through the meter. Equipment which permits the changing of the orifice place without bleeding the pressure off the gas meter run shall not be considered a by-pass. Effectively Sealed – means the placement of a seal in such a manner that the position of the sealed valve may not be altered, or a component in a measuring system affecting quality or quantity accessed, without the seal being destroyed. Major Violation – means noncompliance which causes or threaten immediate, substantial, and adverse impacts on public health and safety, the environment, production accountability, or royalty income. Oil – means all nongaseous hydrocarbon substances, other than those substances leasable as cole, oil shale or “gilsonite”. Production Phase – means that period of time or mode of operating during which crude oil is delivered directly to or through production vessels to the storage facilities and includes all operations at the facility other than those defined by the sales phase. Please note that unless the oil is salable, the operator is not required to maintain records of the loading/unloading and seals. If the oil (i.e. condensate) accumulated within the produced water tanks becomes salable, all requirements for documentation and record keeping will apply. Sales Phase – means that period of time or mode of operation during which crude oil is removed from the storage facility for sale, transportation, or other purposes. Seal – means a device, uniquely numbered which completely secures either a valve of those components of a measuring system that affect the quality and/or quantity of the liquid measured. Ursa Operating Company LLC Attachment 1 6 3.0 Record Keeping Requirements All documents and records shall be filed for a period of seven years. The respective hardcopy records shall be stored at the Rifle Field Office and shall be managed by designated Ursa personnel as defined in Section 8.0 of this document. In the event an acquisition is made and no records are available, a document stating such shall be drafted and filed for the respective location. 4.0 Seal Requirements Specified equipment components will be required to have a seal as defined in Section 2.0 of this document. The seals will be placed and removed by designated personnel at the time of sale, or during a change in the position the respective valve is kept (i.e., open or closed). Anytime a seal is changed, it shall be documented in the applicable forms included within this document. Each ineffectively sealed valve or appropriate valve not sealed shall be considered a separate violation. Violation fines range from $250 to $500 per violation. In the event an authorized representative identifies the unsealed valve, he or shall place a federal seal on the valve and notify the operator. Fines for theft of materials (and/or lack of royalty payments) are much greater. The seal record (Section 7.0) serves as the operators defense against such fines in the case that a theft does occur. Please see the below figures for examples of seals 2 : Figure 1. An effectively sealed valve cannot be turned without breaking the seal. 2 Figures taken from BLM Bakersfield Training document. Ursa Operating Company LLC Attachment 1 7 Figure 2. An ineffectively sealed valve, the wheel nut can be taken off and thus product removed. Figure 3. The yellow tag is a federal seal and is a designator of a violation. Ursa Operating Company LLC Attachment 1 8 The following Tables (3 and 4) provide guidance with regards to the equipment which is subject to the seal requirements. Any exceptions or additional guidance is included in the right hand column. Table 3. Non-LACT System Seal Requirements EQUIPMENT REQUIRING SEAL EXCEPTIONS, NOTES NON-LACT SYSTEMS Sales Valves The valves shall be effectively sealed during the production and sales phases or combination of sales phases. Circulating Valves Drain Valves Fill Valves Equalizer Valves Any valve which provides access to oil prior to measurement for sales. All lines entering or leaving oil storage tanks Exempt: Valves on production vessels (e.g. gun barrel, wash tanks) Exempt: Valves on produced water tanks, provided access does not exist through a circulating drain or equalization system to production and sales tanks Exempt: Sample cock valves with piping of 1 inch or less in diameter Exempt: When a single tank is used for collecting small volumes of condensate, all other requirements apply. Exempt: Gas line valves of 1 inch or less used as tank bottom "roll" lines, provided there is no access to the contents of the storage tank and said lines cannot be used as equalizer lines. Exempt: Tank heating systems which use a fluid other than the contents of the storage tanks. Exempt: Tank vent fill valves The above seal requirements will be applicable to most well pads to a certain degree. The seal requirements for the LACT units are specified in Table 4 on the following page. The LACT Units are a much less common facility. Ursa Operating Company LLC Attachment 1 9 Table 4. LACT System Seal Requirements LACT SYSTEM SEAL REQUIREMENTS LACT systems Sales or equalizer lines do not need to be sealed. However, any valves which allow access for the removal of oil prior to measurement through the LACT system shall be sealed. There shall be no bypass around the LACT unit. Sample Probe None Sampler Volume Control None All valves entering or leaving the sample container excluding the safety pop-off valve Meter Assembly, including the counter head, meter head and automatic temperature compensator None Temperature recorder None Back pressure valve downstream of the meter None Any drain valve in the system None Manual sampling valves None Ursa Operating Company LLC Attachment 1 10 5.0 Site Diagram Requirements • Accurately reflects the relative position of the production equipment, piping and metering systems - does not need to be to scale. • Commencing with the header, identify the vessels, piping, and metering systems located on the site and shall include the appropriate valves and any other equipment used in the handling, conditioning, and disposal of oil. gas, and water produced, including any water disposal pits or emergency pits. In those instances where pits are co-located, such pits may be shown in parentheses on the facility diagram. • Indicate which valve(s) shall be sealed and in what position during the production and sales phases and during the conduct of other production activities, i.e., circulating tanks, drawing off water, which may be shown by an attachment, if necessary. • Require as an addition. when describing co-located facilities operated by 2 different operators, a skeleton diagram of the co-located facility, showing only equipment. For co-located common storage facilities operated by 1 operator, one facility diagram shall be sufficient. • Be filed within 60 days of completion of construction of a new facility or when existing facilities are modified or when a non-Federal facility is included in a Federally supervised unit agreement or communitization agreement. • Clearly identify the lease to which it applies and the location of the facility covered by quarter section, section, township, and range or by a legal land description, with co-located facilities being identified by each lease and its facilities. • Clearly identify the site security plan covering the facility. Ursa Operating Company LLC Attachment 1 11 Figure 4. Example diagram and valve documentation Facility Name: Location (legal or lat/long): Lease #: General sealing of valves, sales by tank gauging Valve ID Production Phase Sales Phase (e.g. from S/T 1) Other Phase (e.g. draining from S/T 1) Fill Valves F1 - F4 Not Sealed F1 Sealed F2 - F4 Not Sealed F1 Sealed F2 - F4 Not Sealed Equalizer Valves E1 – E4 Not Sealed E1 Sealed E2 - E4 Not Sealed E1 Sealed E2 - E4 Not Sealed Sales Valves S1 – S4 Sealed S1 Not Sealed S2 - S4 Sealed Sealed Drain Valves D1 – D4 Sealed Sealed D1 Not Sealed D2 - D4 Sealed Ursa Operating Company LLC Attachment 1 12 Figure 5. Example diagram of a LACT Unit Ursa Operating Company LLC Attachment 1 13 6.0 Site Security Inspection Requirements Ursa shall establish an inspection program for the purpose of spot checking their facilities with regards to compliance with Onshore Order 3 requirements. One location a month shall be inspected with the form included in this Section and cross referenced with the seal tracking form (Section 7.0) to verify the information. Any information which does not cross reference properly will be flagged and investigated. Pending the results of the investigation, notification may be provided to an authorized representative and will be documented and filed for later reference. Ursa Operating Company LLC Attachment 1 14 Site Security Inspection Form Facility Name: Location (legal or lat/long): Current Operations Phase (production, sales, other): Date of Inspection: Lease #: Inspected By: This inspection should be completed “as-needed” by qualified personnel. Any item marked “No” requires additional description and/or reference to operations phase on Site Facility Diagram (Attachment A). Section III.A - Seals Valve Identification Number Is the valve sealed and closed? SEAL NUMBER Notes Yes No Ursa Operating Company LLC Attachment 1 15 Section III.B – LACT Seals (if present on site) See Attachment B for Meter Diagram Yes No SEAL NUMBER Notes Sample probe closed and sealed? Sampler volume control closed and sealed? Valves on entry/exit lines closed and sealed? Temperature recorder closed and sealed? Back pressure valve closed and sealed? Drain valve(s) closed and sealed? Manual sampling valve(s) closed and sealed? Meter assembly (counter head, meter head, automatic temperature compensator) closed and sealed? Section III.D – Meter By-Pass Yes No N/A Notes Gas meters and/or LACT meters free of by-pass piping installations? Section III.H – Site Security Site Specific Security Yes No N/A Notes Ursa Operating Company LLC Attachment 1 16 Additional Inspection Comments: In the case of any evidence of theft or mishandling (missing or broken seals, valves in incorrect positions, by-passes installed), report to Ursa Operating Company IMMEDIATELY after completing this inspection. Printed Name: _______________________________________ Signature: _______________________________________ Ursa Operating Company LLC Attachment 1 17 7.0 Seal Tracking Requirements To ensure compliance with Onshore Order 3, and to provide a document which tracks all seal installations and removals, a seal tracking form has been provided within this Section. The form shall be completed at the time of the oil loading operation by the Ursa personnel providing oversight of the loading operation. A designated form for each field shall be managed in accordance by the designated Ursa personnel in both hardcopy and electronic form. The personnel managing the seal tracking form shall conduct the monthly site inspections and cross reference the seal tracking form with the respective site inspection. Ursa Operating Company LLC Attachment 1 18 Seal Tracking Form Facility Name: Lease Number Tank Id Number Valve ID Date of Seal Installation/Removal Removed Seal Number Installed Seal Number Reason for Removal/Installation Notification to the Authorized Officer - (Y/N and Date) Ursa Operating Company LLC Attachment 1 19 8.0 Operator and Federal Contact Information Table 5. Contact Information Ursa Contact List Field Contacts Mobile Office Email Battlement Mesa Shane Vaughn (970) 623-9539 (970) 329-4371 svaughn@ursaresources.com Castle Springs/Wolf Creek Same Same Same Same Gravel Trend Same Same Same Same Roan/North Gravel Trench Same Same Same Same Regulatory and Environmental Robert Bleil (720) 425-0303 (970) 329-4373 rbleil@ursaresources.com HS&E Tara Mall (970) 618-2155 (970) 329-4375 tmall@ursaresources.com Federal Contact List* Colorado River Valley Field Office, 2300 River Frontage Road, Silt, CO 81652 Julie J. King 970-876-9036 970-876-9000 jjking@blm.gov * Only notify the BLM field office which the respective facility is found in. Ursa Operating Company LLC Attachment 1 20 9.0 Removal of Oil Requirements The removal of oil from a facility for sale or transport must be documented and observed by specified persons (i.e. gauger, Ursa representative, BLM personnel). A form has been provided in this Section to fulfill the documentation requirement. Prior to removal of oil from tanks, a verbal notification to the respective BLM personnel is required. The authorized officer or representative from the BLM is to be present at the time of loading. The BLM personnel may collect independent gauging measurements. Their presence is to provide oversight during the gauging process to verify the volume of oil being loading and documented is accurate for royalty purposes. Ursa Operating Company LLC Attachment 1 21 Removal of Oil Form Removal of Oil From Tanks be Means Other Than Through a LACT Unit Date: Name of seller: Ursa Operating Company, LLC Federal or Indian lease number: Legal location of the tank: Tank number and capacity: Valve Number Seal number prior to loading*: Seal number after loading: Opening gauge and temperature*: Closing gauge and temperature*: Observed gravity and sediment and water content*: Name of Gauger: Signature of Gauger: Name of Ursa representative: Signature of Ursa representative: Name of Federal representative: Signature of Federal representative: * Omission of the designated information constitutes a major violation, complete missing information and submit within 3 days of notice. Ursa Operating Company LLC Attachment 1 22 10.0 Theft or Mishandling of Oil Protocol 10.1 Internal Notification Protocol • Personnel identifying the incident will report all applicable information to the Regulatory and Environmental Manger (REM) in addition to the Health and Safety Manager (H&S). • In the event of criminal activity, law enforcement may be involved. The REM and/or H&S will determine the involvement of law enforcement. • The form included in this section shall be completed within 10 days of discovery of the incident. o Any additional information not identified within the form is to be attached. o All forms shall be retained for a period of seven years in accordance with the regulatory requirements. 10.2 Federal Notification Requirements: • The theft of mishandling of oil shall be reported no later than the next business day after discovery of the incident to the authorizing officer. • All oral reports shall be followed up with a written report within 10 business days. o Please see the form within this Section for the written report form. • Violations: o Minor  e.g. failure to file a complete report  corrective action: oral report upon request, and submit report of incident within 10 business days after notice of failure to file a complete report is received. o Major  e.g. failure to report the incident  corrective action: oral report upon request and submit report of incident within 10 business days after notice of failure to report incident is received. Ursa Operating Company LLC Attachment 1 23 Theft of Mishandling of Oil Form Theft or Mishandling of Oil Verbal notification required: next business day after incident is discovered Written notification required: 10 days after incident is discovered Date: Name of seller: Ursa Operating Company, LLC Name of Ursa representative reporting the incident: Name of the person who discovered the incident and company: Date and time the incident was discovered: Federal or Indian lease number: Legal location of the tank: Tank number and capacity: Estimated volume oil or condensate removed: The manner which access to the oil was removed: The way access was obtained: Whether the incident was reported to local law enforcement agencies and company security: Signature of Ursa representative: Ursa Operating Company LLC Attachment 1 24 11.0 Site Security Plan The operator shall establish a site security plan for all facilities. The plan need not be submitted to the authorized officer, but the authorized officer shall be notified of the location where the plan is maintained and the normal working hours of said location. The plan shall be available to the authorized officer upon request. The plan shall include, but is not limited to the following: • A self-inspection program that monitors production volumes and ensures compliance with all seal requirements at each storage and sale facility and each LACT unit, if applicable o See form found in Section 6.0 • A system to ensure the maintenance of accurate seal records and the completion of accurate run tickets o See forms found in Sections 7.0 and 8.0 • A system to ensure the reporting of incidents of apparent theft or mishandling of oil o See form in Section 9.0 • A system to ensure that there are no by-pass of meters o See form in Section 6.0 • A list of the leases, communitization agreements, unit agreements, and specific facilities that are subject to each plan o See Tables 1 and 2 of this document. • Documentation that the authorized officer has been notified of the completion of a plan and site facility diagram(s) and the leases, communication agreements, unit agreements, and specific facilities that are subject to each plan and diagram(s) Documentation that the authorized officer was notified within 60 days of completion of construction of a new facility or of commencement of first production or of inclusion of the production from a committed nonfederal well into a federally supervised unit or communitization agreement, whichever occurs first, whether that facility is covered by a specific existing plan or a new plan has been prepared. o See Form in Section 11.0 of this document. Ursa Operating Company LLC Attachment 1 25 Notification to Authorized Representative Form Notification to Authorized Representative Name and Title of Ursa Representative Providing Notification: Federal Field Office Notification Provided to: Reason for Notification: X Notes: Completion of a Plan Completion of a Site Diagram Lease addition of change Communication Agreement Unit Agreement Providing list of locations with are subject to the Order Fill in the following information as applicable to the Notification: Date of construction completion: Date of commencement of first production: Date of inclusion of production from a committed nonfederal well into a federally supervised communitization agreement: Was this notification provided within 60 days of completion of construction, or of commencement of first production, or of inclusion of the production from a committed nonfederal well into a federally supervised communitization agreement? Yes No If no, why: ___________________________________ __________________________________________ Ursa Representative Signature: Date: Supplemental information to be attached to this form as an attachment(s). Article 4-203.G Impact Analysis Ursa Operating Company LLC Watson Ranch B Injection Well OA Project No. 014-3005 760 Horizon Road, Suite 102 TEL 970.263.7800 Grand Junction, CO 81506 FAX 970.263.7456 www.olssonassociates.com Article 4 – Impact Analysis Ursa Operating Company LLC Watson Ranch B Injection Well SECTION 4-203.G. IMPACT ANALYSIS 1. Adjacent Land Use The adjacent uses within a 1500 foot radius of the site primarily consist of agricultural activities, natural gas extraction, public lands, and open space for a PUD (see Adjacent Uses Map). The proposed use is consistent with existing uses in the surrounding area. These uses will not be adversely impacted by construction and operation of the injection well as it will be drilled on an existing natural gas well pad. There are rural zone district residences to the west and south of the proposed injection well. 2. Site Features The site is located on private lands located approximately 1.5 miles south of Battlement Mesa, Colorado, off of County Road (CR) 303 (Gardner Lane) in the SE ¼ of the SW ¼ of Section 17, Township 7 South, Range 95 West of the 6th P.M. Access to the site is via the access road for Watson Ranch A off of CR 303. The project site encompasses approximately 6.43 acres at an elevation of 5,560 feet. It will be located on a Colorado Oil and Gas Conservation Commission (COGCC) approved natural gas well pad. No major 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. Native vegetation surrounding the site is consistent with sagebrush communities and pinyon-juniper woodlands that occur in the Colorado River valley corridor. Vegetation is dominated by a mixture of mountain big sagebrush, Gambel oak, and pinyon-juniper. A variety of grasses and forbs are distributed throughout the understory. A few common species include various wheatgrass species, bluegrass, dandelion, and prickly pear. No significant natural features are located in close proximity to the project area. As a result of applying engineering design criteria, detailed in the accompanying drawings, implementation of stormwater best management practices (BMPs), and Ursa’s industry BMPs, the facility will not affect the surrounding vegetation and water resources. Ursa Operating Company Watson Ranch B Injection Well Impact Analysis Page 2 3. Soil Characteristics The Natural Resources Conservation Service (NRCS) Soils Map shows the area soil types. Soils consisting of the following units are within the study area around Watson Ranch B UIC well:  Potts loam 6% to 12% slopes, Map Symbol 56: The Potts loam soil is a deep, well drained, moderate sloping to rolling soil formed on mesas and the sides of valleys at elevations between 5,000 feet to 7,000 feet above mean sea level. Typically the surface layer is a brown loam about four inches thick and the subsoil is a reddish brown clay loam to a depth of 24 inches, and the substratum is a pinkish white loam to a depth of 60 inches. Permeability is very slow, and available water capacity is high. Surface runoff is medium, and the erosion hazard is severe.  Potts-Ildefonso complex, 12% to 25% slopes, Map Symbol 58: The Potts-Ildefonso complex is located along a drainage on the northeast side of the site. The Potts- Ildefonso complex soil is a deep, well drained, sloping soil formed on fans and high terraces at elevations between 5,100 feet and 6,200 feet above mean sea level. Typically the surface layer is a moderately alkaline, pale brown loam about three inches thick and the substratum is light brown to brown silty clay loam to a depth of 60 inches. Permeability is very slow, and available water capacity is high. Surface runoff is moderately rapid, and the erosion hazard for the Potts Ildefonso complex soils is moderate. The Potts loam soil makes up approximately 80% of the unit, and the Potts-Ildefonso complex soil makes about 20% of the unit. 4. Geology and Hazard The Watson Ranch B UIC well pad site is located in the southeastern part of the Piceance Basin. The Piceance Basin is an irregularly-shaped elongated basin formed by tectonic forces associated with the Laramide orogeny. These forces down warped the earth’s crust and formed the Piceance Basin as a result of the uplift of the surrounding Colorado Rocky Mountains and the Colorado Plateau. The Piceance Basin is the major structural geologic feature in the region. It is bound to the east by the Grand Hogback monocline, the White River Uplift to the northeast, the Gunnison Uplift to the south, the Uncompahgre Uplift to the south and southwest, the Douglas Creek Arch to the west-northwest, and the axial basin uplift to the north (Grout and Verbeek, 1992). Sedimentary rocks in the southwestern Piceance Basin gently dip to the north – northeast except where this regional dip is interrupted by low-amplitude folds. Numerous small subparallel northwest trending folds have been identified in the Green River Formation within the basin. There are no mapped faults shown in the area of the site on the Geologic and Structure Map of the Grand Junction Quadrangle, Garfield County, Colorado or on the Preliminary Geologic Map of the Grand Valley Quadrangle, Garfield County, Colorado. Ursa Operating Company Watson Ranch B Injection Well Impact Analysis Page 3 5. Groundwater and Aquifer Recharge Areas The site is located at an elevation of approximately 5,560 feet amsl on a terrace above the Colorado River flood plain. The Colorado River is located approximately 1.3 miles to the northwest at an elevation of approximately 5,150 feet amsl. There are several unnamed intermittent drainages located near the site, the closest is approximately 130 feet to the north of the site that drains to the Colorado River. The Watson Ranch B Site is located approximately 1,930 feet to the northeast of the confluence of Monument Gulch and Stone Quarry Gulch. There are two unnamed intermittent drainages located in proximity to the site. One of the intermittent drainages is located on the northwest corner of the Site, and the other is approximately 150 feet to the south of the Site. The Wasatch Formation locally yields water to wells in some areas, but is generally considered a confining unit. The Tertiary sedimentary rocks in the Piceance Basin are generally fine-grained and well cemented resulting in very small hydraulic conductivity in the rock matrix. Sandstone and siltstone generally occur in lenticular bodies and locally have moderate hydraulic conductivities which range from 0.001 to 0.01 foot per day. These lenses of sandstone and siltstone are often widely spaced and not interconnected which further limits the volumes of groundwater the formation can yield to wells. In some areas, fracturing during the structural deformation that occurred when the Piceance Basin was uplifted and through dissolution of cementing minerals has enhanced the permeability and hydraulic conductivity in parts of the Piceance Basin aquifer system. Water well depths in the area range from 120 feet to 180 feet below ground surface in the vicinity of the site. The water wells in the SE ¼ SW ¼ have total depths of 140 feet to 145 feet below ground surface (bgs) and static water levels that range from 64 feet to 111 feet bgs. Groundwater within the unconsolidated sediments in the area of the proposed site is controlled by the thickness of the sediments and the depth to the top of the Wasatch bedrock. The estimated groundwater flow direction in the vicinity of the site is likely to be sub-parallel with the Colorado River, flowing north-northwest toward the Colorado River. The proposed injection well will be utilized to dispose of water from Ursa’s operations in the Battlement Mesa area. The proposed well will be permitted and approved for operation by the Colorado Oil and Gas Conservation Commission (COGCC). The COGCC review process is intended to address any issues related to potential impacts to groundwater . This well will be operated in strict accordance with COGCC regulations and the approved permit criteria and Conditions of Approval. Environmentally sound and safe operation of the proposed injection well is assured with the implementation of the following leak detection and emergency controls:  Bradenhead Pressure Alarm: monitors surface casing pressure;  Wireless Casing Pressure Monitor/Transmitter: monitors casing pressure;  Wireless Tubing Pressure Monitor/Transmitter: monitors tubing pressure; and  Remote Shut Down Controls: the injection well is equipped with a standalone remote telemetry (shutdown) unit that would allow the injection well to continue to operate (but Ursa Operating Company Watson Ranch B Injection Well Impact Analysis Page 4 shut down if any alarms or operational issues occur) in the event that the operator loses contact with the injection well; it is solar powered and has a backup battery power supply. Each control is designed to notify the operator regarding any issues with the injection well, and the controls have the capability to remotely shut down the well, without operator assistance. In addition to the injection well controls listed above, Ursa will have additional controls, which consist of:  Filter Pod Pressure Alarms: monitors filters and notifies operator when to replace filter;  Pump(s) supporting the injection well are equipped with Programmable Logic Controls, which monitors the pump package and pressures; and  The pump(s) are also equipped with Low Oil Level Alarms and monitor flow rates, including the maximum daily pressure/volume (as set by the COGCC). The facility will be covered under a site-specific Spill Prevention Control and Countermeasures plan (SPCC) and Colorado Department of Health and Environment (CDPHE) construction stormwater management plans and COGCC post-construction stormwater management plans (see appropriate sections included in this submittal). 6. Environmental Impacts See the Impact Analysis: Section 4-203-G (8) Environmental Impacts Report prepared by WestWater Engineering and the Geologic Hazard Report prepared by Olsson Associates for a full analyses of the Environmental Impacts. The project area was evaluated for threatened, endangered, or sensitive wildlife and plant species listed in Garfield County. Designated critical habitat for two endangered fish species (Colorado pikeminnow and razorback sucker) occurs in the Colorado River downstream of the project and critical habitat for two additional species (bonytail and humpback chub) occurs downstream of the project near Grand Junction. Colorado pikeminnow and razorback sucker have been documented in the river upstream as far as Rifle. No other species listed in Garfield County would be expected, as habitat conditions are not appropriate for these species. a. Determination of long-term and short-term effects on flora and fauna Flora The injection well will be placed within the disturbance of the Watson Ranch B COGCC approved natural gas well pad. The surface disturbance and vegetation removal will encompass approximately 6.85 acres. The affected area is primarily composed of grasses planted for hay production and livestock pasture, including crested wheatgrass, smooth brome, orchardgrass, timothy grass, and several additional species. The area immediately surrounding the proposed Watson Ranch B Pad UIC site consists of pinyon-juniper woodlands and sagebrush shrublands. The habitat may be suitable for Colorado hookless cactus, but none were observed. This species is not Ursa Operating Company Watson Ranch B Injection Well Impact Analysis Page 5 known to occur nearby. Due to soil composition, elevation, previous disturbances, and hydrology patterns, the site is unlikely to provide suitable habitat for any other special status plant species in this region. A review of the Colorado Rare Plant Field Guide and WestWater’s database confirms that no known populations of special status plants occur nearby. Noxious weeds occurring in the area are discussed in an accompanying IVNWMP prepared by WestWater for this project. Fauna Colorado River Endangered Fishes: Designated critical habitat for two endangered fish species (Colorado pikeminnow and razorback sucker) occurs in the Colorado River downstream of the project. These species have been documented near Parachute. Designated critical habitat for two additional species (bonytail and humpback chub) occurs downstream of the project near Grand Junction. Potential impacts would be limited to runoff from storms or snowmelt that carry increased sediment loads or pollutants from the pad to the river. Implementation of a Spill Prevention, Control, and Countermeasure Plan (SPCC), a Stormwater Management Plan (SWMP), and Best Management Practices (BMPs) associated with this type of project will provide a good degree of mitigation for any potential impacts. There are be no anticipated depletions that could affect aquatic species associated with the project. Raptors: No raptor nesting habitat will be directly affected by the project. The primary potential long-term effect would be the loss of foraging habitat within the footprint of the proposed pad. Short-term effects could include temporary displacement of raptors in an avoidance area surrounding the pad due to increased human presence and equipment associated with construction, operation, and maintenance of the facility. American Elk and Mule Deer: Approximately 6.85 acres of foraging habitat will be lost from development of the natural gas well pad where the injection well will be placed. No migration corridors are affected. Human presence and activity may affect animal distribution by creating avoidance areas and increasing stress on wintering big game. This project will contribute to the cumulative effects of habitat alteration and increased development in the area. An increase in vehicle traffic could result in additional vehicle related wildlife mortality, although additional traffic resulting from this project would contribute minimally, given current traffic volumes on the existing county road. Fences can pose an increased risk to big game and any fencing around the facility should be constructed according to published standards that reduce impacts to big game. Black Bear and Mountain Lion: Potential encounters between bears and personnel could occur if garbage or food is available on the site. Mountain lions are occasionally observed in the area, but generally avoid human contact. Incidences of human and Ursa Operating Company Watson Ranch B Injection Well Impact Analysis Page 6 bear/lion interactions sometimes result in the euthanasia of offending animals by the CPW. Small Mammals, Birds (BCC), and Reptiles: The vegetation removal required for development of the natural gas well pad will reduce the habitat available for small mammals and birds. The vegetation on the site provides nesting cover for ground nesting species, though very little nesting habitat for other birds will be lost. The habitat is primarily valuable for foraging. Human presence and activity may affect animal distribution. An increase in traffic could result in vehicle related mortalities. b. Determination of the effect on designated environmental resources, including critical Wildlife Habitat Development of this well pad will result in additional contributions to the cumulative effects of habitat alteration and fragmentation in the region, although development of the project is not expected to significantly affect any critical environmental resources. c. Impacts on wildlife and domestic animals through creation of hazardous attractions, alteration of existing native vegetation, blockade of migration routes, use patterns, or other disruptions  Creation of hazardous conditions: Some passerine bird species and small mammals may choose to inhabit or nest on equipment or objects at the site. The inherent risks associated with these structures are low. By closing or covering all ports, hatches, cavities, and openings (such as the ends of pipes) this potential is decreased. Most non-game bird species and their nests are protected under the Migratory Bird Treaty Act (16 U.S.C. 703-712; Ch. 128; July 13, 1918; 40 Stat. 755) and damaging occupied nests could be considered a “take” resulting in a violation. Livestock and big game will likely avoid the project site.  Indirect Construction Effects: Additional human presence and activity related to construction, operation, and maintenance of an injection well may influence spatial and temporal use of habitat surrounding the project by wildlife. Since the site exists adjacent to significant and long-term human presence, the additional disturbance from this project is expected to be low.  Road-kill: Speed limits are set low and most wildlife in the area has become habituated to vehicle traffic. The potential for vehicle related mortalities related to this project should be low. d. Evaluation of any potential radiation hazard that may have been identified by the State or County Health Departments Naturally occurring radioactive materials are not expected to be an issue at the site. Colorado oil and gas operations are not known to have a significant problem with naturally occurring radioactive materials (NORM) or technologically enhanced naturally occurring radioactive materials (TENORM); however, there have been some instances where pipe scale has contained radium and associated radon gas. A NORM Ursa Operating Company Watson Ranch B Injection Well Impact Analysis Page 7 survey including site specific testing could be performed to further assess the radon potential at the site to serve as a baseline assessment if used pipe or pipe scale is to be disposed offsite in the future. Olsson reviewed the Colorado Bulletin 40, Radioactive Mineral Occurrences of Colorado which states that nearly all of Garfield County’s uranium production came before 1954, and most of that came from the Rifle and Garfield mines. Both of these mines were located along the same ore body near the town of Rifle. These occurrences were all hosted in the Jurassic Morrison and Entrada Formations, and the Triassic-Jurassic Navajo Sandstone, or the Triassic Chinle Formation which are known to contain uranium and vanadium deposits in the county and in the Colorado Plateau in general. These formations lie at great depth in the vicinity of the site and are stratigraphically below the depth of the Wasatch Formation. The CDPHE has posted a statewide radon potential map on their website based on data collected by the EPA and the U.S. Geological Survey. Garfield County and most of Colorado has been mapped as being within Zone 1 – High Radon Potential, or having a high probability that indoor radon concentrations will exceed the EPA action level of 4 picocuries per liter (pCi/L). Radon is not expected to be a significant problem at the proposed site since the development will not include any occupied structures, personnel will not be onsite for extended periods, and the site will not be developed with structures containing basements or substructures in which radon can accumulate. 7. Nuisance Adjacent lands will not be impacted by the generation of vapor, dust, smoke, noise, glare, or vibration beyond those impacts of the current natural gas activities taking place on the well pad. Ursa will apply the appropriate level of controls to accommodate potential impacts via adherence to CDPHE Air Quality regulations and the implementation of industry BMPs included in the SWMP and Ursa’s dust control plan. This proposed use will comply with Colorado Revised State Statutes and COGCC Rules regarding noise impacts at all times. A sound barrier will be erected and remain in place through completions to minimize noise. As shown in the Noise Assessment included in this submittal, the projected sound pressure will not exceed the COGCC and Garfield county Standards for Residential/Agricultural/Rural zones. The pad and access road will be graveled to reduce fugitive dust, which will be controlled using water or other dust suppressants. Remote monitoring will be used to reduce truck traffic and fugitive dust to the extent practical. Aboveground facilities will be managed to minimize visual effects (e.g. painted to blend with environment). 8. Hours of Operation The proposed injection well facility will be accessible to Ursa personnel and their contractors 24 hours-a-day, 365 days-a-year. Daily inspections will be conducted by local Ursa Operating Company Watson Ranch B Injection Well Impact Analysis Page 8 operations personnel. Operations and maintenance of the proposed facility will be coordinated with the existing operations in the area. Monitoring of operations will typically be performed periodically during the daylight hours of 7:00 am to 6:00 pm by an Ursa employee arriving via pickup truck. Article 4-203.G.3 NRCS Soils Report Ursa Operating Company LLC Watson Ranch B Injection Well OA Project No. 014-3005 SBattlementPkwy Underwood Ln Gardner Ln F o u r C o r n e r R d O l d S t o n e Q u a r r y R d 56 58 55 500' 1,000' 1/4 Mile 1/2 Mile 33 Author: M. Spinelli 0 500 1,000Feet ±Revision: 1 Date: 11/19/2014 Notes / Comments:NRCS SOILS KEY: MAP SYMBOL SERIES NAME (Slope) 55 Potts loam (3-6% slopes) 58 Form 2A - Attachment G & HForm 2A - Attachment G & HNRCS Map & Current Land Uses Potts-Ildefonso complex (12-25%)39.43338 -108.02268Section 17, Township 7 South, Range 95 West Watson Ranch B Attachment G - Land use type "Range" 56 Potts loam (6-12% slopes) Proposed Pipeline Pipeline Tie-in Proposed Access ProposedDevelopment County Roads Local Roads 33 Ildefonso stony loam (6-25%) Attachment H – NRCS Soil Survey, Rifle Area Map Symbol 56 – Potts loam (6-12% slopes) Deep, well drained, moderately sloping soils found on mesas, benches and sides of valleys. Elevation 5,000 to 7,000 feet Average Annual Precipitation Approximately 14 inches Average Annual Air Temp Approximately 46 degrees F Frost Free Days Approximately 120 days Permeability Moderate Available Water Capacity High Effective Rooting Depth 60+ inches Surface Runoff Slow Erosion Hazard Moderate Native Vegetation: Mainly wheatgrass, needleandthread, and sagebrush. Development is limited by low strength and shrink-swell potential. This soil is in capability subclasses IIIe, irrigated and IVe, nonirrigated. Map Symbol 58 – Potts-Ildefonso complex (12-25% slopes) Strongly sloping to hilly soils found on mesas, alluvial fans, and sides of valleys. Elevation 5,000 to 6,500 feet Average Annual Precipitation Approximately 14 inches Average Annual Air Temp Approximately 46 degrees F Frost Free Days Approximately 120 days Permeability Moderate Available Water Capacity High Effective Rooting Depth 60+ inches Surface Runoff Medium Erosion Hazard Moderate Native Vegetation: Mainly wheatgrass, needleandthread, and sagebrush with additional pinyon, juniper, ricegrass, serviceberry, bitterbrush, and junegrass. Development is limited by steep slopes, runoff, gullying, and erosion. This complex is in capability subclass Vie, nonirrigated. Article 4-203.G.4 Geologic and Soils Hazard Report Ursa Operating Company LLC Watson Ranch B Injection Well OA Project No. 014-3005 NATURAL AND GEOLOGIC HAZARDS ASSESSMENT REPORT URSA OPERATING COMPANY WATSON RANCH B UIC – COUNTY ROAD 303 SE ¼, SW ¼, SECTION 17, T7S, R95W, 6TH P.M. GARFIELD COUNTY, COLORADO PREPARED FOR URSA OPERATING COMPANY 1050 17TH STREET, SUITE 2400 RIFLE, COLORADO 81650 PREPARED BY OLSSON ASSOCIATES 4690 TABLE MOUNTAIN DRIVE, SUITE 200 GOLDEN, COLORADO 80403 JANUARY 2015 PROJECT NO. 014-3005 Geologic Hazard Report i Olsson Associates Ursa Operating Company Watson B UIC Golden, Colorado Garfield County, CO January 2015 Natural and Geologic Hazard Report Preface Garfield County, Colorado, finalized the Land Use and Development Code (LUDC) with an effective date of July 15, 2013, last amended December 16, 2013. According to Section 7-108 Use of Land Subject to Natural Hazards of the Garfield County LUDC “Land subject to identified Natural and Geologic Hazards, such as falling rock, landslides, snow slides, mud flows, radiation, flooding, or high water tables, shall not be developed unless it has been designed to eliminate or mitigate the potential effects of hazardous site conditions as designed by a qualified professional engineer and as approved by the County.” The LUDC requires a Natural and Geologic Hazard Study be prepared by a qualified professional geologist and submitted with a development plan or plat. The LUDC defines a geologic hazard as “A geologic phenomenon that is so adverse to past, current, or foreseeable construction or land use as to constitute a significant hazard to public health and safety or to property.” The LUDC defines a Hazard Area as “An area that contains or is directly affected by a geologic hazard, including but not limited to the following types of areas.” A. Avalanche Area. “A mass of snow or ice and other material that may become incorporated therein as such mass moves rapidly down a slope.” B. Landslide Area. “An area with demonstrably active mass movement of rock and soil where there is a distinct surface rupture or zone of weakness that separates the landslide material from more stable underlying material.” C. Mudflow Debris Area. “An area subject to rapid mud and debris movement or deposit occurring after mobilization by heavy rainfall or snowmelt runoff. Such areas are formed by successive episodes of deposition of mud and debris.” D. Radioactive Area. “An area subject to various types of radiation emission from radioactive minerals that occur in natural or manmade deposits of rock, soil, or water.” E. Potentially Unstable Soils. “An area of land identified as having soils that may cause damage to structures, such as buildings and roadways, as a result of over saturation or some other outside influence.” According to the Garfield County LUDC Section 4-203 Description of Submittal Requirements, the professional qualifications for preparation and certification of certain documents required by this Code are as follows: “Geologist: Geology reports shall be prepared by either a member of the American Institute of Professional Geologists, a member of the Association of Engineering Geologists, or a qualified geotechnical engineer licensed in the State of Colorado.” Geologic Hazard Report ii Olsson Associates Ursa Operating Company Watson B UIC Golden, Colorado Garfield County, CO January 2015 Currently, the State of Colorado does not require licensure or registration of geologists; however, Colorado Revised Statutes do require that geologic reports be prepared or authorized by a professional geologist, and the term “Professional Geologist” is defined in Colorado Statutes. The references for these Statutes are shown here: 34-1-201. Definitions. As used in this part 2, unless the context otherwise requires: (1) “Geologist” means a person engaged in the practice of geology. (2) “Geology” means the science which treats of the earth in general; the earth’s processes and its history; investigation of the earth’s crust and the rocks and other materials which compose it; and the applied science of utilizing knowledge of the earth’s history, processes, constituent rocks, minerals, liquids, gases, and other materials for the use of mankind. (3) “Professional geologist” is a person who is a graduate of an institution of higher education which is accredited by a regional or national accrediting agency, with a minimum of thirty semester hours (forty-five quarter) hours of undergraduate or graduate work in a field of geology and whose post baccalaureate training has been in the field of geology with a specific record of an additional five years of geological experience to include no more than two years of graduate work. (4) 34-1-202. Reports containing geologic information. Any report required by law or by rule and regulation, and prepared as a result of or based on a geologic study or on geologic data, or which contains information relating to geology, as defined in Section 34-1-201 (2), and which is to be presented for any state agency, political subdivision of the state, or recognized state or local board or commission, shall be prepared or approved by a professional geologist as defined in Section 34-1-201(3). Professional Geologist Certification By means of this certification, I attest that: I am qualified to prepare a Natural and Geologic Hazard Study in accordance with the provisions of Section 7-207 of the Garfield County LUDC, and that I am a member of the American Institute of Professional Geologists per LUDC 4-203. Although I have not visited the proposed site, I am familiar with the geology and have performed field work in the area of the proposed Ursa Operating Company LLC Watson B Ranch UIC Well located in the SE~ SW~ Section 17, Township 7 South, Range 95 West, 61h Principal Meridian in Garfield County, Colorado. Although Colorado does not currently have a licensing board or registration program for professional geologists practicing in the state of Colorado, there are requirements within local and State statutes that require that geologic reports be prepared by a professional geologist. I attest that I meet the requirements of the Colorado Geological Survey's definition of a professional geologist having completed and met the educational requirements of the Colorado Geological Survey definition. I am a licensed Professional Geologist and Professional Geoscientist in other States, including Texas, Utah, and Wyoming which do have licensing programs for professional geologists. I have reviewed published geologic maps and reports applicable to this area and have considered the implications of these conditions in the context of the proposed development. This report has been prepared in accordance with good scientific principles and engineering practices including consideration of applicable industry standards, and with consideration of the requirements of the National Association of State Boards of Geology. The conclusions and recommendations contained in this report are based on information available and known to me at the time of this report. Good scientific principles and standard engineering practices were taken into consideration to in arriving at the conclusions and recommendation s made in this report. Prepared by James W. Hix, PG Senior Geologist Date: 01/19/2015 Geologic Hazard Report Ursa Operating Company Watson B UIC Garfield County, CO iii Reviewed by Olsson Associates Golden, Colorado January 2015 Geologic Hazard Report iv Olsson Associates Ursa Operating Company Watson B UIC Golden, Colorado Garfield County, CO January 2015 TABLE OF CONTENTS Natural and Geologic Hazard Report Preface ............................................................................... i Professional Geologist Certification ............................................................................................. iii TABLE OF CONTENTS ............................................................................................................... iv FIGURES ..................................................................................................................................... iv 1.0 EXECUTIVE SUMMARY ..................................................................................................... 5 2.0 GENERAL SITE LOCATION AND BACKGROUND ............................................................ 7 2.1 Project and Site Description ............................................................................................ 7 2.2 Structural Geology ........................................................................................................... 7 2.3 Site Geology .................................................................................................................... 8 2.4 Soil ................................................................................................................................... 8 2.5 Hydrologic Setting ............................................................................................................ 9 2.6 Aquifers ............................................................................................................................ 9 3.0 NATURAL AND GEOLOGIC HAZARD ASSESSMENT .................................................... 10 3.1 Utilities ........................................................................................................................... 10 3.2 Avalanche Hazard Area ................................................................................................. 10 3.3 Landslide Areas or Potential Landslide Hazard Areas .................................................. 10 3.4 Rockfall Areas ................................................................................................................ 11 3.5 Alluvial Fan Hazard Areas ............................................................................................. 11 3.6 Unstable or Potentially Unstable Slopes ........................................................................ 11 3.7 Corrosive or Expansive Soils and Rock ......................................................................... 11 3.8 Mudflow and Debris Fan Areas ..................................................................................... 12 3.9 Development Over Faults and Risk of Seismic Activity ................................................. 12 3.10 Flood Prone Areas ......................................................................................................... 13 3.11 Collapsible Soils ............................................................................................................ 13 3.12 Mining Activity ................................................................................................................ 13 3.13 Radioactivity .................................................................................................................. 13 4.0 Conclusions and Recommendations .................................................................................. 15 5.0 References ......................................................................................................................... 16  FIGURES List of Figures SL-1 Site Location Map G-1 Geology Map NRCS Soils Map Hydrology Map FP-1 Floodplain Map Geologic Hazard Report 5 Olsson Associates Ursa Operating Company Watson B UIC Golden, Colorado Garfield County, CO January 2015 1.0 EXECUTIVE SUMMARY Olsson Associates (Olsson) was contracted by Ursa Operating Company to assess natural and geologic hazards potentially present in the area of the proposed Watson Ranch B UIC well pad located in the SE ¼ SW ¼ Section 17, Township 7 South, Range 95 West, of the 6th Principal Meridian, Garfield County, Colorado. The site is at an elevation of about 5,560 feet above mean sea level (amsl) as shown on the attached SL-1 Watson Ranch B UIC Site Map. The purpose of this report is to identify geologic conditions that may pose hazards to a land development project in order that appropriate mitigation or avoidance techniques may be implemented as described in the Garfield County LUDC. According to the Garfield County LUDC, Section 7-207, the types of natural and geologic hazards identified pertain to the following: A. Utilities; B. Development in Avalanche Hazard Areas; C. Development in Landslide Hazard Areas; D. Development in Rock-fall Hazard Areas; E. Development in Alluvial Fan Hazard Areas; F. Slope Development; G. Development on Corrosive or Expansive Soils and Rock; H. Development in Mudflow Areas; and I. Development Over Faults. At the request of Ursa Operating Company, Olsson has included maps prepared by HRL Compliance Solutions, Inc. of Grand Junction, Colorado. Olsson is not responsible for the content of these maps and has reviewed the original source materials for information on soils and surface water in the area in addition to information provided on these maps. This report presents Olsson findings following an evaluation of these and other geologic hazards potentially affecting the site and proposed development. The Ursa Operating Company site was found to be suitable for the proposed development with consideration of the following identified geologic hazards.  Development in areas characterized by the Potts, soil unit #56, are limited by moderately steep slopes. This limitation may be mitigated by proper engineering and design.  The Potts loam soils are moderately corrosive to unprotected steel but the risk of corrosion to concrete is low. Corrosion can be mitigated by coating the steel or through cathodic protection.  According to the Preliminary Geologic Map of the Grand Valley Quadrangle, Garfield County (1:24,000), the proposed site is located on Quaternary age (Holocene) mudflows and fan gravel deposits (Symbol Qgmf).  According to the Geologic and Structural Map of the Grand Junction Quadrangle, Colorado and Utah (1:250,000), the site bedrock is located on the Tertiary age Wasatch Formation, but does not show the overlying Quaternary unconsolidated deposits over Geologic Hazard Report 6 Olsson Associates Ursa Operating Company Watson B UIC Golden, Colorado Garfield County, CO January 2015 the site. The map does show Quaternary colluvial deposits (Qc) which consist of earthflow, mudflow, landslide, and talus deposits to the south. The geologic mapping at a scale of 1:500,000 on the Colorado Oil and Gas Conservation Commission (COGCC) GIS database website shows the area covered by landslide deposits (Ql). Therefore, the site appears to be located near the contact of unconsolidated materials and bedrock.  The site is not mapped within the FEMA 100-year flood plain. The site is located at an elevation of approximately 5,560 feet approximately 1.3 miles south of the Colorado River which is at an elevation of approximately 5,150 feet. The Watson Ranch B UIC can be constructed to compensate for these limitations and potential hazards. This report should be read in its entirety, including but not limited to the conclusions and recommendations in Section 4.0. Geologic Hazard Report 7 Olsson Associates Ursa Operating Company Watson B UIC Golden, Colorado Garfield County, CO January 2015 2.0 GENERAL SITE LOCATION AND BACKGROUND Ursa Operating Company LLC (Ursa) contracted Olsson Associates (Olsson) to conduct a natural and geologic hazards assessment as part of the proposed development of the Watson B Ranch UIC well pad. The proposed facility will be used to drill an underground injection control (UIC) class II disposal well for exploration and production wastes. The following sections provide information about the proposed development and the site geologic setting. The site surface and bedrock geology is shown on the G-1 Geology Map. 2.1 Project and Site Description The proposed Watson Ranch B UIC well pad is located to the southeast of the town of Parachute, Colorado off of County Road 303. The site is located in the SE ¼ SW ¼ Section 17, T7S, R95W, 6th P.M. and is located in parcel # 240717300129. The surface land is owned by Watson Ranches, LTD of Meeker, Colorado. The site is located northwest of the intersection of Four Corners Road (County Road 308) and Gardner Lane (County Road 303), to the south of the community of Battlement Mesa. 2.2 Structural Geology The Watson B Ranch UIC well pad site is located in the southeastern part of the Piceance Basin. The Piceance Basin is an irregularly-shaped elongated basin formed by tectonic forces associated with the Laramide orogeny. These forces down warped the earth’s crust and formed the Piceance Basin as a result of the uplift of the surrounding Colorado Rocky Mountains and the Colorado Plateau. The Piceance Basin is the major structural geologic feature in the region. It is bound to the east by the Grand Hogback monocline, the White River Uplift to the northeast, the Gunnison Uplift to the south, the Uncompahgre Uplift to the south and southwest, the Douglas Creek Arch to the west-northwest, and the axial basin uplift to the north (Grout and Verbeek, 1992). Sedimentary rocks in the southwestern Piceance Basin gently dip to the north - northeast except where this regional dip is interrupted by low-amplitude folds. Numerous small sub-parallel northwest trending folds have been identified in the Green River Formation within the basin. The site is shown on the Geologic and Structure Map of the Grand Junction Quadrangle map (Scale 1:250,000). There are no mapped faults shown in the area of the site on the Geologic and Structure Map of the Grand Junction Quadrangle, Garfield County, Colorado (Cashion, 1973) or on the Preliminary Geologic Map of the Grand Valley 7.5-minute Quadrangle, Garfield County, Colorado (Donnell, Yeend, Smith, 1986) (Scale 1:24,000). A fault is a fracture in rock along which movement has occurred. Mountains are bound by faults and are a visible indication of a structural weakness in the earth’s crust. The Colorado Rocky Mountains are bound by faults; however, these faults are not always visible at the ground surface either because the fault trace is ‘blind’, meaning that the fault does not have surface expression since it does not cut across overlying sedimentary bedrock units, or that it has been Geologic Hazard Report 8 Olsson Associates Ursa Operating Company Watson B UIC Golden, Colorado Garfield County, CO January 2015 buried and concealed by unconsolidated sediments deposited over the area where the faults are present. There are no known major faults mapped in the area of the site. 2.3 Site Geology According to the Preliminary Geologic Map of the Grand Valley Quadrangle (Donnell, Yeend, Smith, 1986), bedrock mapped to the east of the project area consists of the Eocene and Paleocene-age Shire Member of the Wasatch Formation which consists of purple, lavender, gray, and brown claystone, with minor beds of fine- to medium-grained sandstone. The maximum exposed thickness of the Wasatch is approximately 1,200 feet. The bedrock in the area of the site is covered with unconsolidated sediments of Quaternary age consisting of mudflow and fan gravel deposits consisting of pebble, cobble, and boulder gravel within a gray matrix of poorly-sorted coarse sand; clasts consisting primarily of unweathered basalt, with some sandstone, marlstone, siltstone and claystone. These deposits are largely derived from solifluction deposits located east of the Grand Valley 7.5-minute quadrangle. Weak claystone in the upper Wasatch Formation are responsible for the slope failure which resulted in landslides and mudflows during a time when the climate was much wetter. 2.4 Soil Olsson reviewed the Natural Resources Conservation Service (NRCS) information and information provided on the NRCS Soils Map shows the area soil types. Soils, consisting of the following units, are within the study area around Watson Ranch B UIC well pad:  Potts loam 6% to 12% slopes, Map Symbol 56: The Potts loam soil is a deep, well drained, moderate sloping to rolling soil formed on mesas and the sides of valleys at elevations between 5,000 feet to 7,000 feet above mean sea level. Typically the surface layer is a brown loam about four inches thick and the subsoil is a reddish brown clay loam to a depth of 24 inches, and the substratum is a pinkish white loam to a depth of 60 inches. Permeability is very slow, and available water capacity is high. Surface runoff is medium, and the erosion hazard is severe.  Potts-Ildefonso complex, 12% to 25% slopes, Map Symbol 58: The Potts-Ildefonso complex is located along a drainage on the northeast side of the site. The Potts-Ildefonso complex soil is a deep, well drained, sloping soil formed on fans and high terraces at elevations between 5,100 feet and 6,200 feet above mean sea level. Typically the surface layer is a moderately alkaline, pale brown loam about three inches thick and the substratum is light brown to brown silty clay loam to a depth of 60 inches. Permeability is very slow, and available water capacity is high. Surface runoff is moderately rapid, and the erosion hazard for the Potts Ildefonso complex soils is moderate. Slope is listed as a moderate limitation for development on the Potts loam soils. Due to the clay loam subsoil the Potts loam percolates slowly. The Potts loam soils in the vicinity of the site are listed to moderately to highly corrosive to unprotected steel but the risk of corrosion to concrete is low. Buried piping and structures onsite may need to be coated or have adequate cathodic protection to prevent corrosion. Use of corrosion resistant concrete may be necessary. Geologic Hazard Report 9 Olsson Associates Ursa Operating Company Watson B UIC Golden, Colorado Garfield County, CO January 2015 Slope is listed as a severe limitation for the Potts-Ildefonso complex soils, and large stones are listed as a limitation for development over the Ildefonso soil. The Potts-Ildefonso complex soils are listed as having a high risk of corrosion to uncoated steel, and a moderate to low risk of corrosion to concrete. Permeability of the Ildefonso soils is moderately rapid and the available water capacity is low. Surface runoff is medium and the erosion hazard is moderate. 2.5 Hydrologic Setting The site is located at an elevation of approximately 5,560 feet amsl on a terrace above the Colorado River flood plain. The Colorado River is located approximately 1.3 miles to the northwest at an elevation of approximately 5,150 feet amsl. There are several unnamed intermittent drainages located near the site, the closest is approximately 130 feet to the north of the site that drains to the Colorado River. The Watson Ranch B Site is located approximately 1,930 feet to the northeast of the confluence of Monument Gulch and Stone Quarry Gulch. There are two unnamed intermittent drainages located in proximity to the site. One of the intermittent drainages is located on the northwest corner of the Site, and the other is approximately 150 feet to the south of the Site. These surface water features are shown on the Hydrology Map. 2.6 Aquifers The Wasatch Formation locally yields water to wells in some areas, but is generally considered a confining unit. The Tertiary sedimentary rocks in the Piceance Basin are generally fine-grained and well cemented resulting in very small hydraulic conductivity in the rock matrix. Sandstone and siltstone generally occur in lenticular bodies and locally have moderate hydraulic conductivities which range from 0.001 to 0.01 foot per day. These lenses of sandstone and siltstone are often widely spaced and not interconnected which further limits the volumes of groundwater the formation can yield to wells. In some areas, fracturing during the structural deformation that occurred when the Piceance Basin was uplifted and through dissolution of cementing minerals has enhanced the permeability and hydraulic conductivity in parts of the Piceance Basin aquifer system (Topper et al, 2003). Water well depths in the area range from 120 feet to 180 feet below ground surface in the vicinity of the site. The water wells in the SE ¼ SW ¼ have total depths of 140 feet to 145 feet below ground surface (bgs) and static water levels that range from 64 feet to 111 feet bgs. Groundwater within the unconsolidated sediments in the area of the proposed site is controlled by the thickness of the sediments and the depth to the top of the Wasatch bedrock. The estimated groundwater flow direction in the vicinity of the site is likely to be sub-parallel with the Colorado River, flowing north-northwest toward the Colorado River. Geologic Hazard Report 10 Olsson Associates Ursa Operating Company Watson B UIC Golden, Colorado Garfield County, CO January 2015 3.0 NATURAL AND GEOLOGIC HAZARD ASSESSMENT The following sections present the assessment of geologic hazards in the vicinity of the proposed Water Impoundment. The SL-1 Site Location Map shows the location of the Watson Ranch B UIC Well Pad site in relation to the affected parcel and local roads. 3.1 Utilities Aboveground utility facilities located in Hazard Areas are to be protected by barriers or diversion techniques approved by a qualified professional engineer. The determination to locate utility facilities aboveground will be based upon the recommendation and requirements of the utility service provider and approved by the County. Except for potential flooding, aboveground utilities, such as transformers, are not expected to be affected by geologic or other natural hazards. Trenches for water pipelines, natural gas pipelines, and electrical lines are expected to be associated with the proposed development. The slopes and corrosive soil may pose technical challenges to the installation of these utilities; however, it is expected that these limitations can be overcome with proper design and installation. 3.2 Avalanche Hazard Area Winters are cold in the mountainous areas of Garfield County, and valleys are colder than the lower parts of adjacent mountains due to cold air drainage. Average seasonal snowfall in Garfield County is 50 inches. The greatest snow depth at any one time during the period of record from 1951 to 1974 was 29 inches recorded at Rifle, Colorado approximately 25 miles to the east-northeast of the proposed site. Avalanches are not expected to affect the proposed natural gas well site, since it is located at an elevation of approximately 5,560 feet amsl. Areas in eastern Garfield County are at higher elevations, receive more snow pack, and are, therefore, more prone to avalanches in certain years. Avalanches are the most dangerous geologic hazard in Colorado resulting in injuries, loss of life, and about $100,000 in direct property damage, and indirect economic losses in the millions of dollars annually. However, the avalanche prone areas include the Park Range and Flat Tops in northeastern Garfield County, Colorado, to the north of Glenwood Springs. Glenwood Springs, near the east edge of the area, averages about one degree cooler than Rifle and receives about five inches more precipitation per year (Harman and Murray, 1985). 3.3 Landslide Areas or Potential Landslide Hazard Areas The site is located on mudflow and fan gravel deposits delivered to their present positions as successive mudflows and debris clogged streams issuing from the Battlement Valley. Larger scale maps describe all these deposits as landslide deposits (Ql). These alluvial terrace and fan gravel deposits are derived from and reworked from landslide deposits further up on Battlement Mesa and were transported down onto the Colorado River flood plain at the end of the last ice age when the climate was wetter. Solifluction deposits are extensive in the Rulison 7.5-minute Geologic Hazard Report 11 Olsson Associates Ursa Operating Company Watson B UIC Golden, Colorado Garfield County, CO January 2015 quadrangle located to the east, but are only found in a small area on the east side of the Parachute (Grand Valley) 7.5-minute quadrangle (Yeend, Donnell, Smith, 1986). According to Map 24 – Surface Geology map, Geologic Hazards Identification Study (Lincoln Devore, 1975-1976), there are no landslides shown to the south of Interstate 70 in the Parachute – Battlement Mesa area. Landslide areas are shown to the northwest of the town of Parachute (Garfield County, Surface Geology, 2007). 3.4 Rockfall Areas The site is not located within an area that has been mapped as having rockfall or potential for rockfall. Potential rockfall areas are present along the steep drainages incised by the major drainages and at higher elevations on Battlement Mesa. 3.5 Alluvial Fan Hazard Areas The site is located in an area that is not mapped as being in an alluvial fan hazard area according to the Garfield County Surficial Geology, 2007. The site is located on mudflow and fan gravel deposits (Symbol Qgmf) according to the Preliminary Geologic Map of the Grand Valley Quadrangle (Donnell, Yeend, Smith, 1986). The site is on the northeastern part of coalescing alluvial fans created along the north flank of Battlement Mesa by Battlement Creek, Monument Gulch, and other unnamed intermittent drainages. These deposits lie about 200 feet above the Colorado River flood plain. 3.6 Unstable or Potentially Unstable Slopes According to the Garfield County Slope Hazard Study Areas 1, 2, & 3 map, parts of the area north of the Colorado River and the town of Parachute, Colorado have been mapped as being in an area of major slope hazard. The map does not show the area south of the Colorado River and in the vicinity of the site as being identified in a slope hazard area. The slope hazard map recommends that site specific investigations should be conducted to assess active landslide areas. Geologic studies may include intensive drilling and sophisticated strength testing, stability analyses, and monitoring of soil, rock, and groundwater conditions. Mitigation may be possible, but likely will be expensive, may require special siting, and will involve some risk. Avoidance may be recommended for projects of lower economic value (Garfield County, Slope Hazard Study 2002). The Potts loam soils are found on 6% to 12% slopes and slope is listed as a moderate limitation for development on these soils. Engineering, design, and construction practices of the proposed development are expected to mitigate the limitation of slopes at the site since the site is located within an area developed for other land uses, including development of natural gas well pads. The site may require mitigation for slope and will be graded and constructed for this purpose. 3.7 Corrosive or Expansive Soils and Rock According to the Soil Survey of the Rifle Area, the soils onsite consist of the Potts Loam (Unit 56) and a strip of Potts-Ildefonso complex soils located on the northwest corner of the Site. The Potts loam and the Potts-Ildefonso complex soils are listed as a high risk of corrosion to unprotected steel, but the potential risk to corrosion of concrete is listed as moderate to low. Geologic Hazard Report 12 Olsson Associates Ursa Operating Company Watson B UIC Golden, Colorado Garfield County, CO January 2015 unprotected steel. The corrosive hazard of these soils may be mitigated by coating the steel or by providing adequate cathodic protection, and using corrosion resistant concrete. Some Tertiary and Cretaceous age sedimentary rocks with high clay content are capable of accepting water into their chemical structure and expanding many times their volume when dry. These sedimentary rocks, and soils formed from these rock types, may expand or contract as they become wet and then dry out resulting in damage to structures built upon them. The Potts loam soils (Unit #56) do not have a high shrink-swell potential and are not considered expansive soils. There is not a potential for expansive rock or soils in the area of the proposed Watson Ranch B UIC site. 3.8 Mudflow and Debris Fan Areas The site is located in an area of mud flow and debris fan areas, but is characterized by alluvial terrace and fan gravel deposits. These deposits are derived from and reworked from Quaternary age landslide deposits deposited as coalescing alluvial fans along the north flank of Battlement Mesa. Mudflow and fan gravel deposits, derived largely from solifluction deposits to the east of the quadrangle. These mudflows originated from higher elevations to the south and would follow the drainages to lower elevations closer to the Colorado River floodplain. Wetter conditions at the end of the last ice age were most likely responsible for the development of the extensive mudflows and fan deposits peripheral to Battlement Mesa. Glacial conditions that existed on the Grand Mesa during the Pleistocene did not exist on Battlement Mesa at this time. Abundant annual runoff is suspected in creating high pore-water pressures within the Wasatch Formation shale and claystone to cause slope failure, especially on north-facing slopes where evaporation was at a minimum (Yeend, 1968). 3.9 Development Over Faults and Risk of Seismic Activity There are no major faults shown in the Grand Valley area on the Geologic and Structure Map of the Grand Junction Quadrangle, Colorado and Utah (Cashion, 1973). There are no mapped faults shown on the Preliminary Geologic Map of the Grand Valley Quadrangle, Garfield County, Colorado (Donnell, Yeend, and Smith, 1986) in the immediate vicinity of the site. The Piceance Basin and other Tertiary age basins of the Colorado Plateau are defined by monoclines, at least along one margin. The Grand Hogback, to the east near the town of Rifle, is such a monocline which is thought to have formed by reactivation of pre-existing, steeply dipping fault zones in the Precambrian basement rock. Recent seismic data suggests that some of the monoclines, especially in the Rocky Mountain foreland near the boundary with the Colorado Plateau, overlie a west-, southwest-, or south-directed thrust fault system. These blind thrust faults transect older Mesozoic and Paleozoic sedimentary rocks that resulted from two major deformational events associated with the uplift of the ancestral Rocky Mountains. The Grand Hogback monocline formed above the tip of a blind, Precambrian basement rock thrust fault wedge which moved southwest and west-southwest into the Piceance basin (Grout and Verbeek, 1992). Geologic Hazard Report 13 Olsson Associates Ursa Operating Company Watson B UIC Golden, Colorado Garfield County, CO January 2015 Colorado is considered a region of minor earthquake activity; however, there is uncertainty due to the relatively short historic record. According to the USGS Colorado Earthquake History online, newspaper accounts were the primary source of earthquake data in Colorado prior to 1962. Few earthquakes have been reported in this part of Colorado. A very minor earthquake occurred in the northwestern part of Colorado on November 22, 1982 at 3:09 a.m. MST. The magnitude 2.9 earthquake was located about 18 miles northeast of the town of Rifle and was felt at a fish hatchery in the area. The largest quake in the area occurred on April 22, 1984 and had a magnitude of 3.1 on the Richter scale. The quake was felt in Carbondale and in Glenwood Springs. Of the hundreds of quakes that occurred in the Carbondale area during that time period, 12 were reported as felt. 3.10 Flood Prone Areas The facility is not shown within the FEMA 100 year flood hazard zone based on the Flood Plain Map in the Vicinity of the Town of Parachute, Garfield County, Colorado, or a Firmette Map generated from the FEMA data. The Colorado River flood plain is located approximately a half mile to the north of the site at elevations that range 5,200 feet to 5,085 feet. The unnamed drainage and the Monument Gulch drainage are shown as having Zone A – 100-year flood plains located along their banks These areas are also prone to flash floods. The flood plain along the Colorado River is shown in relation to the Watson Ranch B UIC well pad on the attached Flood Plain Location Map. 3.11 Collapsible Soils Collapsible soils are another type of subsidence that occurs in parts of western Colorado where unconsolidated sediments are present. This ground settlement can damage man-made structures such as foundations, pavements, concrete slabs, utilities, and irrigation works. Collapsible soils have not been mapped in the area and are not expected to be encountered in the vicinity of the site. 3.12 Mining Activity A review of the Grand Valley 7.5-minute quadrangle and aerial photographs did not show any significant mining activities in close proximity to the proposed Watson Ranch B UIC well site. Oil shale mining was conducted north of the town of Parachute, and there are sand and gravel operations along the Colorado River. There were no mining activities shown in the immediate area of the site. 3.13 Radioactivity Naturally occurring radioactive materials are not expected to be an issue at the site. Colorado oil and gas operations are not known to have a significant problem with naturally occurring radioactive materials (NORM) or technologically enhanced naturally occurring radioactive materials (TENORM); however, there have been some instances where pipe scale has contained radium and associated radon gas. A NORM survey including site specific testing could be performed to further assess the radon potential at the site to serve as a baseline assessment if used pipe or pipe scale is to be disposed offsite in the future. Geologic Hazard Report 14 Olsson Associates Ursa Operating Company Watson B UIC Golden, Colorado Garfield County, CO January 2015 Olsson reviewed the Colorado Bulletin 40, Radioactive Mineral Occurrences of Colorado which states that nearly all of Garfield County’s uranium production came before 1954, and most of that came from the Rifle and Garfield mines. Both of these mines were located along the same ore body near the town of Rifle. These occurrences were all hosted in the Jurassic Morrison and Entrada Formations, and the Triassic-Jurassic Navajo Sandstone, or the Triassic Chinle Formation which are known to contain uranium and vanadium deposits in the county and in the Colorado Plateau in general (Nelson-Moore, Collins, and Hornbaker, 1978). These formations lie at great depth in the vicinity of the site and are stratigraphically below the depth of the Wasatch Formation. The Colorado Department of Public Health and Environment (CDPHE) has posted a statewide radon potential map on their website based on data collected by the EPA and the U.S. Geological Survey. Garfield County and most of Colorado has been mapped as being within Zone 1 – High Radon Potential, or having a high probability that indoor radon concentrations will exceed the EPA action level of 4 picocuries per liter (pCi/L). Radon is not expected to be a significant problem at the proposed site since the development will not include any occupied structures, personnel will not be onsite for extended periods, and the site will not be developed with structures containing basements or substructures in which radon can accumulate. Geologic Hazard Report 15 Olsson Associates Ursa Operating Company Watson B UIC Golden, Colorado Garfield County, CO January 2015 4.0 Conclusions and Recommendations The following conclusions and recommendations were made following a review of the available site data for natural and geologic hazards in the vicinity of Watson Ranch B UIC site located in Garfield County, Colorado.  Avalanche conditions are not expected to be a hazard in the area of the site.  The site is located on mudflow and fan gravels overlying alluvial terrace deposits and bedrock consisting of the Wasatch Formation. The site is within the town limits for Battlement Mesa, but outside the planned unit development (PUD), and there are existing gas wells and other structures in the area. The landslide, alluvial terrace, and fan gravels are not expected to constitute a geologic hazard for the Watson Ranch B UIC site development.  Rockfall areas are not present in the area of the site and are not expected to be a geologic hazard affecting the site.  The site is not in an area mapped as an alluvial fan hazard area; however, the site is underlain by alluvium and fan gravels. The area has been mapped at large scale as landslide deposits. These landslide deposits formed at the end of the last ice age when the climate was wetter, and are not expected to pose a hazard to the proposed Watson Ranch B UIC well site.  Slope is listed as a moderate limitation for the Potts loam (Unit #56) soils and a severe limitation for the Potts-Ildefonso complex (Unit #58); however, it is expected that with appropriate design and engineering controls, the site can be developed for its intended use.  The Potts loam and Potts-Ildefonso complex soils are listed as a high corrosion risk to uncoated steel, but the potential of corrosion to concrete is moderate to low. Corrosion can be mitigated by coating steel or by using appropriate cathodic protection, and using concrete formulation that is resistant to corrosion.  The Potts loam and Potts-Ildefonso complex soils have a low shrink-swell potential. Expansive soils are not a hazard at the Watson Ranch B UIC site.  Collapsible soils are not present in the vicinity of the proposed Watson Ranch B UIC site.  No significant faults have been mapped or are known in the Watson Ranch B UIC site.  The site is not mapped as being within the 100 year flood plain. Flash flooding is a hazard for lower elevations along Battlement Creek, Monument Gulch, and areas along the Colorado River. There are unnamed drainages located approximately 130 feet to the north; however, it is expected that these drainages do not pose a significant flooding hazard.  There are no mining activities shown in the vicinity of the site. Natural gas well drilling has been conducted in the area since the 1960s.  There are no significant radioactive mineral deposits known in the immediate area of the site. The presence of NORM may be an issue with exploration and production and could be an issue with used pipe scale or used equipment. Radioactive materials are not expected to pose a significant hazard at the site.  Geologic Hazard Report 16 Olsson Associates Ursa Operating Company Watson B UIC Golden, Colorado Garfield County, CO January 2015 5.0 References  Cashion, W.B., 1973, Geologic and Structure Map of the Grand Junction Quadrangle, Colorado and Utah, USGS, Map I-736, scale 1:250,000  Donnell, J.R., Yeend W.E., Smith M.C., 1986, Preliminary Geologic Map of the Grand Valley Quadrangle, Garfield County, Colorado, scale 1:24,000  Grout, M. A. and Verbeek, E.R., 1992, U.S.G.S. Bulletin 1787-Z, Fracture History of the Divide Creek and Wolf Creek Anticlines and Its Relation to Laramide Basin-Margin Tectonism, Southern Piceance Basin, Northwestern Colorado, 32 p.  Fischer, R.P., 1960, Vanadium-Uranium Deposits of the Rifle Creek Area, Garfield County, Colorado, U.S.G.S. Bulletin 1101, 52 p.  Hail, W.J., Jr., 1992, U.S.G.S. Bulletin 1787-R, Geology of the Central Roan Plateau Area, Northwestern, Colorado, 26 p.,  Harman, J.B. and Murray, D. J., 1985, Soil Survey of Rifle Area, Colorado, Parts of Garfield and Mesa Counties, Colorado: U.S. Department of Agriculture, Soil Conservation Service, in cooperation with the Colorado Agricultural Experiment Station, 149 p. two plates, and 20 map sheets.  Nelson-Moore, J.L., Bishop Collins, D., Hornbaker, A.L., 2005, Colorado Geologic Survey, Bulletin 40, Radioactive Mineral Occurrences of Colorado, pp 154-158 (CD)  Robson, S.G. and Banta, E.R., 1995, U.S.G.S. Hydrologic Investigations Atlas 730-C, Groundwater Atlas of the United States, Segment 2, Arizona, Colorado, New Mexico, Utah, 32 p.  Topper, R., Spray, K. L., Bellis, W.H., Hamilton, J.L., Barkman, P.E., Ground Water Atlas of Colorado, Colorado Geologic Survey, 2003, Special Publication 53, 210 p.  Yeend, W.E., 1969, Quaternary Geology of the Grand and Battlement Mesas Area, Colorado, USGS Professional Paper 617, 50 p, 1 plate. Online References  Colorado Oil and Gas Conservation Commission http://cogcc.state.co.us/  Natural Resources Conservation Service - Soil Survey http://www.nrcs.usda.gov/  Garfield County  Slope Hazards: http://garfield‐county.com/geographic‐information‐ systems/documents/6439291200422slopehaz.pdf   Soil Hazards: http://garfield‐county.com/geographic‐information‐ systems/documents/64335291200423soilhaz.pdf  Surficial Geology of Garfield County: http://garfield‐county.com/geographic‐information‐systems/documents/geologic‐hazards/24surfgeo.pdf  Colorado Geological Survey website: http://geosurvey.state.co.us/hazards  Colorado Geological Survey website: http://geosurvey.state.us/land/Pages/Professional  Geologist   Colorado Department of Public Health and Environment: http://co‐ radon.info/CO_radon_map.html FIGURES ") Watson Ranch B ProposedBMC B Pad 7S96W 07 7S 95W Fo u r C o r n e r R d Stone Quarry Rd Gardner Ln Battlement P y Morrisania Me s a R d Fo u r C o r n e r R d Battlement Py Iro n w e d g e C i Sp e n c e r P y Ol d S t o n e Q u a r r y R d Sipprelle Dr Underwood Ln Par a c h u t e C r e e k R d 21 06 05 13 19 16 07 01 08 20 17 04 12 18 09 24 Allenwater Creek Pa r a c h u t e C r e e k Col o r a d o R i v e r D i a m o n d D i t c h Cor n e l l D i t c h DISCLAIMER : This Geographic Information System (GIS) and itscomponents are designed as a source of reference for answeringinquiries, for planning and for modeling. GIS is not intended, nor does itreplace legal description information in the chain of title and otherinformation contained in official government records such as the CountyClerk and Recorders office or the courts. In addition, the representationsof locations in this GIS cannot be substituted for actual legal surveys. Project Number: 014-3005 Drawn By: JWH Revision Date: 1/19/2015 Site Location Map Ursa Operating CompanyWatson Ranch BGarfield County, CO Sec 17, T7S, R95W, 6th PM Figure SL-1 0 1,000 2,000 Feet ¯ F: \ P r o j e c t s \ 0 1 4 - 3 0 0 5 \ G I S \ M X D \ S L - 1 S i t e L o c a t i o n M a p . m x d ")Watson Ranch B Pad Watson Ranch B Pad Area Section County Road Perennial Stream Intermittent Stream Ditch / Canal ") Ql LANDSL IDEDEPO SITS Tw o WASATCH FORMATION(INCLUDING FORTUNION EQUI VALENTAT BASE) AND OHIOCREEK FORMATION 20 17 Gardner Ln Fo u r C o r n e r R d Underwood Ln DISCLAIMER : This Geographic Information System (GIS) and itscomponents are designed as a source of reference for answeringinquiries, for planning and for modeling. GIS is not intended, nor does itreplace legal description information in the chain of title and otherinformation contained in official government records such as the CountyClerk and Recorders office or the courts. In addition, the representationsof locations in this GIS cannot be substituted for actual legal surveys. Project Number: 014-3005 Drawn By: JWH Revision Date: 12/26/2014 Geology Map Ursa Operating CompanyWatson Ranch BGarfield County, CO Sec 17, T7S, R95W, 6th PM Figure G-1 0 250 500 Feet ¯ F: \ P r o j e c t s \ 0 1 4 - 3 0 0 5 \ G I S \ M X D \ G - 1 S u r f i c i a l G e o l o g y M a p . m x d ")Watson Ranch B Pad Watson Ranch B Pad Area Section County Road Perennial Stream Intermittent Stream SBattlementPkwy Underwood Ln Gardner Ln F o u r C o r n e r R d O l d S t o n e Q u a r r y R d 56 58 55 500' 1,000' 1/4 Mile 1/2 Mile 33 Author: M. Spinelli 0 500 1,000Feet ± Revision: 2 Date: 1/5/2015 Notes / Comments:NRCS SOILS KEY: MAP SYMBOL SERIES NAME (Slope) 55 Potts loam (3-6% slopes) 58 Form 2A - Attachment HForm 2A - Attachment H NRCS Map Potts-Ildefonso complex (12-25%)39.43338 -108.02268Section 17, Township 7 South, Range 95 West Watson Ranch B56Potts loam (6-12% slopes) Proposed Pipeline Pipeline Tie-in Proposed Access ProposedDevelopment County Roads Local Roads 33 Ildefonso stony loam (6-25%) Attachment H – NRCS Soil Survey, Rifle Area Map Symbol 56 – Potts loam (6-12% slopes) Deep, well drained, moderately sloping soils found on mesas, benches and sides of valleys. Elevation 5,000 to 7,000 feet Average Annual Precipitation Approximately 14 inches Average Annual Air Temp Approximately 46 degrees F Frost Free Days Approximately 120 days Permeability Moderate Available Water Capacity High Effective Rooting Depth 60+ inches Surface Runoff Slow Erosion Hazard Moderate Native Vegetation: Mainly wheatgrass, needleandthread, and sagebrush. Development is limited by low strength and shrink-swell potential. This soil is in capability subclasses IIIe, irrigated and IVe, nonirrigated. Map Symbol 58 – Potts-Ildefonso complex (12-25% slopes) Strongly sloping to hilly soils found on mesas, alluvial fans, and sides of valleys. Elevation 5,000 to 6,500 feet Average Annual Precipitation Approximately 14 inches Average Annual Air Temp Approximately 46 degrees F Frost Free Days Approximately 120 days Permeability Moderate Available Water Capacity High Effective Rooting Depth 60+ inches Surface Runoff Medium Erosion Hazard Moderate Native Vegetation: Mainly wheatgrass, needleandthread, and sagebrush with additional pinyon, juniper, ricegrass, serviceberry, bitterbrush, and junegrass. Development is limited by steep slopes, runoff, gullying, and erosion. This complex is in capability subclass Vie, nonirrigated. !P !P !P !P !P !P !P !P !P !P !P !P !P !P !P !P !P !P !P!P !P !P !P !P!P !P !P !P !P!P !P !P!P !P !P !P !P !P !P !P !P !P !P 500' 1,000' 1/4 Mile 1/2 Mile SBattlementPkwy Underwood Ln Gardner Ln F o u r C o r n e r R d O l d S t o n e Q u a r r y R d 57701 93976 119545 63102 66636 64325 64327 64326 6120557520 51470 95280 92020 47521 57705 57704 57703 57702 56583 56582 56570 56566 52803 22935 264602 206247 119545 211946 206247 119549 Author: M. Spinelli 0 500 1,000Feet Notes / Comments: ±Revision: 1 Date: 11/19/2014 !? !PWater Well Spring Ditch Intermittent Stream Perennial Stream Water Body Watershed Form 2A - Attachment EForm 2A - Attachment EHydrology Map 39.43338 -108.02268Sections 17, Township 7 South, Range 95 West Watson Ranch B Yes - 729' No *Yes No No Yes - 139' No Groundwater Depth Approx. 90' Riparian Area No Wetland No Proposed Pipeline Pipeline Tie-in HYDROGRAPHY:FEATURE PRESENT WITHIN 1,000 ft Floodplain No Proposed Access ProposedDevelopment County Roads Local Roads *Irrigation ditches present on-site; absent from USGS National Hydrography Dataset. ") 07 19 07 08 20 17 18 7S 95W Colo r a d o R i v e r Gree n Mes a P l LarkspurPl Lodg e p o l e C i Sno w b e r r y Pl Locust Wy Cotto n w o o d Ct W i l l o w C r e e k T r Aster Ct WillowView Wy Pop p y C t Dogwood Ln Sage m o n t C i A l d e r C t S u m a c C t Willo w Cree k C t Ol d S t o n e Q u a r r y R d Mon u m e n t T r Stone Q u a r r y R d Holly Wy Lupine Ln Promo n t o r y P l Rosewood Wy Rive r View P l Grave l Pit R d Juniper Ln Si l v e r Qu e e n C i Northstar Tr Columb i n e L n Battle m e n t P y Spe n c e r P y Sipprelle Dr Riv e r B l u f f R d Underwood Ln Gardner Ln DISCLAIMER : This Geographic Information System (GIS) and itscomponents are designed as a source of reference for answeringinquiries, for planning and for modeling. GIS is not intended, nor does itreplace legal description information in the chain of title and otherinformation contained in official government records such as the CountyClerk and Recorders office or the courts. In addition, the representationsof locations in this GIS cannot be substituted for actual legal surveys. Project Number: 014-3005 Drawn By: JWH Revision Date: 12/26/2014 100/500 Year Floodplain Map Ursa Operating CompanyWatson Ranch BGarfield County, CO Sec 17, T7S, R95W, 6th PM Figure FP-1 0 250 500 Feet ¯ F: \ P r o j e c t s \ 0 1 4 - 3 0 0 5 \ G I S \ M X D \ F P - 1 F l o o d p l a i n M a p . m x d ")Watson Ranch B Pad Watson Ranch B Pad Area Township Section County Road Colorado River Perennial Stream Intermittent Stream 100/500 Year Combined Floodplain 4690 Table Mountain Drive, Suite 200 TEL 303.237.2072 Golden, CO 80403 FAX 303.237.2659 www.oaconsulting.com  March 12, 2015 Addendum to the Geologic and Natural Hazards Report – January 2015 Seismic Hazards Associated with the Ursa Operating Company, LLC Watson Ranch Class II Underground Injection Control Activity Olsson Project #014-3005 Olsson reviewed available published geologic reports and maps for the proposed Ursa Watson Ranch Class II Underground Injection Control (UIC) well. The proposed Watson Ranch B UIC well pad is located to the northeast of the town of Parachute, Colorado off of County Road 303. The site is located in the SE ¼ SW ¼ Section 17, T7S, R95W, 6th P.M. and is located in parcel # 240717300129. Injection Wells and Induced Seismicity Most earthquakes or seismic events occur as the result of natural geologic phenomena. There have been some cases where seismicity was suspected to have been triggered by injection of fluids into the subsurface. Induced seismicity is defined as a phenomenon caused by human activities, such as injecting waste water into UIC disposal wells, which results in a release of energy within the earth. Several investigations are underway to explore a potential link between seismicity to operation of a few of the nation’s approximately 30,000 Class II UIC wells used by the natural gas and oil industry to dispose of produced water or to enhance resource recovery. These Class II injection wells are a subset of more than 800,000 injection wells nationwide that handle a variety of industrial wastes and the development of various minerals and geothermal energy sources (API, 2012). Underground Injection Control Regulation The U.S. Environmental Protection Agency (EPA) regulates the UIC program and the injection of fluids related to oil and gas production as Class II disposal wells for the protection of underground sources of drinking water (USDWs). In many cases, the EPA delegated authority to implement the UIC program to the states, with 39 states having primary authority over 95 percent of all UIC Class II wells. The EPA delegated primacy for regulation of Class II UIC wells to the State of Colorado in April 1984. Class II UIC wells inject fluids associated with oil and natural gas production. Most of the injected fluid is salt water, or brine, naturally present in the formation, produced along with the oil and gas and is injected into a deep disposal well into a formation that contains brine with similar or more saline water quality characteristics. Underground Injection Control and Seismicity in Colorado The Colorado Oil and Gas Conservation Commission (COGCC) is the agency in Colorado with primacy for permitting Class II UIC wells associated with oil and gas production operations. The COGCC regulates operators of Class II UIC wells in accordance with federal law and COGCC’s 2 Ursa Operating Company, LLC Olsson Associates Watson Ranch Class II UIC Well Golden, Colorado March 2015 Olsson Project #014-3005 rules and policies which are in place to reduce the likelihood of induced seismicity. The current safeguards defined by the COGCC permit process include limits on injection volume at pressures below the fracture gradient. The permit process also involves input from the Colorado Division of Water Resources (CDWR), the Colorado Geological Survey (CGS), the Colorado Department of Public Health and Environment (CDPHE), and EPA Region 8 UIC program in Denver. The COGCC requires Class II UIC wells be properly constructed with cemented surface casing and production casing to isolate and prevent fluid flow between the injection zones and USDWs. The COGCC UIC engineer reviews all relevant information including hydrogeologic studies, CDWR water well information, COGCC geophysical well logs from area production wells. The COGCC UIC engineer also reviews information on the specific formation and well construction data submitted by the operator, including resistivity, cement bond, and geophysical logs to verify that 1) the surface casing is set below the fresh water zones used as a water supply, and 2) production casing and cement placement and quality adequately isolate the injection zone and USDWs including fresh water zones that are not currently used as water supplies. The COGCC requires mechanical integrity tests (MIT) be performed on the injection wells every five years. The maximum surface injection pressure is calculated based on a default fracture pressure gradient of 0.6 pounds per square inch (psi) per foot of depth. The operator may conduct a State Rate Injection Test to define whether a higher injection zone fracture gradient exists. The COGCC UIC engineer designates a maximum surface injection pressure as a condition of permit approval. It is the COGCC’s policy to keep injection pressures below the fracture gradient, which is defined for each injection well, in order to minimize the potential for seismic events related to fluid injection. Mitigation and Minimization of Injection-Induced Seismicity Injection-induced seismic events have the potential to impact USDWs. The EPA’s UIC program has undertaken investigation of a number of recent small to moderate magnitude seismic events recorded in areas with Class II disposal wells related to unconventional hydrocarbon production. The EPA’s Office of Ground Water and Drinking Water (OGWDW) Drinking Water Protection Division requested that the UIC national Technical Workgroup (NTW) develop recommendations for consideration by UIC regulators. The UIC NTW consists of UIC staff from each EPA regional office, EPA headquarters, and six state UIC program representatives. In June 2011, a subgroup was formed to develop a report of recommending possible strategies for managing or minimizing significant seismic events associated with induced seismicity in the context of Class II disposal well operations. Unconventional production activities and larger volumes of waste water have created a need for increased disposal capacity, and the permitting of new disposal wells to handle large volumes of produced water and other exploration and production related waste water. Of the 30,000 Class II UIC disposal wells, very few have produced seismic events with magnitudes greater than M4.0. In addition, the EPA is unaware of any USDW contamination resulting from seismic events related to injection-induced seismicity (UIC-NTW, 2014). The NTW identified three key components that are thought to contribute to injection-induced seismicity: 1) the presence of a stressed fault, 2) pressure buildup from disposal operations, and 3) a pathway for the increased pressure to communicate from the disposal well to the fault. The NTW used a strategy that summarized geoscience factors and applications, applied petroleum engineering methods, compiled and reviewed historic and current scientific literature from 3 Ursa Operating Company, LLC Olsson Associates Watson Ranch Class II UIC Well Golden, Colorado March 2015 Olsson Project #014-3005 ongoing projects and materials associated with injection-induced seismicity, and selected case examples of Class II brine disposal wells suspected of inducing seismicity in different areas of the country. According to the NTW report, a fault of concern is a fault optimally oriented for movement and located in a critically stressed region. The fault is also of sufficient size, possesses sufficient accumulated stress/strain, such that fault slip and movement has the potential to cause a significant earthquake. A fault may consist of a single fault or a fault zone comprised of multiple faults and fractures. Structural Geology The Watson Ranch UIC well site is located in an area on the southern margin of the Piceance Basin. The Piceance Basin is a broad structural and depositional basin trending northwest, that formed during Late Cretaceous time. The sedimentary rocks gently dip between 2° to 5° northward into the center of the basin. The surface geology of the site area consists of unconsolidated Quaternary age deposits. These deposits are typically several tens of feet thick, and total thickness may be as much as 150 feet thick. These unconsolidated sediments obscure fractures and faults in the bedrock in the area; however, no there are no known major faults mapped in the area of the site. Regionally within the Piceance Basin there are faults that trend to the northwest. There are several northwest-trending faults present on the north side of Plateau Creek to the south of Battlement Mesa and north of the Grand Mesa. These faults cut rocks as young as the upper Wasatch and possess throws of less than 150 feet. Small recent fractures in the basalt capping Grand Mesa are a result of landslide activity and do not extend far below the base of the basalt (Yeend, 1969). Recent seismic data for the area near Rifle suggests that monoclines, such as the Grand Hogback, and similar monoclines in the Rocky Mountain foreland near the boundary with the Colorado Plateau, overlie a west-, southwest-, or south-directed thrust system. The Grand Hogback is interpreted as having formed above the tip of a Precambrian basement rock wedge blind thrust fault that moved southwest and west-southwest into the Piceance Basin. The Divide Creek Anticline and the Wolf Creek Anticline, located to the west of the Grand Hogback, are thought to be related to this same thrust system (Grout and Verbeek, 1992). These faults were active when the Colorado Plateau and Rocky Mountains were being uplifted during the Laramide orogeny during the late Cretaceous period. Northwestward-trending faults with displacements large enough to be shown on areal geologic maps are not common in the area; none have displacements exceeding 150 feet, and none were traced for more than a mile. The faults of this set are uniform in strike direction, but some appear to have had complex zones of movement and jointing rather than simple displacement (Fischer, 1960). The largest fault in the Rifle area, trends slightly north of west, nearly parallel to regional strike. The strike refers to the attitude or position of linear features such as faults, outcrops, beds, joints, and folds. In this case the regional strike is controlled by the structural orientation of the Piceance Basin. The maximum displacement along this fault is about 500 feet observed in the southern part of Section 34, Township 4 South, Range 92 West, and was mapped for about six miles in the area (Fischer, 1960). As many as 30 faults are described in the area of the Grand Hogback west of Glenwood Springs. These faults consist of a series of parallel, northwest trending, west dipping, normal 4 Ursa Operating Company, LLC Olsson Associates Watson Ranch Class II UIC Well Golden, Colorado March 2015 Olsson Project #014-3005 faults that have broken the basalt cap and basalt gravels. The offset Quaternary basalt gravels indicate possible recent movement, but due to the nature of deformation, large earthquakes caused by the process would seem unlikely (Kirkham and Rogers, 1978). The structural geology of the Roan Plateau area to the north of the site and on the southwestern flank of the Piceance Basin is fairly simple. The deepest part of the basin is about 18,000 feet below sea level and lies about 18 miles to the north of the Roan Plateau. The depth to the Precambrian basement within the area increases from about 7,500 feet below sea level at the southwestern corner of the area to about 14,000 feet below sea level along the northern boundary of the area (Hail, 1992). There are no major faults in the central Roan Plateau area. Three narrow grabens are present along a northwest-trending fracture zone to the north of the Crystal Creek anticline in the central part of Township 4 South, Range 96 West, and Township 4 South, Range 97 West. Maximum measured stratigraphic displacements on these faults do not exceed 120 feet; most are considerably less. These grabens are thought to lie along a single fracture zone that extends for a total distance of about 9 miles (Hail, 1992). Colorado Geological Survey Earthquake and Late Cenozoic Fault Map According to the Colorado Geologic Survey most people are surprised to learn that natural earthquakes do occur in Colorado. The largest known earthquake Colorado experienced was a magnitude 6.6 earthquake in November 1882 in north-central Colorado. Natural earthquakes can be triggered by movements along faults, by rock fall, or subsidence resulting from the collapse of underground mines. Uplift of the Colorado Rocky Mountains and Colorado Plateau, and the creation of the Piceance Basin, occurred as a result of tectonic activity and movement along faults during the Late Cretaceous and early Tertiary geologic periods. The 2014 USGS National Seismic Hazard Maps display earthquake ground motions for various probability levels across the United States. The maps show the Parachute – Battlement Mesa area as having 0.03 to 0.05 peak ground acceleration, expressed as a fraction of standard gravity (g), with a ten-percent probability of exceedance in 50 years. Maps prepared by the USGS and the Colorado Geologic Survey do not show any Quaternary faults in the Parachute – Battlement Mesa area. The only seismic event shown on the Colorado Geologic Survey Earthquake and Late Cenozoic Fault and Fold Map Server in close proximity to the site is related to the Atomic Energy Commission’s Project Rulison in September 1969. Project Rulison was an induced seismic event resulting from the detonation of an underground nuclear device to stimulate natural gas production from tight sands at a depth of 8,426 feet. It had a magnitude of 5.3 on the Richter scale. Another underground nuclear detonation induced seismic event took place at the Rio Blanco test site in Rio Blanco County northwest of Rifle, Colorado in May 1973. The Rio Blanco test involved simultaneous detonation of three 33-kiloton nuclear devices and was also designed to stimulate natural gas production from tight gas sands. The event had a magnitude of 5.4 on the Richter scale. Two 2.9 magnitude quakes occurred near Douglas Pass including one on March 8, 1994, and another 2.9 magnitude earthquake that occurred on March 19, 2002. These earthquakes appear to be the result of natural causes and are not related to injection of fluids. Earthquakes have been recorded in eastern Garfield County. The area of New Castle has experienced earthquakes with one reported on December 21, 1906, and two recorded in late December 1920. These are taken from newspaper accounts at the time and are described as 5 Ursa Operating Company, LLC Olsson Associates Watson Ranch Class II UIC Well Golden, Colorado March 2015 Olsson Project #014-3005 ‘felt reports’ meaning that they were taken from personal accounts at the time. These earthquakes were assigned an intensity of III and V, respectively, on the Mercalli scale based on the described damage. More recently earthquakes have been recorded in the New Castle area including two in October 1990 with magnitude of 2.1 and 2.3 on the Richter scale, and another on December 12, 1990 with a magnitude of 2.7 on the Richter scale. A 4.3 magnitude earthquake occurred near Glenwood Springs in January 1971; a 2.2 magnitude earthquake occurred north of Glenwood Springs on August 10, 2001; and another 3.8 magnitude earthquake occurred five miles west of Glenwood Springs on February 8, 2006. A 2.5 magnitude earthquake was recorded on July 9, 2009 near Palisade in Mesa County. An earthquake occurred north of Grand Junction on January 30, 1975 and had a magnitude of 4.4 on the Richter scale and was felt as far away as the towns of DeBeque and Delta. Colorado is well known in earthquake literature for a swarm of earthquakes that occurred in the 1960s and were linked to operation of a deep chemical waste injection well by the Army Corps of Engineers at the Rocky Mountain Arsenal near Denver, Colorado. Studies have also been conducted in Colorado to control seismic activity by monitoring fluid pressures and the quantities of fluid injected. Summary The COGCC and EPA have safe guards in place to prevent injection induced seismic events from occurring. The Class II UIC well must be constructed to prevent communication between the disposal zone and overlying fresh water zones. The Class II UIC well must pass a mechanical integrity test and must be re-tested every five years. The injected volumes and maximum surface pressures recorded in the permit are designed to be below the fracture pressure gradient. There are no mapped or known major faults in the area. Most of the northwest trending fault traces that have been mapped in the region show limited displacement of 150 feet and are not laterally extensive. There are relatively few recorded earthquakes in the area of the site, as shown on the Colorado Geologic Survey Earthquake and Fault Map server. The closest seismicity events are related to the detonation of subsurface nuclear devices in the late 1960s and early 1970s. The sedimentary rock in the formation used for disposal would have to be isolated from shallow fresh water supplies and demonstration of this is required in the permitting process. For injection induced-seismicity to occur, there would have to be a connection from the injection zone formation to a stressed fault. OLSSON ASSOCIATES James W. Hix Senior Geologist 6 Ursa Operating Company, LLC Olsson Associates Watson Ranch Class II UIC Well Golden, Colorado March 2015 Olsson Project #014-3005 References Blume F., and Sheehan, A.F., 2003, Quantifying Seismic Hazard in the Southern Rocky Mountains Through GPS Measurements of Crustal Deformation, University of Colorado, Boulder, Department of Geological Sciences, 9 p. Fischer, R.P., 1960, Vanadium-Uranium Deposits of the Rifle Creek Area, Garfield County, Colorado, USGS Bulletin 1101, 52 p. and 4 plates Grout M.A., and Verbeek, E.R., 1992, Fracture History of the Divide Creek and Wolf Creek Anticlines and Its Relation to Laramide Basin-Margin Tectonism, Southern Piceance Basin, Northwestern, Colorado, USGS Bulletin 1787, Z32 p. Hail, W.J., Jr., 1992, Geology of the Central Roan Plateau Area, Northwestern Colorado, USGS Bulletin 1787, R24 p., 2 plates, 8 figures Kirkham, R.M. and Rogers, W.P., 1978, Earthquake Potential in Colorado, a Preliminary Evaluation, Colorado Geological Survey Open File Report 78-3, 211 p. McClain, W.C., 1970, On Earthquakes Induced by Underground Fluid Injection, Oak Ridge National Laboratory, Union Carbide Corporation for the U.S. Atomic Energy Commission, 22 p. Oaks S.D., and Kirkham, R.M., 1986, Results of a Search for Felt Reports for Selected Colorado Earthquakes, Colorado Geological Survey, Information Series 23, 89 p. Yeend, W.E., 1969, Quaternary Geology of the Grand and Battlement Mesas Area, Colorado, USGS Professional Paper 617, 50 p. and 1 plate API Document, 2012, Injection Wells & Induced Seismicity, 2 p. COGCC, January 19, 2011, COGCC Underground Injection Control and Seismicity in Colorado, 5 p. U.S. EPA Underground Injection Control National Technical Working Group, Revised November 12, 2014, Minimizing and Managing Potential Impacts of Injection-Induced Seismicity from Class II Disposal Wells: Practical Approaches, 415 p. Internet Websites Colorado Geological Survey http://coloradogeologicalsurvey.org/geologic-hazards/earthquakes-2/ USGS Earthquake Hazards Program http://earthquake.usgs.gov/hazards/products/conterminous/index.php#2014 Article 4-203.G.6 Wildlife and Vegetation Impact Analysis Ursa Operating Company LLC Watson Ranch B Injection Well OA Project No. 014-3005 URSA OPERATING COMPANY, LLC. WATSON RANCH B PAD UNDERGROUND INJECTION CONTROL Impact Analysis: Section 4-203-G (6) – Environmental Impacts Garfield County Land Use and Development Code Cover photo: View of proposed Watson Ranch B Pad UIC location. Prepared for: Ursa Operating Company, LLC. Prepared by: WestWater Engineering 2516 Foresight Circle #1 Grand Junction, CO 81505 In cooperation with: Olsson Associates, Inc. Nicholas Jaramillo, Biologist/Environmental Scientist DECEMBER 2014 WestWater Engineering Page 1 of 12 December 2014 INTRODUCTION Project Description At the request of Olsson Associates, Inc. (Olsson), on behalf of Ursa Operating Company, LLC. (Ursa), WestWater Engineering (WestWater) has prepared this Garfield County Impact Analysis for the proposed Watson Ranch B Pad Underground Injection Control (UIC) project. The proposed injection well would be located on a site that is currently used for agriculture and native vegetation communities have been altered from their natural state. This project would be located on private lands in Section 17, Township 7 South, Range 95 West, Sixth Principal Meridian in Garfield County, Colorado (Figure 1). The current primary uses of the project area are rural residential, irrigated pasture, livestock grazing, natural gas development, and wildlife habitat. This document reports the results and analysis of findings pertinent to the Garfield County Land Use and Development Code (amended November 12, 2013) as they apply to this project. Survey Methods The project area was evaluated for the potential occurrence of special status plants and wildlife, raptors, noxious weeds, and potential Army Corps of Engineers jurisdictional Waters of the U.S. by WestWater biologists on December 3, 2014. The survey took place outside the active growth period for plants in the project area. The survey also took place outside the active nesting season for migratory birds and raptors in the project area. Based on existing survey data, literature review, firsthand knowledge, and experience with biological resources in the geographical area, WestWater biologists have made assertions regarding the plant and animal species which may or may not be present in the project area. Vegetation communities were determined through aerial photography, on-the-ground assessments, and WestWater’s previous experience in the project area. Plant species occurrence and identification was aided by using pertinent published field guides (Spackman et al. 1997, Kershaw et al. 1998, Whitson et al. 2001, CWMA 2007, Weber and Wittmann 2012). Mapped soil types, as published by the Natural Resources Conservation Service (NRCS), U.S. Department of Agriculture (USDA), were reviewed to determine the soil types and expected natural vegetation characteristics at the project site (NRCS 2014). Raptor and special status wildlife species surveys were conducted on foot within 0.25 miles of project features within suitable habitats for these species. Noxious weed conditions are reported in an Integrated Vegetation and Noxious Weed Management Plan (IVNWMP) that was prepared separately for this project (WestWater 2014). Data locations were recorded using handheld Global Positioning System (GPS) units (Datum: NAD83, Zone 12) and photographs were taken of the habitat, terrain, and biological features found during the survey. SECTION 4-203-G (6) - ENVIRONMENTAL IMPACTS EXISTING ENVIRONMENTAL CONDITIONS WATERS OF THE U.S. – Army Corps of Engineers (ACOE) The proposed injection well is planned to be built in an irrigated pasture and approximately 6.85 acres of surface disturbance would be required. WestWater biologists determined that one natural drainage and several irrigation ditches would be affected (Table 1, Figure 1). No ACOE jurisdictional wetlands would be affected by the project. Table 1. Potential ACOE Jurisdictional Waters of the U.S. Label Easting Northing Comments WOUS-1 756361 4369166 Irrigation ditch. OHWM is 6" deep and 1' wide. WOUS-2 756395 4369099 Historic irrigation ditch. No obvious OHWM. WestWater Engineering Page 2 of 12 December 2014 Table 1. Potential ACOE Jurisdictional Waters of the U.S. Label Easting Northing Comments WOUS-3 756371 4369154 Natural drainage. No OHWM. WOUS-4 756401 4369129 Irrigation ditch. OHWM is 6" deep and 1' wide. WOUS-5 756390 4369087 Irrigation ditch. OHWM is 8" deep and 1.5' wide. WOUS-6 756200 4369026 Historic irrigation ditch. No OHWM. VEGETATION The pad where the injection well would be located would require approximately 6.85 acres of surface disturbance and vegetation removal. The affected area is primarily composed of grasses planted for hay production and livestock pasture, including crested wheatgrass (Agropyron cristatum), smooth brome (Bromus inermis), orchardgrass (Dactylis glomerata), timothy grass (Phleum pratense), and several additional species. Native vegetation surrounding the site is consistent with sagebrush communities and pinyon-juniper woodlands that occur in the Colorado River valley corridor. Vegetation is dominated by a mixture of mountain big sagebrush (Artemisia tridentata vaseyana), Gambel oak (Quercus gambelii), and pinyon- juniper (Pinus edulis – Juniperus osteosperma). A variety of grasses and forbs are distributed throughout the understory. A few common species include various wheatgrass species (Elymus and Pascopyrum spp.), bluegrass (Poa spp.), dandelion (Taraxacum spp.), and prickly pear (Opuntia spp.). Threatened and Endangered Plant Species The occurrence and distribution of special status plants in this region are strongly influenced by elevation, hydrology, geologic formations, and soil characteristics present in an area. Threatened and endangered plants known to occur in Garfield County are listed in Table 2 (USFWS 2014). Table 2. Special status plants occurring in Garfield County. Common Name Scientific Name Listing Status Colorado hookless cactus Sclerocactus glaucus Threatened DeBeque phacelia Phacelia submutica Threatened Parachute beardtongue Penstemon debilis Threatened Ute ladies’-tresses orchid Spiranthes diluvialis Threatened The area immediately surrounding the proposed Watson Ranch B Pad UIC site consists of pinyon-juniper woodlands and sagebrush shrublands. The habitat may be suitable for Colorado hookless cactus, but none were observed and this species is not known to occur nearby. Due to soil composition, elevation, previous disturbances, and hydrology patterns the site is unlikely to provide suitable habitat for any other special status plant species in this region. A review of the Colorado Rare Plant Field Guide (Spackman et. al. 1997) and WestWater’s database confirms that no known populations of special status plants occur nearby. Noxious Weeds Noxious weed infestations, control techniques, and revegetation recommendations are reported in an IVNWMP that was prepared for this project (WestWater 2014). Noxious weed species listed by the State of Colorado (2005) detected in or near the project area included Canada thistle (Cirsium arvense), cheatgrass (Bromus tectorum), chicory (Cichorium intybus), common burdock (Arctium minus), common mullein (Verbascum thapsus), field bindweed (Convolvulus arvensis), musk thistle (Carduus nutans), redstem filaree (Erodium cicutarium), and Russian knapweed (Acroptilon repens). WestWater Engineering Page 3 of 12 December 2014 Several unlisted nuisance weed species that are present in disturbed areas include flixweed (Descurania sophia), kochia (Bassia scoparia), Russian thistle (Salsola spp.), tumble mustard (Sisymbrium altissimum), and yellow sweet clover (Melilotus officinalis). WILDLIFE Threatened, Endangered, and Candidate Wildlife Species The project area was evaluated for threatened, endangered, or sensitive wildlife species listed in Garfield County (Table 3) (USFWS 2014). Table 3. Federal Threatened, Endangered, and Candidate Wildlife Species for Garfield County. Common Name Scientific Name Status Bonytail Gila elegans Endangered Canada lynx Lynx canadensis Threatened Colorado pikeminnow Ptychocheilus lucius Endangered Greater Sage-grouse Centrocercus urophasianus Candidate Greenback cutthroat trout* Oncorhynchus clarki stomias Threatened Humpback chub Gila cypha Endangered Mexican spotted owl Strix occidentalis lucida Threatened Razorback sucker Xyrauchen texanus Endangered Yellow-billed cuckoo Coccyzus americanus Threatened Bold = Species which may be affected by project. * Recent genetic studies indicate that pure greenback cutthroat trout likely do not exist in western Colorado. Until the review and rulemaking process is complete, the U.S. Fish and Wildlife Service is recommending that “Lineage GB” cutthroat trout , which do exist in western Colorado, be managed as greenback cutthroat (USFWS 2012) Designated critical habitat for two endangered fish species (Colorado pikeminnow and razorback sucker) occurs in the Colorado River downstream of the project and these species have been documented near Parachute (Maddux et al. 1993). Designated critical habitat for two additional species (bonytail and humpback chub) occurs downstream of the project near Grand Junction (Maddux et al. 1993). No other species listed in Table 3 would be affected, as habitat conditions are not appropriate. Raptors At least fifteen raptor species may be found in suitable habitats in the region (Table 4). Nesting season for raptor species in this area takes place from January through mid-August. The most common raptor species observed in the area include American Kestrel, Cooper’s Hawk, Golden Eagle, Great Horned Owl, and Red-tailed Hawk. Bald Eagles are common near the Colorado River and forage near Battlement Mesa. Table 4. Raptor species that may occur near the project area. Common Name Scientific Name BCC* American Kestrel Falco sparverius No Bald Eagle§ Haliaeetus leucocephalus Yes Cooper’s Hawk Accipiter cooperii No Flammulated Owl Otus flammeolus Yes Golden Eagle Aquila chrysaetos Yes Great Horned Owl Bubo virginianus No Long-eared Owl Asio otus No Northern Harrier Circus cyaneus No Northern Pygmy Owl Glaucidium gnoma No WestWater Engineering Page 4 of 12 December 2014 Table 4. Raptor species that may occur near the project area. Common Name Scientific Name BCC* Northern Saw-whet Owl Aegolius acadicus No Peregrine Falcon+§ Falco peregrines Yes Prairie Falcon Falco mexicanus Yes Red-tailed Hawk Buteo jamaicensis No Sharp-shinned Hawk Accipiter striatus No Swainson’s Hawk Buteo swainsoni No *BCC=U.S. Fish and Wildlife Service, Bird of Conservation Concern (USFWS 2008) + State species of concern (CPW 2014a) §BLM sensitive species (BLM 2009) No raptor nests were detected within 0.25 miles of the proposed injection well and what little suitable nesting habitat exists is composed of scattered cottonwood trees and Gambel oak. Birds of Conservation Concern, Migratory, and Non-migratory Birds (other than raptors) WestWater biologists evaluated the project area for migratory bird species that could be affected by the project. Birds of Conservation Concern (BCC) have been identified by the U.S. Fish and Wildlife Service (USFWS) for priority conservation management in an attempt to prevent the listing of additional species under the Endangered Species Act (USFWS 2008). A thorough literature review was conducted to identify BCC species with potential to occur during other times of the year (Table 5) (Andrews & Righter 1992, Kingery 1998, Righter et al. 2004). Table 5. BCC species that may occur in the project area. Common Name Scientific Name Status Habitat Description Potential to Occur Brewer’s Sparrow Spizella breweri BCC/BLM* Expansive sagebrush shrublands; occasionally found in greasewood or other shrublands. Likely to occur in sagebrush shrublands near the project area. Cassin’s Finch Carpodacus cassinii BCC May occur in pinyon-juniper woodlands and riparian cottonwood. May occur in pinyon- juniper habitat near the project area. Gray Vireo Vireo vicinior BCC Mature pinyon-juniper woodlands. May occur in pinyon- juniper habitat near the project area. Juniper Titmouse Baeolophus griseus BCC Pinyon-juniper woodlands. Likely to occur in pinyon-juniper habitat near the project area. Lewis’s Woodpecker Melanerpes lewis BCC Pinyon-juniper woodlands and riparian cottonwoods. May occur in pinyon- juniper or ripiarian habitats near the project area. Pinyon Jay Gymnorhinus cyanocephalus BCC Pinyon-juniper woodlands. Likely to occur in pinyon-juniper woodlands. * BLM sensitive species (BLM 2009) U.S. Fish and Wildlife Service guidance indicates that developments may potentially affect nesting migratory birds within 100 feet of a project. The survey was conducted in late fall, outside the nesting WestWater Engineering Page 5 of 12 December 2014 season and at a time when most neo-tropical migrant bird species would not be expected to occupy the area. Black-billed Magpie and Horned Lark were observed during surveys. American Elk and Mule Deer The site is located in CPW Game Management Unit 42. The project is within CPW mapped mule deer severe winter range and a winter concentration area (CPW 2014b) (Figure 2). The site is located within a mapped elk winter concentration area (Figure 3). Both species utilize the area extensively throughout the winter. Mule deer sign was observed during the survey. Black Bear and Mountain Lion CPW mapping shows the project area to be within overall range for black bear and mountain lion and both species are known to occur nearby (CPW 2014b). The project area is mapped by CPW as a potential mountain lion/human conflict area and also a mapped black bear/human conflict area (Figure 4). Bears could occur in the area almost year round with the exception of the hibernation period occurring from late fall through late spring. At times when foraging is difficult bears become more visible as they are more likely to utilize unnatural food sources created by humans. Mountain lions likely inhabit the general project area primarily during the winter months as they follow migrating big game herds, but could be found year-round. Lions tend to have large territories and are highly mobile as they search for food or new territories so sightings tend to be uncommon. Small Mammals Common small mammal species in the project area include coyote (Canis latrans), cottontail (Sylvilagus nuttallii), least chipmunk (Tamias minimus), and a multitude of rodent species. Reptiles Bull snake (Pituophis catenifer), collared lizard (Crotaphytus collaris), plateau striped whiptail (Cnemidophorus velox), racer (Coluber constrictor), sagebrush lizard (Sceloporus graciousus), short- horned lizard (Phrynosoma hernandesi), western terrestrial garter snake (Thamnophis elegans), and midget faded rattlesnake (Crotalus viridis concolor) are reptiles potentially occurring in the project area (Hammerson 1999). No reptiles were observed during surveys, as the site visit took place in late autumn. Other than the midget faded rattlesnake, which is a BLM sensitive and State species of concern (BLM 2009, CPW 2014a), these species do not have any special protection. Aquatic Species There are no permanent water sources and no aquatic species would occupy the project area. Stormwater runoff from the site could impact aquatic habitats downstream. SECTION 4-203-G (6) (a) - DETERMINATION OF LONG AND SHORT-TERM EFFECTS ON FLORA AND FAUNA FLORA The injection well would be placed in a hay field and very little additional native vegetation would be removed for construction. No special status plants occurrences are known to exist nearby. Noxious weeds occurring in the area are discussed in an accompanying IVNWMP prepared by WestWater for this project (WestWater 2014). Dry Hollow Water Facility Facility WestWater Engineering Page 6 of 12 December 2014 FAUNA Colorado River Endangered Fishes Designated critical habitat for two endangered fish species (Colorado pikeminnow and razorback sucker) occurs in the Colorado River downstream of the project and critical habitat for two additional species (bonytail and humpback chub) occurs downstream of the project near Grand Junction (Maddux et al. 1993). Colorado pikeminnow and razorback sucker have been documented in the river upstream as far as Rifle (W. R. Elmblad, retired CPW fisheries biologist, pers. comm.). Potential impacts would be limited to runoff from storms or snowmelt that carry increased sediment loads or pollutants from the pad to the river. Implementation of a Spill Prevention, Control, and Countermeasure Plan (SPCC), a Stormwater Management Plan (SWMP), and Best Management Practices (BMPs) associated with this type of project will provide a good degree of mitigation for any potential impacts. There would be no anticipated depletions that could affect aquatic species associated with the project. Raptors No raptor nesting habitat will be directly affected by the project. The primary potential long term effect would be the loss of foraging habitat within the footprint of the proposed pad. Short-term effects could include temporary displacement of raptors in an avoidance area surrounding the pad due to increased human presence and equipment associated with construction, operation, and maintenance of the facility. American Elk and Mule Deer Approximately 6.85 acres of foraging habitat will be lost from development of the pad where the injection well will be placed. No migration corridors are affected. Human presence and activity may affect animal distribution by creating avoidance areas and increasing stress on wintering big game. This project will contribute to the cumulative effects of habitat alteration and increased development in the area. An increase in vehicle traffic could result in additional vehicle related wildlife mortality, although additional traffic resulting from this project would contribute minimally, given current traffic volumes on the existing county road. Fences can pose an increased risk to big game and any fencing around the facility should be constructed according to published standards that reduce impacts to big game (Hanophy 2009). Black Bear and Mountain Lion Potential encounters between bears and personnel could occur if garbage or food is available on the site. Mountain lions are occasionally observed in the area, but generally avoid human contact. Incidences of human and bear/lion interactions sometimes result in the euthanasia of offending animals by the CPW. Small Mammals, Birds (BCC), and Reptiles The vegetation removal required for development of this project will reduce the habitat available for small mammals and birds. The vegetation on the site provides nesting cover for ground nesting species, though very little nesting habitat for other birds will be lost and the habitat is primarily valuable for foraging. Human presence and activity may affect animal distribution. An increase in traffic could result in vehicle related mortalities. SECTION 4-203-G (6) (b) – DETERMINATION OF THE EFFECT ON DESIGNATED ENVIRONMENTAL RESOURCES Development of this project will result in additional contributions to the cumulative effects of habitat alteration and fragmentation in the region, although development of the project is not expected to significantly affect any critical environmental resources. WestWater Engineering Page 7 of 12 December 2014 SECTION 4-203-G (6) (c) – IMPACTS ON WILDLIFE AND DOMESTIC ANIMALS  Creation of hazardous conditions: Some passerine bird species and small mammals may choose to inhabit or nest on equipment or objects at the site. The inherent risks associated with these structures are low. By closing or covering all ports, hatches, cavities, and openings (such as the ends of pipes) this potential is decreased. Most non-game bird species and their nests are protected under the Migratory Bird Treaty Act (16 U.S.C. 703-712; Ch. 128; July 13, 1918; 40 Stat. 755) and damaging occupied nests could be considered a “take” resulting in a violation. Livestock and big game will likely avoid the project site.  Indirect Construction Effects: Additional human presence and activity related to construction, operation, and maintenance of an injection well may influence spatial and temporal use of habitat surrounding the project by wildlife. Since the site exists adjacent to significant and long-term human presence, the additional disturbance from this project is expected to be low.  Road-kill: Speed limits are set low and most wildlife in the area has become habituated to vehicle traffic. The potential for vehicle related mortalities related to this project should be low. REFERENCES Andrews, R., and R. Righter. 1992. Colorado Birds: A Reference to Their Distribution and Habitat. Denver Museum of Natural History. Denver. BLM. 2009. BLM Colorado State Director’s Sensitive Species List. November 20, 2009 Update. CPW. 2014a. State of Colorado species of concern list. Available online: http://wildlife.state.co.us/WildlifeSpecies/SpeciesOfConcern/Pages/SpeciesOfConcern1.aspx Accessed December 3, 2014. CPW. 2014b. All species activity mapping data. Available online: http://www.arcgis.com/home/item.html?id=190573c5aba643a0bc058e6f7f0510b7 Accessed December 3, 2014. CWMA. 2007. S. Anthony, T. D’Amato, A. Doran, S. Elzinga, J. Powell, I. Schonle, K. Uhing. Noxious Weeds of Colorado, Ninth Edition. Colorado Weed Management Association, Centennial. Hammerson, G. A. 1999. Amphibians and Reptiles in Colorado, Second Edition. Colorado Division of Wildlife, Denver. Hanophy, W. 2009. Fencing with Wildlife in Mind. Colorado Division of Wildlife. Denver. Available online: http://wildlife.state.co.us/SiteCollectionDocuments/DOW/LandWater/PrivateLandPrograms/DO WFencingWithWildlifeInMind.pdf Kershaw, L., A. MacKinnon, and J. Pojar. 1998. Plants of the Rocky Mountains. Lone Pine Publishing, Auburn, Washington. Kingery, H. E. 1998. Colorado Breeding Bird Atlas. Colorado Bird Atlas Partnership, Colorado Division of Wildlife, Denver. Maddux, H., L. Fitzpatrick, and W. Noonan. 1993. Colorado River Endangered Fishes Critical Habitat. Biological Support Document. U.S. Fish and Wildlife Service, Utah/Colorado Field Office, Salt Lake City, Utah, 225 pp. NRCS. 2014. Web Soil Survey, U.S. Department of Agriculture, Natural Resource Conservation Service, Available online: http://websoilsurvey.nrcs.usda.gov. Accessed March 14, 2013. WestWater Engineering Page 8 of 12 December 2014 Righter, R., R. Levad, C. Dexter, and K. Potter. 2004. Birds of Western Colorado Plateau and Mesa Country. Grand Valley Audubon Society, Grand Junction. Spackman, S., B. Jennings, J. Coles, C. Dawson, M. Minton, A. Kratz, and C. Spurrier. 1997. Colorado Rare Plant Field Guide. Prepared for the Bureau of Land Management, the U.S. Forest Service, and U.S. Fish and Wildlife Service by the Colorado Natural Heritage Program. State of Colorado. 2005. Rules pertaining to the administration and enforcement of the Colorado Noxious Weed Act, 35-5-1-119, C.R.S. 2003. Department of Agriculture, Plant Industry Division, Denver, 78 p. USFWS. 2008. Birds of Conservation Concern 2008. U.S. Fish and Wildlife Service, Division of Migratory Bird Management, U.S. Fish and Wildlife Service, Arlington, Virginia. USFWS. 2012. Updated position paper on ESA consultations on greenback cutthroat trout, including the cutthroat trout referred to as Lineage GB. Updated Oct 4, 2012. USFWS. 2014. U.S. Fish and Wildlife Service Endangered Species List for the State of Colorado. Available online: http://ecos.fws.gov/tess_public/pub/stateListingAndOccurrenceIndividual.jsp?state=CO. Accessed December 3, 2014. Weber, W. A., and R. C. Wittmann. 2012. Colorado Flora, Western Slope. Fourth Edition, University Press of Colorado, Boulder. WestWater. 2014. Integrated vegetation and noxious weed management plan for Ursa Operating Company, LLC’s proposed Watson Ranch B Pad UIC. Grand Junction. Whitson, T. D. (editor), L. C. Burrill, S. A. Dewey, D. W. Cudney, B. E. Nelson, R. D. Lee and R. Parker. 2001. Weeds of the West – 9th edition. Western Society of Weed Science in cooperation with Cooperative Extension Services, University of Wyoming, Laramie WestWater Engineering Page 1 of 12 December 2014 -$-Potential Waters of the US c:::J 100 Foot Weeds Su rvey Area c:::J 1/4 Mile Raptor Survey Area D Pad = Access Road --County Road ID BLM Figure 1 Ursa Operating Company Watson Ranch B Pad UIC Biological Survey Location and Potential Waters of the US ~\NestWater Engineering -:;;;JI Consulting Engineers & Sc ient ists 0 0 .1 0.2 0 .3 Miles WestWater Engineering Page 1 of 12 December 2014 WestWater Engineering Page 1 of 12 December 2014 Legend CJ Elk Winter Concentra tion Area CJ Pad = Access Road --County Road IO BLM 9 ·J=t-~~.:.--~t1J1--~-'--_j_~ Figure 3 Ursa Operating Company Wats~n Ranch B Pad UIC Biological survey Elk Activities g \NestWater Engineerin _. Consulti ng Engineers & S . . 9 cient 1sts y. y, Miles : ordi 11eran omplianc• . December 2014 e rv1ce ( sson ssoc)\ rsa\ atson an c WestWater Engineering Page 1 of 12 December 2014 WestWater Engineering Page 1 of 2 December 2014 URSA OPERATING COMPANY, LLC. WATSON RANCH B PAD UNDERGROUND INJECTION CONTROL Section 7-202 Protection of Wildlife Habitat Areas Garfield County Land Use and Development Code WILDLIFE Colorado River Endangered Fishes Designated critical habitat for four endangered fish occurs in the Colorado River adjacent to or downstream of the project area. Runoff from storms or snowmelt may carry increased sediment loads or pollutants from the well pad to the river. Implementation of a Spill Prevention, Control, and Countermeasure Plan (SPCC), a Stormwater Management Plan (SWMP), and Best Management Practices (BMPs) associated with this type of project will provide a good degree of mitigation for any potential impacts. There would be no anticipated depletions that could affect aquatic species associated with the project. Raptors Activities associated with the project have minimal potential to impact raptor populations as no raptor nesting habitat would be affected, and no raptor nests are known to occur within 0.25 miles of the project area. Indirect impacts would be related to displacement of foraging activities and the effect would be small given the abundance of foraging habitat available. Due to these factors, in addition to a high ongoing level of human activity in the general project area, it is unlikely that the injection well would contribute to any negative impacts. American Elk, Mule Deer, Black Bear, and Mountain Lion Implementation of the Integrated Vegetation and Noxious Weed Management Plan (IVNWMP) (WestWater 2014) would help reduce impacts from habitat loss and alteration of native plant communities to the extent possible. A reclamation plan should be implemented to reduce the establishment of noxious weeds in disturbed areas. Reclamation of disturbed areas not critical for operations would replace a portion of the forage lost for mule deer and elk and reduce the presence of noxious weeds. Low speed limits already in place on area roads mitigate potential road kill. Facility fencing should be consistent with published standards that reduce potential harm to wildlife (Hanophy 2009). Black bear and mountain lion may occasionally be observed near the site and should not be approached if encountered. Personnel may be unfamiliar with wildlife in the area and should be informed of the potential for bear and lion interactions. Personnel should not feed or harass wildlife at any time. Trash should be stored in bear-proof receptacles and/or removed from the site on a daily basis to prevent attracting bears to the site. Negative interactions may result in euthanasia of problem animals. Birds, Small Mammals, and Reptiles Removal of native vegetation contributes to cumulative effects of habitat conversion and fragmentation in Garfield County. The placement of the injection well in a previously disturbed area (hay field) has reduced additional impacts, though some nesting cover for ground nesting birds and foraging habitat for numerous species will be affected. Low speed limits on area roads mitigate potential road kill. PRESERVATION OF NATIVE VEGETATION Very little native vegetation will be removed for development of the injection well since the project will be placed in an agricultural area where native vegetation had previously been removed. Application of the IVNWMP (WestWater 2014) would provide a degree of mitigation for the native vegetation that has already been removed. Reducing the amount of bare ground to only the area needed for utilization and WestWater Engineering Page 2 of 2 December 2014 maintenance of the facility will help reduce the effect of the project on native vegetation and wildlife habitat. The best method to mitigate loss of wildlife habitat and provide the greatest benefit for wildlife is to increase the availability of native grasses and shrubs. Vegetation removal and soil disturbance during construction can create optimal conditions for the establishment of invasive, non-native species. Vehicles and equipment traveling from weed-infested areas into weed-free areas could disperse noxious or invasive weed seeds and propagates, resulting in the establishment of these weeds in previously weed-free areas. Several simple practices should be employed to prevent most weed infestations. The following practices should be adopted for any activity to reduce the costs of noxious weed control through prevention. The practices include:  Prior to delivery to the site, equipment should be thoroughly cleaned of soils remaining from previous construction sites which may be contaminated with noxious weeds.  If working in sites with weed-seed contaminated soil, equipment should be cleaned of potentially seed-bearing soils and vegetative debris at the infested area prior to moving to uncontaminated terrain.  All maintenance vehicles should be regularly cleaned of soil.  Avoid driving vehicles through areas where weed infestations exist. REFERENCES Hanophy, W. 2009. Fencing with Wildlife in Mind. Colorado Division of Wildlife. Denver. Available online: http://wildlife.state.co.us/SiteCollectionDocuments/DOW/LandWater/PrivateLandPrograms/DO WFencingWithWildlifeInMind.pdf WestWater Engineering. 2014. Integrated Vegetation and Noxious Weed Management Plan for Ursa Operating Company, LLC’s proposed Watson Ranch B Pad UIC Injection Well. Grand Junction. Article 4-203.G.7 Fugitive Dust Control Plan Ursa Operating Company LLC Watson Ranch B Injection Well OA Project No. 014-3005 Fugitive Dust Control Plan Page 1 Ursa Operating Company July 2014 Fugitive Dust Control Plan Garfield County, Colorado July 2014 Ursa Operating Company Colorado, USA Scope: The scope of these guidelines is to outline some basic principles to minimize and control fugitive dust emissions during land development. Requirements: Ursa Operating Company places the highest priority on the health and safety of our workforce and protection of our assets and the environment. Applicable Documents: Department of Public Health and Environment Air Quality Control Commission Regulation 1 5CCR 1001-3. Safety: Safety Plan Quality: These guidelines will be reviewed periodically and will be shared with employees and contractors to ensure that they have adequate knowledge to minimize fugitive dust emissions. • INTRODUCTION Land development activities, including clearing, excavating, and grading, release fugitive dust, a pollutant regulated by the Air Pollution Control Division (Division) at the Colorado Department of Public Health and Environment. However, small land development activities that are less than 25 contiguous acres and less than 6 months in duration do not need to report air emissions to the Division, but must use appropriate control measures to minimize the release of fugitive dust from the site. This Fugitive Dust Control Plan addresses how dust will be kept to a minimum on roads, pad sites, and operational facilities. This plan focuses action on: • Identifying specific individual sources of fugitive dust. • Control options for unpaved roadways. • Control options for disturbed areas. • Control options for transport, storage and handling of bulk materials. • Contingency Plan for alternative action in the event that control strategies are not adequate, effective, or practical. Fugitive Dust Control Plan Page 2 Ursa Operating Company July 2014 • SPECIFIC SOURCES Specific types of fugitive dust sources may appear to have negligible dust emissions, but when combined with other specific sources underway at the same time can create dust plumes that are visible beyond that which is appropriate for designated speeds and designs and may exceed nuisance emission limitation guidelines. It is important to consider all activities on the site together in determining compliance with federal, state, and local air quality regulations. Task: Provide field personnel and contractors with the information required to limit fugitive particulate matter (fugitive dust) from all specific sources to include: • Unpaved roadways and traffic areas. • Construction activities including earth moving and excavation. • Bulk material (i.e. gravel and soils). • Storage and handling of materials • CONTROL OPTIONS FOR UNPAVED ROADWAYS Any owner or operator responsible for construction or maintenance of any (existing or new) unpaved roadway is required to use all available, practical methods to minimize dust emissions. Task: Provide guidelines for minimizing fugitive dust emissions from all specific sources on unpaved roadways and traffic areas: • Require that all passenger vehicles, construction equipment, and truck traffic obey the posted speed limits on all unpaved County and private roads to and from the project site. • Ensure that vehicle speeds on new and existing access roads on the project site do not exceed 15 miles per hour by posting speed limits along these roads. • Restrict vehicle traffic to existing roads by posting signs and/or providing the locations of allowable access routes to all field personnel and visitors. • Encourage carpooling to and from the project site to limit traffic on existing County and private roads. • Roads and well locations will be surfaced with compacted gravel to protect against wind erosion, to reduce the amount of fugitive dust generated by traffic and other activities, and to reduce carryout/trackout. • Use dust inhibitors (surfacing materials, water, or non-saline dust suppressants) on all unpaved collector, local, and resource roads to prevent fugitive dust problems (ensure that any dust suppressants used are appropriate for road conditions and will not compromise the safety of workers on the project site). Fugitive Dust Control Plan Page 3 Ursa Operating Company July 2014 • Restrict vehicular access during periods of inactivity using gates, fencing, and/or onsite security personnel. • CONTROL OPTIONS FOR DISTURBED AREAS Disturbed areas include new roads, well pads, parking and staging areas, and material storage areas that have been cleared of vegetation, leveled, or excavated. These areas are susceptible to wind erosion and are a major source of fugitive dust emissions that require the appropriate controls and dust mitigation methods. Note that specific sources are subject to change as project conditions change, and will require an evaluation of current control options to ensure effectiveness and practicality. Task: Limit the adverse impacts of fugitive dust emissions through control measures and operational procedures designed so that no off-property transport emissions occur at the project site. • Surface all bare ground with gravel as soon as practicable after clearing, leveling, and grading. • Use dust inhibitors (surfacing materials, water, or non-saline dust suppressants) on all disturbed areas as necessary to prevent fugitive dust problems. • Reduce the amount of time between initially disturbing the soil and revegetating or other surface stabilization. • Apply vegetative or synthetic cover to topsoil and spoil piles as soon as practicable following stockpiling to prevent wind erosion and fugitive dust emissions. • Compact the soil on disturbed areas that will not be surfaced with gravel or revegetated immediately following construction. • Minimize surface disturbance to only that necessary for safe and efficient construction and operations. • Use vegetative mulch, reseeding, or other methods of surface stabilization on all areas adjoining development to include shoulders, borrow ditches, and berms, if practical. • Restrict vehicular access during periods of inactivity using gates, fencing. • Identify any new sources of fugitive dust emissions and evaluate and implement the appropriate control methods for that source. • Incorporate fugitive dust controls in all lands projects. • CONTROL OPTIONS FOR TRANSPORT, STORAGE AND HANDLING OF BULK MATERIALS Transporting bulk materials, such as gravel and fill material, can result in off-property dust emissions and other impacts (i.e. broken windshields) over some distance if the appropriate control measures are not implemented. Storage and handling of bulk materials once they arrive Fugitive Dust Control Plan Page 4 Ursa Operating Company July 2014 at the project site also requires that controls are in place to ensure that these materials do not exceed regulated nuisance dust emissions. Task: Use control measures and operational procedures designed so that no off-property transport emissions occur along public roadways to and from the project site: • Enclose, cover, water, or otherwise treat loaded haul trucks to minimize the loss of material to wind and spillage. • Require that all contract haul vehicles obey the posted speed limits on all public roadways to and from the project site. • Ensure that haul truck speed on new and existing access roads on the project site do not exceed 15 miles per hour by posting speed limits along these roads. • Restrict haul trucks to existing roads and pad locations. • Promptly remove dust-forming material from haul trucks to minimize entrainment of fugitive particulate matter. • Avoid storage and handling of bulk material any more than necessary to complete construction. • Use covers, enclosures, wind breaks, or watering to prevent fugitive dust emissions from material storage piles. • Restrict access to construction areas and storage piles during periods of inactivity using gates, fencing. • CONTINGENCY PLANNING Alternative control measures may become necessary in the event that the current dust control strategy is not adequate or effective for conditions. An alternative plan may require additional planning, permitting, or other regulatory compliance requirements to implement. In this case, the current activities at the project site would necessarily be suspended until such time as the alternate dust control methods could be put into place. Task: Implement alternative action to fugitive dust control plan and to each specific source if deemed necessary to comply with federal, state, and local air quality regulations: • Provide field personnel and contractors with contact information for responsible individuals in cases where control measures need to be escalated in response to weather conditions (i.e. increased windiness). • Use an appropriate alternative dust inhibitor if water does not prove to be effective under normal circumstances, and obtain all regulatory permissions for the use of chemical suppressants on the project site. Fugitive Dust Control Plan Page 5 Ursa Operating Company July 2014 • Use vegetative blankets or other methods for cover of topsoil, spoil, and bulk material storage piles if immediate cover becomes necessary. • Attempt to locate alternative sources of bulk material closer to the project site if fugitive dust emissions or other impacts from contract haul trucks on state or federal highways become an issue with public safety or regulatory compliance. Article 4-203.G.7 Sound Study Ursa Operating Company LLC Watson Ranch B Injection Well OA Project No. 014-3005 760 Horizon Drive, Suite 102 TEL 970.263.7800 Grand Junction, CO 81506 FAX 970.263.7456 www.olssonassociates.com 4-203.G.7 – Sound Data Review Ursa Operating Co. Watson Ranch B UIC At the request of Ursa Operating Co. (Ursa), Olsson Associates (Olsson) has conducted an assessment of noise survey data. This noise survey data was collected at the Valley Farms F injection operation. The noise generating equipment assessed was an electric triplex pump used to inject waste water underground. The intent of this assessment was to review the data to determine the sound pressure levels generated during the operation of the injection pump and extrapolate that data out for comparison at the proposed Watson Ranch B UIC facility. Using the planned distances, conclusions can be drawn about the potential sound pressure levels that pump operations at the Watson Ranch B facility will be in order to determine compliance with the noise limits set forth in the Colorado Oil and Gas Conservation Commission (COGCC) Rule 802. Noise Data The data was collected by Ursa at the Valley Farms F UIC facility during the operation of the noise generating equipment. The noise generated by this equipment should be comparable to that equipment planned at the Watson Ranch B facility. The noise measurements were collected on April 8, 2014 approximately 350 feet south of the pump enclosure. An Extech Model 407764 Sound Level Meter was used to collect 518 consecutive noise readings at 15-second intervals. Portions of the collected data were not useable because of external interference observed during data collection. Such interference was related to adjacent vehicle traffic, onsite activities, air traffic, and rural farming and ranching operations. Based on the observations of these noise impacts, data collected during times of interference was excluded from the determination of the average sound pressure level of the pump’s operation. The raw data is attached to this report. Noise Generating Equipment The electric triplex pump used at the Valley Farms F injection operation is identical to the pump that is planned for installation at the Watson Ranch B injection facility. The existing pump is located inside a fabricated metal enclosure. Compliance Point(s) The COGCC Rule 802 uses the property line or 350 feet from the noise generating equipment, whichever is greater, as the compliance point for oil and gas operations. The nearest property boundary is approximately 85 feet to the north of the pump house. Therefore Olsson has used 350 feet as the compliance point. Olsson has also calculated the sound pressure levels at 1,000 feet from the noise generating equipment to ensure that noise would not be a nuisance at the nearest occupied structure(s), located approximately 1,000 feet to the south southwest. Maximum Permissible Noise Levels Garfield County is applying the Residential/Agricultural/Rural noise standard as prescribed in COGCC Rule 802.The night time maximum permissible noise limit is 50 dB(A) for residential areas. This noise pressure limit has been used to ensure that the proposed noise generating equipment would not be a nuisance at the property line or nearest occupied structure(s). 014-3005 Sound Data Review –Watson Ranch B UIC Facility 12/31/14 Calculated Sound Pressure Levels The average sound pressure level of the pump calculated from the noise survey data is 44 dB(A) at 350 feet. . Olsson has also assessed the potential noise level at 1,000 feet using the noise/distance extrapolation equation provided in COGCC Rule 802 and calculated average sound pressure level. The calculated sound pressure level at 1,000 feet from the equipment will be approximately 35 dB(A). Conclusion By utilizing the sound readings collected from an injection pump currently operating we can estimate the sound pressure levels that would be generated from similar equipment operated at the Watson Ranch B facility. Extrapolating the actual average sound pressure level from the Valley Farms F facility using the distances to the compliance points at the Watson Ranch B facility it appears that the operation of a similar pump should be below the residential limit at 350 feet from the planned location at the nearest occupied structure. These sound pressure levels are calculated based on collected data from a similar operation and actual noise levels should be measured during equipment operation to insure regulatory compliance. Statement of Qualification I am a multi-disciplinary Project Manager at Olsson Associates. I have coordinated many Noise Control Regulation Compliance Assessments over 5 years at existing and planned noise generating equipment installations in Colorado. If you have any questions regarding this assessment, please contact me at 970-263-7800. Ken Kreie Senior Scientist Enclosures – Attachment A – Data Set Attachment B – Valley Farm F Noise Monitoring Data Collection Notes Cc: Project File Site:URSA Watson Ranch B UIC (Electric Pump)dBA1 = 44 dB (A)(Log Average of Noise Reading data at 350' from pump enclosure) D2 = 1000 ft.(Distance to Nearest Occupied Structure) D1 = 350 ft.(Distance of Noise Readings Provided by URSA) dBA2 = 34.9 dB (A)(Calculated dB (A) at 1,000 ft.) Table 1 Distance Extrapolation Worksheet Extrapolation to 1,000 ft. COGCC Rule 802(c) 1 - dB(A)Distance 2 = dB(A)Distance 1 - 20 x log10(Distance2/Distance1) ATTACHMENT A Data Set Valley Farms F  Noise Monitoring Data  Recording #D a t e Hr Min Sec dB 1 4/8/2014 13 46 17 55.8 2 4/8/2014 13 46 32 62.1 3 4/8/2014 13 46 47 53.6 4 4/8/2014 13 47 2 53.2 5 4/8/2014 13 47 17 43.2 6 4/8/2014 13 47 32 40.6 7 4/8/2014 13 47 47 41.7 8 4/8/2014 13 48 2 40.3 9 4/8/2014 13 48 17 38.9 10 4/8/2014 13 48 32 39.6 11 4/8/2014 13 48 47 38.5 12 4/8/2014 13 49 2 38.9 13 4/8/2014 13 49 17 38.6 14 4/8/2014 13 49 32 39 15 4/8/2014 13 49 47 47.3 16 4/8/2014 13 50 2 38.9 17 4/8/2014 13 50 17 39.5 18 4/8/2014 13 50 32 39.5 19 4/8/2014 13 50 47 40.7 20 4/8/2014 13 51 2 42.7 21 4/8/2014 13 51 17 62.1 22 4/8/2014 13 51 32 59.5 23 4/8/2014 13 51 47 52.9 24 4/8/2014 13 52 2 55.9 25 4/8/2014 13 52 17 50.6 26 4/8/2014 13 52 32 60.1 27 4/8/2014 13 52 47 70.6 28 4/8/2014 13 53 2 52.6 29 4/8/2014 13 53 17 53.6 30 4/8/2014 13 53 32 47.2 31 4/8/2014 13 53 47 42 32 4/8/2014 13 54 2 40 33 4/8/2014 13 54 17 40.2 34 4/8/2014 13 54 32 44.9 35 4/8/2014 13 54 47 39.6 36 4/8/2014 13 55 2 39.2 37 4/8/2014 13 55 17 39.4 38 4/8/2014 13 55 32 38.1 39 4/8/2014 13 55 47 38.2 40 4/8/2014 13 56 2 38.3 41 4/8/2014 13 56 17 37.7 42 4/8/2014 13 56 32 37.6 43 4/8/2014 13 56 47 47 44 4/8/2014 13 57 2 41.9 45 4/8/2014 13 57 17 37.9 46 4/8/2014 13 57 32 43.9 47 4/8/2014 13 57 47 49.2 48 4/8/2014 13 58 2 59.3 49 4/8/2014 13 58 17 48.1 50 4/8/2014 13 58 32 51.5 51 4/8/2014 13 58 47 57.5 52 4/8/2014 13 59 2 64.6 53 4/8/2014 13 59 17 48.3 54 4/8/2014 13 59 32 43.7 55 4/8/2014 13 59 47 42.6 56 4/8/2014 14 0 2 44.5 57 4/8/2014 14 0 17 38.7 58 4/8/2014 14 0 32 37.7 59 4/8/2014 14 0 47 38.3 60 4/8/2014 14 1 2 37.1 61 4/8/2014 14 1 17 37.7 62 4/8/2014 14 1 32 49.3 63 4/8/2014 14 1 47 45.6 64 4/8/2014 14 2 2 42.1 65 4/8/2014 14 2 17 42.3 66 4/8/2014 14 2 32 61.7 67 4/8/2014 14 2 47 67.2 68 4/8/2014 14 3 2 42.6 69 4/8/2014 14 3 17 51.1 70 4/8/2014 14 3 32 42.1 71 4/8/2014 14 3 47 40.8 72 4/8/2014 14 4 2 40.3 73 4/8/2014 14 4 17 44.6 74 4/8/2014 14 4 32 41.2 75 4/8/2014 14 4 47 39.3 76 4/8/2014 14 5 2 41.2 77 4/8/2014 14 5 17 42.8 78 4/8/2014 14 5 32 39.6 79 4/8/2014 14 6 47 38.6 80 4/8/2014 14 6 2 44.8 81 4/8/2014 14 6 17 44.9 82 4/8/2014 14 6 32 43 83 4/8/2014 14 6 47 32 84 4/8/2014 14 7 2 39.7 85 4/8/2014 14 7 17 38.3 86 4/8/2014 14 7 32 42 87 4/8/2014 14 7 47 41.5 88 4/8/2014 14 8 2 43.5 89 4/8/2014 14 8 17 46.1 90 4/8/2014 14 8 32 42.5 91 4/8/2014 14 8 47 40.1 92 4/8/2014 14 9 2 39.8 Time 1 Valley Farms F  Noise Monitoring Data  Recording #D a t e Hr Min Sec dB Time 93 4/8/2014 14 9 17 38.9 94 4/8/2014 14 9 32 38.3 95 4/8/2014 14 9 47 41.6 96 4/8/2014 14 10 2 39.3 97 4/8/2014 14 10 17 40.5 98 4/8/2014 14 10 32 38.5 99 4/8/2014 14 10 47 38.3 100 4/8/2014 14 11 2 38.1 101 4/8/2014 14 11 17 38.3 102 4/8/2014 14 11 32 38.2 103 4/8/2014 14 11 47 39.1 104 4/8/2014 14 12 2 38.2 105 4/8/2014 14 12 17 38.2 106 4/8/2014 14 12 32 40.5 107 4/8/2014 14 12 47 39.9 108 4/8/2014 14 13 2 41.3 109 4/8/2014 14 13 17 45.5 110 4/8/2014 14 13 32 51.9 111 4/8/2014 14 13 47 42.2 112 4/8/2014 14 14 2 40.6 113 4/8/2014 14 14 17 40.8 114 4/8/2014 14 14 32 40.8 115 4/8/2014 14 14 47 53.9 116 4/8/2014 14 15 2 42.5 117 4/8/2014 14 15 17 39.6 118 4/8/2014 14 15 32 39.7 119 4/8/2014 14 15 47 41.2 120 4/8/2014 14 16 2 58.4 121 4/8/2014 14 16 17 44 122 4/8/2014 14 16 32 47.6 123 4/8/2014 14 16 47 58.4 124 4/8/2014 14 17 2 47.9 125 4/8/2014 14 17 17 47.7 126 4/8/2014 14 17 32 50.2 127 4/8/2014 14 17 47 42.4 128 4/8/2014 14 18 2 42.7 129 4/8/2014 14 18 17 41.1 130 4/8/2014 14 18 32 52.5 131 4/8/2014 14 18 47 53.8 132 4/8/2014 14 19 2 45.3 133 4/8/2014 14 19 17 55.2 134 4/8/2014 14 19 32 46.3 135 4/8/2014 14 19 47 43.8 136 4/8/2014 14 20 2 48.6 137 4/8/2014 14 20 17 51.7 138 4/8/2014 14 20 32 46.6 139 4/8/2014 14 20 47 45.9 140 4/8/2014 14 21 2 42.4 141 4/8/2014 14 21 17 42.7 142 4/8/2014 14 21 32 42.2 143 4/8/2014 14 21 47 42.3 144 4/8/2014 14 22 2 40.4 145 4/8/2014 14 22 17 39.7 146 4/8/2014 14 22 32 39.3 147 4/8/2014 14 22 47 40.2 148 4/8/2014 14 23 2 39.8 149 4/8/2014 14 23 17 42.8 150 4/8/2014 14 23 32 45.4 151 4/8/2014 14 23 47 39.1 152 4/8/2014 14 24 2 39.3 153 4/8/2014 14 24 17 38.6 154 4/8/2014 14 24 32 38.1 155 4/8/2014 14 24 47 39.7 156 4/8/2014 14 25 2 41.1 157 4/8/2014 14 25 17 38.3 158 4/8/2014 14 25 32 39.2 159 4/8/2014 14 25 47 39.8 160 4/8/2014 14 26 2 39.7 161 4/8/2014 14 26 17 39.6 162 4/8/2014 14 26 32 40.2 163 4/8/2014 14 26 47 40.3 164 4/8/2014 14 27 2 51 165 4/8/2014 14 27 17 41.3 166 4/8/2014 14 27 32 40.3 167 4/8/2014 14 27 47 49.7 168 4/8/2014 14 28 2 42.1 169 4/8/2014 14 28 17 38.9 170 4/8/2014 14 28 32 39.3 171 4/8/2014 14 28 47 39.2 172 4/8/2014 14 29 2 39.1 173 4/8/2014 14 29 17 38.8 174 4/8/2014 14 29 32 39.3 175 4/8/2014 14 29 47 40 176 4/8/2014 14 30 2 39 177 4/8/2014 14 30 17 38.5 178 4/8/2014 14 30 32 38.8 179 4/8/2014 14 30 47 39.1 180 4/8/2014 14 31 2 39.5 181 4/8/2014 14 31 17 39 182 4/8/2014 14 31 32 39.3 183 4/8/2014 14 31 47 39.1 184 4/8/2014 14 32 2 46.1 2 Valley Farms F  Noise Monitoring Data  Recording #D a t e Hr Min Sec dB Time 185 4/8/2014 14 32 17 39.6 186 4/8/2014 14 32 32 52.9 187 4/8/2014 14 32 47 43 188 4/8/2014 14 33 2 53.9 189 4/8/2014 14 33 17 54.1 190 4/8/2014 14 33 32 58.1 191 4/8/2014 14 33 47 44.6 192 4/8/2014 14 34 2 45 193 4/8/2014 14 34 17 42.1 194 4/8/2014 14 34 32 40 195 4/8/2014 14 34 47 44.2 196 4/8/2014 14 35 2 40.9 197 4/8/2014 14 35 17 45.2 198 4/8/2014 14 35 32 60.2 199 4/8/2014 14 35 47 48.4 200 4/8/2014 14 36 2 43.9 201 4/8/2014 14 36 17 47.9 202 4/8/2014 14 36 32 42.2 203 4/8/2014 14 36 47 41.8 204 4/8/2014 14 37 2 38.9 205 4/8/2014 14 37 17 48.5 206 4/8/2014 14 37 32 38.9 207 4/8/2014 14 37 47 43.5 208 4/8/2014 14 38 2 40.5 209 4/8/2014 14 38 17 39.3 210 4/8/2014 14 38 32 39.1 211 4/8/2014 14 38 47 43.2 212 4/8/2014 14 39 2 49.7 213 4/8/2014 14 39 17 53.5 214 4/8/2014 14 39 32 40.7 215 4/8/2014 14 39 47 40.5 216 4/8/2014 14 40 2 44.2 217 4/8/2014 14 40 17 50 218 4/8/2014 14 40 32 39.8 219 4/8/2014 14 40 47 38.7 220 4/8/2014 14 41 2 42.8 221 4/8/2014 14 41 17 39.7 222 4/8/2014 14 41 32 40.6 223 4/8/2014 14 41 47 39.1 224 4/8/2014 14 42 2 52.3 225 4/8/2014 14 42 17 42.8 226 4/8/2014 14 42 32 42.9 227 4/8/2014 14 42 47 42 228 4/8/2014 14 43 2 39.8 229 4/8/2014 14 43 17 39.6 230 4/8/2014 14 43 32 38.4 231 4/8/2014 14 43 47 38.4 232 4/8/2014 14 44 2 39.3 233 4/8/2014 14 44 17 39.4 234 4/8/2014 14 44 32 39.8 235 4/8/2014 14 44 47 46.4 236 4/8/2014 14 45 2 39.8 237 4/8/2014 14 45 17 39.5 238 4/8/2014 14 45 32 39 239 4/8/2014 14 45 47 40.4 240 4/8/2014 14 46 2 57.2 241 4/8/2014 14 46 17 47.1 242 4/8/2014 14 46 32 52.5 243 4/8/2014 14 46 47 40.2 244 4/8/2014 14 47 2 38.6 245 4/8/2014 14 47 17 39.2 246 4/8/2014 14 47 32 38.7 247 4/8/2014 14 47 47 39.8 248 4/8/2014 14 48 2 38.7 249 4/8/2014 14 48 17 38.8 250 4/8/2014 14 48 32 40 251 4/8/2014 14 48 47 40.6 252 4/8/2014 14 49 2 41.3 253 4/8/2014 14 49 17 41.2 254 4/8/2014 14 49 32 42.2 255 4/8/2014 14 49 47 49.7 256 4/8/2014 14 50 2 49.6 257 4/8/2014 14 50 17 48.7 258 4/8/2014 14 50 32 44.1 259 4/8/2014 14 50 47 47.1 260 4/8/2014 14 51 2 58.8 261 4/8/2014 14 51 17 57.8 262 4/8/2014 14 51 32 54.7 263 4/8/2014 14 51 47 62.3 264 4/8/2014 14 52 2 59.1 265 4/8/2014 14 52 17 58.7 266 4/8/2014 14 52 32 57.9 267 4/8/2014 14 52 47 63.4 268 4/8/2014 14 53 2 56.5 269 4/8/2014 14 53 17 57.6 270 4/8/2014 14 53 32 56.3 271 4/8/2014 14 53 47 55.3 272 4/8/2014 14 54 2 56.7 273 4/8/2014 14 54 17 55.7 274 4/8/2014 14 54 32 56.1 275 4/8/2014 14 54 47 55.4 276 4/8/2014 14 55 2 55.5 3 Valley Farms F  Noise Monitoring Data  Recording #D a t e Hr Min Sec dB Time 277 4/8/2014 14 55 17 55.1 278 4/8/2014 14 55 32 58.6 279 4/8/2014 14 55 47 58.3 280 4/8/2014 14 56 2 56 281 4/8/2014 14 56 17 55.3 282 4/8/2014 14 56 32 53.4 283 4/8/2014 14 56 47 51.3 284 4/8/2014 14 57 2 49.5 285 4/8/2014 14 57 17 50.7 286 4/8/2014 14 57 32 52.6 287 4/8/2014 14 57 47 53.2 288 4/8/2014 14 58 2 58.3 289 4/8/2014 14 58 17 52 290 4/8/2014 14 58 32 50.9 291 4/8/2014 14 58 47 54.4 292 4/8/2014 14 59 2 54.6 293 4/8/2014 14 59 17 52.5 294 4/8/2014 14 59 32 52.2 295 4/8/2014 14 59 47 50.3 296 4/8/2014 15 0 2 51.2 297 4/8/2014 15 0 17 51.3 298 4/8/2014 15 0 32 54.7 299 4/8/2014 15 0 47 52.6 300 4/8/2014 15 1 2 56.9 301 4/8/2014 15 1 17 52.1 302 4/8/2014 15 1 32 52.9 303 4/8/2014 15 1 47 53 304 4/8/2014 15 2 2 56 305 4/8/2014 15 2 17 53.6 306 4/8/2014 15 2 32 52.7 307 4/8/2014 15 2 47 53.9 308 4/8/2014 15 3 2 53.8 309 4/8/2014 15 3 17 53 310 4/8/2014 15 3 32 59.8 311 4/8/2014 15 3 47 53.1 312 4/8/2014 15 4 2 55.1 313 4/8/2014 15 4 17 54.9 314 4/8/2014 15 4 32 56.3 315 4/8/2014 15 4 47 52.2 316 4/8/2014 15 5 2 53 317 4/8/2014 15 5 17 53 318 4/8/2014 15 5 32 50.9 319 4/8/2014 15 6 47 55.1 320 4/8/2014 15 6 2 56.7 321 4/8/2014 15 6 17 53.5 322 4/8/2014 15 6 32 57.9 323 4/8/2014 15 6 47 55.6 324 4/8/2014 15 7 2 55.8 325 4/8/2014 15 7 17 57 326 4/8/2014 15 7 32 54.3 327 4/8/2014 15 7 47 52.7 328 4/8/2014 15 8 2 55.4 329 4/8/2014 15 8 17 57.1 330 4/8/2014 15 8 32 52.6 331 4/8/2014 15 8 47 53.9 332 4/8/2014 15 9 2 58.2 333 4/8/2014 15 9 17 59.3 334 4/8/2014 15 9 32 57.2 335 4/8/2014 15 9 47 57.8 336 4/8/2014 15 10 2 59.9 337 4/8/2014 15 10 17 62.2 338 4/8/2014 15 10 32 53.5 339 4/8/2014 15 10 47 58.1 340 4/8/2014 15 11 2 58.4 341 4/8/2014 15 11 17 60.2 342 4/8/2014 15 11 32 61.7 343 4/8/2014 15 11 47 62.7 344 4/8/2014 15 12 2 63.3 345 4/8/2014 15 12 17 63.1 346 4/8/2014 15 12 32 64 347 4/8/2014 15 12 47 64.1 348 4/8/2014 15 13 2 64 349 4/8/2014 15 13 17 64.9 350 4/8/2014 15 13 32 65.1 351 4/8/2014 15 13 47 64.8 352 4/8/2014 15 14 2 65 353 4/8/2014 15 14 17 64.7 354 4/8/2014 15 14 32 65 355 4/8/2014 15 14 47 65 356 4/8/2014 15 15 2 65 357 4/8/2014 15 15 17 66.3 358 4/8/2014 15 15 32 65.2 359 4/8/2014 15 15 47 65.9 360 4/8/2014 15 16 2 65.5 361 4/8/2014 15 16 17 65.6 362 4/8/2014 15 16 32 65.9 363 4/8/2014 15 16 47 65.8 364 4/8/2014 15 17 2 64.4 365 4/8/2014 15 17 17 65.4 366 4/8/2014 15 17 32 65.3 367 4/8/2014 15 17 47 66.1 368 4/8/2014 15 18 2 65 4 Valley Farms F  Noise Monitoring Data  Recording #D a t e Hr Min Sec dB Time 369 4/8/2014 15 18 17 60.6 370 4/8/2014 15 18 32 61.1 371 4/8/2014 15 18 47 63.7 372 4/8/2014 15 19 2 62.9 373 4/8/2014 15 19 17 62.2 374 4/8/2014 15 19 32 60.2 375 4/8/2014 15 19 47 58 376 4/8/2014 15 20 2 59.5 377 4/8/2014 15 20 17 57.7 378 4/8/2014 15 20 32 54.7 379 4/8/2014 15 20 47 55.2 380 4/8/2014 15 21 2 52.7 381 4/8/2014 15 21 17 49 382 4/8/2014 15 21 32 46.7 383 4/8/2014 15 21 47 41 384 4/8/2014 15 22 2 56.2 385 4/8/2014 15 22 17 55.5 386 4/8/2014 15 22 32 56.6 387 4/8/2014 15 22 47 55.1 388 4/8/2014 15 23 2 55.8 389 4/8/2014 15 23 17 56.2 390 4/8/2014 15 23 32 57.4 391 4/8/2014 15 23 47 56.5 392 4/8/2014 15 24 2 55.9 393 4/8/2014 15 24 17 54.7 394 4/8/2014 15 24 32 55.4 395 4/8/2014 15 24 47 59.1 396 4/8/2014 15 25 2 57.9 397 4/8/2014 15 25 17 61.5 398 4/8/2014 15 25 32 55 399 4/8/2014 15 25 47 53.7 400 4/8/2014 15 26 2 53.3 401 4/8/2014 15 26 17 59.6 402 4/8/2014 15 26 32 61.1 403 4/8/2014 15 26 47 62.5 404 4/8/2014 15 27 2 59.9 405 4/8/2014 15 27 17 61.9 406 4/8/2014 15 27 32 62.1 407 4/8/2014 15 27 47 65.4 408 4/8/2014 15 28 2 57.7 409 4/8/2014 15 28 17 58.7 410 4/8/2014 15 28 32 58.2 411 4/8/2014 15 28 47 58.8 412 4/8/2014 15 29 2 58.9 413 4/8/2014 15 29 17 56.9 414 4/8/2014 15 29 32 59.5 415 4/8/2014 15 29 47 61.1 416 4/8/2014 15 30 2 57 417 4/8/2014 15 30 17 61.9 418 4/8/2014 15 30 32 61.6 419 4/8/2014 15 30 47 62.5 420 4/8/2014 15 31 2 61.9 421 4/8/2014 15 31 17 61.2 422 4/8/2014 15 31 32 59.5 423 4/8/2014 15 31 47 61.4 424 4/8/2014 15 32 2 62.9 425 4/8/2014 15 32 17 63.9 426 4/8/2014 15 32 32 62.6 427 4/8/2014 15 32 47 59.8 428 4/8/2014 15 33 2 62.4 429 4/8/2014 15 33 17 58.7 430 4/8/2014 15 33 32 57.3 431 4/8/2014 15 33 47 58.9 432 4/8/2014 15 34 2 58.2 433 4/8/2014 15 34 17 55.1 434 4/8/2014 15 34 32 57.1 435 4/8/2014 15 34 47 55.8 436 4/8/2014 15 35 2 56.3 437 4/8/2014 15 35 17 56.5 438 4/8/2014 15 35 32 57.5 439 4/8/2014 15 35 47 57.1 440 4/8/2014 15 36 2 54.9 441 4/8/2014 15 36 17 52.8 442 4/8/2014 15 36 32 53.9 443 4/8/2014 15 36 47 55.8 444 4/8/2014 15 37 2 45.4 445 4/8/2014 15 37 17 45.9 446 4/8/2014 15 37 32 46.1 447 4/8/2014 15 37 47 50.5 448 4/8/2014 15 38 2 46.3 449 4/8/2014 15 38 17 46.2 450 4/8/2014 15 38 32 45.4 451 4/8/2014 15 38 47 45.8 452 4/8/2014 15 39 2 45.1 453 4/8/2014 15 39 17 46.1 454 4/8/2014 15 39 32 45.7 455 4/8/2014 15 39 47 47.6 456 4/8/2014 15 40 2 45.3 457 4/8/2014 15 40 17 45.4 458 4/8/2014 15 40 32 46 459 4/8/2014 15 40 47 45.9 460 4/8/2014 15 41 2 45.6 5 Valley Farms F  Noise Monitoring Data  Recording #D a t e Hr Min Sec dB Time 461 4/8/2014 15 41 17 46.4 462 4/8/2014 15 41 32 46.2 463 4/8/2014 15 41 47 46.5 464 4/8/2014 15 42 2 46.7 465 4/8/2014 15 42 17 46.9 466 4/8/2014 15 42 32 46.3 467 4/8/2014 15 42 47 46.1 468 4/8/2014 15 43 2 46.8 469 4/8/2014 15 43 17 46.2 470 4/8/2014 15 43 32 46 471 4/8/2014 15 43 47 48.1 472 4/8/2014 15 44 2 47.2 473 4/8/2014 15 44 17 47.6 474 4/8/2014 15 44 32 46.5 475 4/8/2014 15 44 47 51 476 4/8/2014 15 45 2 52 477 4/8/2014 15 45 17 54.7 478 4/8/2014 15 45 32 45.4 479 4/8/2014 15 45 47 46 480 4/8/2014 15 46 2 44.8 481 4/8/2014 15 46 17 45 482 4/8/2014 15 46 32 45 483 4/8/2014 15 46 47 45.4 484 4/8/2014 15 47 2 45 485 4/8/2014 15 47 17 45.1 486 4/8/2014 15 47 32 44.6 487 4/8/2014 15 47 47 46.2 488 4/8/2014 15 48 2 45.9 489 4/8/2014 15 48 17 51.7 490 4/8/2014 15 48 32 47 491 4/8/2014 15 48 47 58.1 492 4/8/2014 15 49 2 60.2 493 4/8/2014 15 49 17 60.1 494 4/8/2014 15 49 32 63.1 495 4/8/2014 15 49 47 58.8 496 4/8/2014 15 50 2 55.4 497 4/8/2014 15 50 17 56.1 498 4/8/2014 15 50 32 58.6 499 4/8/2014 15 50 47 57.4 500 4/8/2014 15 51 2 56.4 501 4/8/2014 15 51 17 60.7 502 4/8/2014 15 51 32 55.7 503 4/8/2014 15 51 47 55.7 504 4/8/2014 15 52 2 55.1 505 4/8/2014 15 52 17 60.4 506 4/8/2014 15 52 32 53.5 507 4/8/2014 15 52 47 53.6 508 4/8/2014 15 53 2 53.8 509 4/8/2014 15 53 17 59 510 4/8/2014 15 53 32 54.8 511 4/8/2014 15 53 47 52.6 512 4/8/2014 15 54 2 52.4 513 4/8/2014 15 54 17 52.6 514 4/8/2014 15 54 32 53.7 515 4/8/2014 15 54 47 56.2 516 4/8/2014 15 55 2 57.2 517 4/8/2014 15 55 17 54.7 518 4/8/2014 15 55 32 56.5 44 ### #### Log Average of applicable measurements  rounded to the nearest decibel Data not applicable because of noise  interference by other operations 6 ATTACHMENT B Valley Farm F Noise Monitoring Data Collection Notes Valley Farms F ‐ Noise Monitoring   Current Operations Phase: Production & Injection Well Operations   Operating Injection facility to include electric triplex pump    Production of existing wells    Hauling produced liquids off location utilizing transport trucks   Adjacent Land Operations:   Rural Farming and Ranching Operation   Air plane traffic    Traffic from landowners and subdivision activities (Miniota Estates)  Sound Study Duration and Location   Approximately 2 Hours 5 Minutes   Began Recordings at 1:46 p.m.   Ended Recordings at 3:50 p.m.   Equipment located 350 ft. south of center of location.    Weather Conditions   Start of Study ‐ 59° F / SW Wind @ 2 ‐3 mph Sunny   End of Study ‐ 62° F / West Wind @ 5 mph Sunny   Measurement Equipment:   EXTECH Instrument/ Sound Level Meter/ Model 407764  Cody Smith, Noise Measurement Analyst   Article 4-203.L Traffic Study Ursa Operating Company LLC Watson Ranch B Injection Well OA Project No. 014-3005 BASIC TRAFFIC ANALYSIS URSA OPERATING COMPANY, LLC WATSON RANCH B INJECTION WELL GARFIELD COUNTY, COLORADO OA Project No. 014-3005 February 2015 760 Horizon Dr., Suite 102 | Grand Junction, CO 81506 | 970.263.7800 | Fax 970.263.7456 Watson Ranch B Injection Well February, 2015 Ursa Operating Company, LLC Basic Traffic Analysis Page 1 INTRODUCTION & OBJECTIVE This document summarizes findings of a Basic Traffic Analysis performed for the Ursa Operating Company, LLC proposed Watson Ranch B Injection Well. The primary use of the site will be as a COGCC approved natural gas well pad, and the injection well is proposed to be an additional use on the property. The injection well will be used to dispose of produced water from well pads in the Battlement Mesa area. The facility will be constructed as a well pad, but will require minor infrastructure improvements for the additional use as an injection well. It is expected that the lifespan of the site will be 20 or more years. A Vicinity Map is included as an attachment at the end of this document. The site is approximately 3.5 travel miles southeast of Parachute, CO. The facility is located in the southeast ¼ of the southwest ¼ of Section 17, Township 7 South, Range 95 West of the 6th Principal Meridian in unincorporated Garfield County. The subject site encompasses approximately 6.43 acres. The property is leased from Watson Ranches, Ltd., and the facility is operated by Ursa Operating, LLC. The objective of this analysis is to provide traffic data for the additional land use, review the existing road network, and provide traffic projections for public roads impacted by site traffic. EXISTING ROAD NETWORK Regional trips will use the I-70 West Parachute Interchange (Exit 72) southwest of Parachute, Colorado. A primary access route to the southwest of the site is expected to be used as the preferred route for out-of-area traffic to reach the Watson Ranch B site. These vehicles will drive west along the I-70 frontage road to CR 300 (Stone Quarry Road), then north and east along CR 300 to CR 300O. At this intersection, vehicles will turn right onto CR 300O (Old Stone Quarry Rd) and continue on and turn right onto CR 303 (Gardner Ln). From there the vehicles will turn left onto the Watson Ranch access road. This route follows Garfield County preferred haul roads for the entire length. Maps showing the access route, haul routes, and county roadways within one mile of the pad are included as an attachment at the end of this document. Table 1 tabulates roadway geometry and characteristics for the county roads used by vehicles visiting this site. County roads included in the table but not mentioned above area along the secondary haul route discussed in following. Watson Ranch B Injection Well February, 2015 Ursa Operating Company, LLC Basic Traffic Analysis Page 2 Table 1: Roadway Geometry and Characteristics Roadway Lanes Road Width Roadway Type Speed Limit Condition Year of Impmt. Functional Classification CR 300* 2 22’-24’ Asphalt 35 mph Good (’05) 2007 Local CR 300** 4 46’-52’ Asphalt 35 mph Good (’02) 2009 Local CR 300O 2 22’ Asphalt 35 mph Good (’02) 2006 Local CR 300N 2-4 26’-64’ Asphalt 35 mph Good (’02) 2007 Minor CollectorCR 303 2 22’ Asphalt 35 mph Good (’02) 2006 Local CR 308 2-4 22’-64’ Asphalt 35 mph Good (’05) 2008 Local CR 309 2 24’ Asphalt 35 mph Good (’02) 2007 Minor Collector*From I-70 Frontage to Parachute Way **From Parachute Way to CR 300O The Garfield County Road Inventory Report, 2011 Garfield County HUTF Report, and 2002 Garfield County Road & Bridge county-wide traffic study were all used to identify the roadway geometry and characteristics of the facilities being used by site traffic. BACKGROUND TRAFFIC Background traffic volumes were obtained from the 2014 Garfield County Road & Bridge county- wide traffic study and updated count data provided by Garfield County. The updated count data included 2014 counts at all roadways planned to be used for the Watson Injection Well. The background traffic volumes are shown in Table 2 below. Table 2: Background Traffic Roadway 2014 CR 300 500 CR 300O 240 CR 303 470 CR 300N 6840 CR 308 360 CR 309 255 TRIP GENERATION AND DISTRIBUTION Trip generation is generally determined using rates found in the ITE Trip Generation manual. Rates from this publication are applied to values related to the size of the proposed site to estimate the trips expected to enter and exit the site. In this case, no rates are provided for facilities similar to the injection well. To estimate trips expected for this site, information was gathered regarding the expected traffic based on the existing operations. Because this site will be an active well pad, a small number of trips will visit the site, typically two per day, for inspection of the wells in operation. Watson Ranch B Injection Well February, 2015 Ursa Operating Company, LLC Basic Traffic Analysis Page 3 Because an injection well is being constructed on an existing well pad site, there will be a short construction phase to add the infrastructure needed to inject produced water. This construction phase will last for approximately three (3) days. Daily traffic during that phase will include two (2) lowboys making two round trips (4 one-way trips) for equipment and tanks. One (1) additional lowboy would arrive on day 2 and leave on day 3 to transport an earthmover. There will be 2 pickups per day arriving in the morning and leaving at the end of the work day. Injection well activity includes the following. During the injection well drilling event, there would be 4-5 days at the beginning and end for mobilization and demobilization of equipment, respectively. During that time, there would be approximately twenty round trips (40 one way trips) per day distributed evenly through a ten-hour work day. These trips are considered to be affiliated with local drilling operations and are not mutually exclusive trips to the injection well. Vehicle trips outside the first and last weeks would be minimal including a daily pickup truck for monitoring. Production phase traffic is generated from several well pads, including Yater, Watson Ranch, Monument Ridge, Watson Ranch B, Speakman A, Speakman B, B&V, Stierberger, Richardson, and Tompkins. Each well has the potential to produce approximately five (5) trucks (10 one-way trips) per day. These trips are assumed to arrive evenly throughout the ten-hour work day. Produced water from the aforementioned sites may be delivered to the Tompkins, Watson Ranch B, and Speakman A injection wells after their construction. Ursa indicated that water from Speakman A and Speakman B pads will rarely be transported to the Watson Ranch B site. Watson Ranch will deliver water to Watson B, but is located adjacent to Watson Ranch B and will have direct access to the proposed injection well. There is an existing pipeline that runs from Monument Ridge to Watson Ranch and, it is expected that a pipeline running from the Yater site will service the injection well at Watson Ranch B immediately after construction. With the elimination of trips from the Watson Ranch, Watson Ranch B, Yater, Monument Ridge, Speakman A, and Speakman B pads, total traffic on public roads generated as a result of this site will ultimately result in forty (40) one-way trips, ten each for the B&V, Stierberger, Richardson, and Tompkins pads. Traffic traveling to and from the Tompkins and B&V pads, including maintenance vehicles, will follow the preferred haul route to the west along the I-70 frontage road and then to the site by way of CR 300. Trips to and from the Stierberger and Richardson pads will follow the preferred haul route to the south along CR 308. These haul routes, along with a secondary haul route map for the Tompkins and B&V pads, are provided as an attachment at the end of the document. Watson Ranch B Injection Well February, 2015 Ursa Operating Company, LLC Basic Traffic Analysis Page 4 Based on the background traffic, traffic volume increases related to the additional use as an injection well are summarized in Table 3 below. Table 3: Injection Well Background Traffic Projections Roadway Background Traffic Construction & Drilling* Total Traffic Incr. Operations Total Traffic Incr. CR 300 500 40 540 7% 22 522 4% CR 300O 240 40 280 14% 22 262 8% CR 303 470 40 510 8% 22 492 4% CR 300N 6840 - 6840 - 12 6852 <1% CR 308 360 - 360 - 22 382 5% CR 309 255 - 255 - 12 267 4% *Traffic during mobilization/demobilization for first and last weeks of 13‐week phase   ROADWAY ANALYSIS Existing Parcel Current land use on the subject parcel is a mix of agricultural and natural gas development with a residence for a tenant. State Highway Crossings and Access The roadway access to this site does not cross any highway rights-of-way managed by the Colorado Department of Transportation. CR 300 is accessed directly from Highway 006M approximately 4.25 miles southwest of Parachute. Note that the primary haul route passes between the Parachute interchanges on I-70. Trucks will use either the interstate or the I-70 frontage road (Highway 006M). There is I-70 access at the Parachute interchange (Exit 75) and the Parachute West interchange (Exit 72). The ramp terminals at the Parachute West interchange are grade-separated with roundabouts as traffic control. Site distances are adequate in both directions at these ramp terminals. The US Highway 6 / I-70 Frontage Road intersects CR 300 approximately 2.5 miles southwest of the Parachute West interchange. This is a two-way stop-controlled intersection with CR 300 as the minor roadway. Left-turn and right-turn deceleration lanes are provided the highway. Railroad Crossings There is an at-grade crossing on CR 300 adjacent to the Highway 006M intersection. There is adequate sight distance at the crossing. The crossing is also equipped with gates and flashers. The roadway access to this site does not cross any other active railroad rights-of-way. For sight distance calculations at all intersections, the design vehicle used was a single-unit truck with a major road speed limit of 35 mph. Watson Ranch B Injection Well February, 2015 Ursa Operating Company, LLC Basic Traffic Analysis Page 5 Intersection of CR 300 & CR 300O The intersection of CR 300 & CR 300O is a stop controlled “T” intersection. Intersection sight distance looking north and west from CR 300O is adequate for a single unit truck as measured from the stop bar. To determine minimum intersection sight distance at this intersection and subsequent ones in this study, the design vehicle was assumed to be a single-unit truck making a minor-road left turn with a major road speed limit of 35 mph (490’). An additional 70’ was considered for trucks turning onto Stone Quarry Road (CR 300), as this is a four-lane divided roadway at this intersection. Intersection of CR 300O & CR 303 The intersection of CR 300O & CR 303 is a “T” intersection with CR 303 as the stop-controlled minor approach. Sight distance is adequate looking north and south from the stop bar. Intersection of CR 300N & CR 309 The intersection of CR 300N & CR 309 is a “T” intersection with CR 309 as the stop-controlled minor approach. This intersection is along the horizontal curve of CR 300N. However, sight distance is adequate looking west and south from the stop bar on CR 309. Intersection of CR 308 & CR 303 The intersection of CR 308 & CR 303 is a “T” intersection with CR 308 as the stop-controlled minor approach. Sight distance is adequate looking west and east from the stop bar. To the west of this intersection CR 303 ends and becomes a private gravel road to access private residences and other pad sites. CONCLUSIONS Based on the expected trip generation rates discussed above, the increase in average daily traffic is not expected to be significant on roads generally used by the public. The county roads discussed will see only a minor increase in traffic as compared to existing traffic volumes. The addition of traffic generated by the proposed project use does not increase existing volumes to levels required for State or County permits. The geometry at all intersections where site traffic will be turning is expected to be adequate for site traffic. Attachments Primary Haul Route/Volumes Map Secondary Haul Route Map LEGEND "' -Site Location -Primary Haul Roule x.xxx -Background ADT x.xxx -Drllllng & Comple1lons ACT x.xxx -Operations ACT Um Kfltson Ranch B Gatfield County, CO I 1~1 ------------------------1 '-=I~ FIGURE OLSSON ® Primary Haul RouteNolumes Map ASSOCIATES 1 LEGEND "' -Site Location -Secondary Haul Route Um Kfltson Ranch B Gatfield County, CO I 1~;...__ _________________ ---1 <.:1~ O\oLssoN ® FIGURE Secondary Haul Route Map ASSOCIATES 2 Article 4-203.M Water Supply and Distribution Plan Ursa Operating Company LLC Watson Ranch B Injection Well OA Project No. 014-3005 760 Horizon Drive, Suite 102 TEL 970.263.7800 Grand Junction, CO 81506 FAX 970.263.7456 www.olssonassociates.com URSA OPERATING COMPANY LLC WATSON RANCH B INJECTION WELL WATER SUPPLY AND DISTRIBUTION PLAN Section 4-203.M. Water Supply and Distribution Plan. The Ursa Watson Ranch B Injection Well facility does not require potable water source for personnel or freshwater for sanitary facilities, landscaping or day to day operations of the facility. The operations of the facility will be similar to other natural gas operations in Garfield County. No potable water will be provided at this facility. The proposed use is an unmanned facility with personnel onsite only for short intervals. Personnel provide their own potable water carried in their vehicles. Ursa Resources makes potable water available at their field office to staff and contractors. Sanitary facilities will not require a source of water and will be provided by portable toilets located on site and at numerous sites in the field per OSHA standards. Landscaping is not being proposed, and a water system is not required to maintain any plantings. The Watson Ranch B Injection Well facility does not use potable or fresh water in its daily operation. Ursa Operating Company LLC Watson Ranch B Injection Well Water Supply and Distribution Plan Page 2 THIS PAGE LEFT BLANK FOR TWO-SIDED DUPLICATION. Article 4-203.N Wastewater Management and System Plan Ursa Operating Company LLC Watson Ranch B Injection Well OA Project No. 014-3005 760 Horizon Drive, Suite 102 TEL 970.263.7800 Grand Junction, CO 81506 FAX 970.263.7456 www.olssonassociates.com URSA OPERATING COMPANY LLC WATSON RANCH B INJECTION WELL WASTE MANAGEMENT AND SYSTEM PLAN Section 4-203.N. Wastewater Management and System Plan. The operations of the facility will be similar to other natural gas operations in Garfield County. Staff will not be assigned to the facility on a regular basis. Personnel will be at the facility only for short periods of time. Workers will be providing facility maintenance and inspections. Sanitary facilities are provided by portable toilets placed on site per OSHA standards. These portable toilets are maintained by Redi Services and Western Colorado Waste. All waste is hauled to a licensed treatment facility. “Will Serve” letters are provided documenting the maintenance of these sanitary facilities. Ursa Operating Company LLC Watson Ranch B Injection Well Wastewater Management and System Plan Page 2 THIS PAGE LEFT BLANK FOR TWO-SIDED DUPLICATION. 2143 Airport Road, Rifle, Colorado 81650 Phone (970)625-0233 Fax (970)625-0232 Subject: Will Serve Letter 217 /2014 Company-;-Ursa Resources Redi Services will provide Ursa Resources with Porta John Units on their designated locations. Redi Services will service and maintain the units and dispose of the waste at an approved disposal site. At this time we are disposing of the waste at the West Garfield County Landfill and the South Canyon Landfill. Thanks, WESTERN COLORADO WASTE, INC Mailing Address : P. 0 . Box 26 Mack, CO 81525 Hank Bounds -Trash : (970) 210-2330 Terry Forrest -To ilets: (970) 216-5668 Fax : (970) 255-7080 Re: Roll -off Trash Containers, Portable Toilets To whom it may concern, Western Colorado Was t e, Inc. provides roll-o ff trash containers and portable toilet service to Ursa in the Silt, Rifle, Battlement Mesa, and Parachute ar eas of Colorado. Toilets are serviced on a weekly basis, or as requested by Ursa. The waste is disposed of at one of three locations. Trash is disposed at Garfield Co. landfill only. Garfield Co. Landfill, Rulison, CO Clifton Sanitation, Clifton, CO Persigo Wastewater Treatment Facility, Grand Junction, CO Thank you , ;zz~;~~,-~s Western Colorado Waste, Inc. 970-210-2330 Article 7 Standards Analysis Ursa Operating Company LLC Watson Ranch B Injection Well OA Project No. 014-3005 760 Horizon Drive, Suite 102 TEL 970.263.7800 Grand Junction, CO 81506 FAX 970.263.7456 www.olssonassociates.com Article 7 – Standards Analysis Ursa Operating Company LLC Watson Ranch B Injection Well DIVISION 1. GENERAL APPROVAL STANDARDS SECTION 7-101. ZONE DISTRICT USE REGULATIONS Small Injection Wells are allowed upon review and approval of an Administrative Review application within the Rural zone district. SECTION 7-102. COMPREHENSIVE PLAN AND INTERGOVERNMENTAL AGREEMENTS The overall project facility generally conforms to the Garfield County Comprehensive Plan. The proposed use is not within an area governed by an intergovernmental agreement. SECTION 7-103. COMPATIBILITY The proposed facility is consistent with current uses on the subject parcel and adjacent properties. The proposed injection well will be located on a natural gas well pad which will be screened visually from the adjacent Battlement Mesa PUD. The proposed injection well is compatible with the current use of the project site. SECTION 7-104. SOURCE OF WATER A source of potable water will not be required for workers utilizing the site. This facility is not manned on a regular basis and does not require a fresh water distribution and wastewater system to properly function. Workers will provide their own potable water in their trucks. Ursa will provide personnel bottled or potable water at their field office. A source of water is not required for the operation of the facility. Water will not be required for the operation of sanitary facilities. Portable toilets will be used, and all wastes will be hauled to a licensed treatment facility. Water will not be required for landscaping. No landscaping is proposed at this site. Water to be injected into the proposed injection well is generated by Ursa’s natural gas production assets in the Piceance region. Water delivered to the facility will not infringe on any existing water rights. The produced water generated from Ursa’s natural gas production operations is a result of Ursa’s drilling operations within the Williams Fork Formation. This formation is classified as a nontributary formation. Details specific to the nontributary nature of the water that will be delivered to the proposed injection well are provided in this submittal. The proposed injection well will not place a demand on local groundwater resources. The proposed injection well will be used to dispose of produced water from Ursa’s operations only. Ursa Operating Company, LLC Watson Ranch B Injection Well Standards Analysis Page 2 The injection permit applications (COGCC Forms 31 and 33) will be submitted to the Colorado Oil and Gas Conservation Commission (COGCC). The COGCC review process is intended to address any issues related to potential impacts to groundwater. This well will be operated in strict accordance with COGCC regulations and the approved permit criteria and conditions of approval. Other required COGCC forms will be submitted when appropriate. Produced water will be hauled to the proposed facility via pipeline or water truck from the various Ursa Piceance Basin locations. A pipeline will be constructed to pipe produced water to the injection well in order to cut down on the number of trucks needed to haul water and to decrease opportunities for environmental impacts due to water hauling by truck. B. Determination of Adequate Water The proposed injection well will not place a demand on local groundwater resources. The water disposed of is a result of Ursa’s drilling operations within the Williams Fork Formation. This formation is classified as a nontributary formation. Details specific to the nontributary nature of the water that will be delivered to the proposed facility are provided in this submittal. SECTION 7-105. CENTRAL WATER DISTRIBUTION AND WASTEWATER SYSTEMS A. Water Distribution System The proposed injection well facility will be unmanned. This facility will not require potable or fresh water distribution within the facility. B. Wastewater System No water is required for sanitary services at the site. The site will be served by porta- johns provided and serviced by Redi Services or Western Colorado Waste. “Will Serve” letters are included in this submittal in the Wastewater Management Section. SECTION 7-106. PUBLIC UTILITIES A. Adequate Public Utilities Adequate Public Utilities shall be available to serve the land use. Holy Cross Energy will provide electrical service to the pad. A “Will Serve” letter can be found at the end of this section. Other public utilities are not required. B. Approval of Utility Easement by Utility Company All appropriate easements have been or will be secured as part of the electrical installation process. C. Utility Location Any power line enlargements, relocations, and new extensions necessary to deliver adequate power to and within the development will be undertaken by Holy Cross Energy upon completion of appropriate contractual agreements and subject to necessary governmental approvals. Ursa Operating Company, LLC Watson Ranch B Injection Well Standards Analysis Page 3 D. Dedication of Easements All appropriate easements have been or will be dedicated to the public as part of this process. E. Construction and Installation of Utilities Holy Cross Energy will provide electrical power to the site. A copy of the “Will Serve” letter is provided at the end of this section. Utilities will be installed in a manner that avoids unnecessary removal of trees or excessive excavations and will be reasonably free of physical obstructions. F. Conflicting Encumbrances Holy Cross Energy will provide electrical power to the site. All appropriate easements will be free from encumbrances. SECTION 7-107. ACCESS AND ROADWAYS The proposed injection well facility will require construction of a portion of a new road as part of the complete well pad development. The use will utilize the existing access off of CR 303 (Gardner Lane) to the Watson Ranch well pad. Further access will be constructed from the Watson Ranch access road to the Watson Ranch B well pad. No traffic will be routed through the Battlement Mesa area during operation of this facility. A. Access to Public Right of Way No new public roads are proposed to accommodate the proposed injection well facility. Access to the subject property is from County Road 303 via a private roadway. Access is granted via an easement identified in the First Amendment to the Surface Use and Easement Agreement between Watson Ranches, Ltd and Ursa, dated September 11, 2014. A driveway permit, GRB09-D-40, was obtained by Antero Resources for the Watson Ranch access road in 2009. B. Safe Access The road functions adequately for its intended use and is typical of existing roads providing access to natural gas production facilities in Garfield County. C. Adequate Capacity The road functions adequately for its intended use and is typical of existing roads providing access to natural gas production facilities in Garfield County. See Traffic Analysis and Road Assessment reports included with this application for additional details. D. Road Dedication No new public roads are being built or dedicated as part of this project. Ursa Operating Company, LLC Watson Ranch B Injection Well Standards Analysis Page 4 E. Impacts Mitigated County roads from the Tompkins, B&V, Stierberger, and Richardson pads to the Watson Ranch B well pad will experience impacts from this project that are characteristic of existing natural gas development in the region due to trucks hauling produced water from those pads to injection well at the Watson Ranch B pad. No pipelines are anticipated from those pads to the Watson Ranch B pad at this time. Produced water will be transported via truck from the Speakman A and B pads on a very limited basis when the Speakman A well pad cannot accommodate the volumes being produced by those two pads. Pipelines will carry produced water from the Monument Ridge and Yater pads to the Watson Ranch pad and then to the Watson Ranch B injection well. Based on the expected trip generation rates discussed in the Basic Traffic Study, the increase in average daily traffic is not expected to be significant on roads generally used by the public. The county road will see only a minor increase in traffic as compared to existing traffic volumes. The addition of traffic generated by the proposed site does not increase existing volumes to levels required for State or County permits. The geometry at all intersections where site traffic will be turning is expected to be adequate for site traffic. The existing roadway and access are adequate for the anticipated low traffic volumes. No formal mitigation will be required for this project. Dust from the private roadway will be mitigated as appropriate. See the Traffic Analysis for further information. F. Design Standards The existing and proposed access roads meet most of the standards for the Semi- Primitive road. The private access road deviates from the design standards for ROW width, shoulder width, ditch width, cross slope, shoulder slope and surface. See Road Assessment Report included in this submittal for further details. A Waiver of Standards request is included in this submittal. SECTION 7-108. USE OF LAND SUBJECT TO NATURAL HAZARDS According to the Geologic Hazard Report, the project area is not subject to avalanche, landslide, rock fall, alluvial fan, shrink-swell potential, collapsible soils, or faults. There are existing wells on the location, and there is other development in the area. No flood prone areas are mapped in the vicinity of the site. Flash flooding is a hazard for lower elevations along Battlement Creek, Monument Gulch, and areas along the Colorado River. There are unnamed drainages located approximately 130 feet to the north; however, it is expected that these drainages do not pose a significant flooding hazard. There are no mining activities shown in the vicinity of the site. Natural gas well drilling has been conducted in the area since the 1960s. There are no significant radioactive mineral deposits known in the immediate area of the site. The presence of NORM may be an issue with exploration and production and could be an issue Ursa Operating Company, LLC Watson Ranch B Injection Well Standards Analysis Page 5 with used pipe scale or used equipment. Radioactive materials are not expected to pose a significant hazard at the site. SECTION 7-109. FIRE PROTECTION A. Adequate Fire Protection The proposed injection well is located within the Grand Valley Fire Protection District. The District is aware of the well pad location and can provide adequate fire protection/response. Ursa is willing to provide training to the District regarding the site operations if requested. B. Subdivisions This standard does not apply as the proposed land use is not a subdivision nor located within a subdivision. DIVISION 2. GENERAL RESOURCE PROTECTION STANDARDS SECTION 7-201. AGRICULTURAL LANDS A. No Adverse Affect to Agricultural Operations The operation of the proposed injection well will not adversely affect agricultural operations on the subject property or adjacent lands. B. Domestic Animal Controls The operation of the proposed facility will comply with this standard. No domestic animals are allowed on the site. C. Fences The facility will not generate a potential hazard to domestic livestock or wildlife . No open storage of hazardous materials or attractions will be conducted on the site. The site will be enclosed within a visual and sound buffer that also serves to protect the facility from possible livestock damage through the completion activities of the natural gas drilling on the site. A temporary 2-strand electric fence may be erected around the facility if the surface owner requests to keep grazing cattle off of the well pad. D. Roads The proposed facility will not impact adjoining roadways beyond current impacts due to the anticipated low operational traffic volumes. The Project Description and Traffic Study describe the proposed access. Additional details are shown on the site plan. The proposed injection well facility will not require construction of new roads beyond the access road to be constructed from the Watson Ranch A to the Watson Ranch B COGCC permitted well pad. The use will utilize existing access constructed for the Watson Ranch A well pad from CR 303 (Gardner Lane). Ursa Operating Company, LLC Watson Ranch B Injection Well Standards Analysis Page 6 E. Irrigation Ditches There are several irrigation ditches close to the proposed Watson Ranch B well pad. The Irrigation Water Catch Ditch that runs through the northern part of the proposed site will be rerouted around the well pad. The irrigation ditches that run through the southeast corner and southern edge of the proposed pad will be rerouted around the well pad. Implementation of the engineered grading and drainage plan and conformance with stormwater best management practices (BMPs) will assure that any irrigation ditches on the subject parcel will not be impacted by sedimentation or stormwater runoff from the facility. SECTION 7-202. WILDLIFE HABITAT AREAS A. Buffers The pad where the injection well will be located will require approximately 6.85 acres of surface disturbance and vegetation removal. The affected area is primarily composed of grasses planted for hay production and livestock pasture. Native vegetation surrounding the site is consistent with sagebrush communities and pinyon-juniper woodlands that occur in the Colorado River valley corridor. The proposed site will be surrounded by an enclosure which provides visual and sound buffers to the surrounding properties and thus from habitat areas. B. Locational Controls of Land Disturbance The proposed injection well is located on a COGCC approved well pad and no additional surface disturbance will be required beyond the construction of the new well pad. No migration corridors are affected. Human presence and activity may affect animal distribution by creating avoidance areas and increasing stress on wintering big game. Over time, deer and elk that winter in this area have become habituated to human activity and the indirect effects of avoidance and displacement have decreased. An increase in vehicle traffic could result in additional vehicle related wildlife mortality, although additional traffic resulting from this project would contribute minimally, given current traffic volumes on the existing county road. Fences can pose an increased risk to big game, and any fencing around the facility will be constructed according to published standards that reduce impacts to big game. Equipment is outfitted with bird cones to prevent perching. C. Preservation of Native Vegetation 1. Very little native vegetation will be removed for development of the injection well since the project will be placed in an agricultural area where native vegetation has previously been removed. 2. Application of the Integrated Vegetation and Noxious Weed Management Plan (IVNWMP) and Ursa’s Noxious Weed Management Plan will provide a degree of mitigation for the native vegetation that has already been removed. Ursa will also Ursa Operating Company, LLC Watson Ranch B Injection Well Standards Analysis Page 7 comply with COGCC Rule 1002 regarding revegetation and control of noxious weeds. 3. Vehicles and equipment traveling from weed-infested areas into weed-free areas could disperse noxious or invasive weed seeds and propagates, resulting in the establishment of these weeds in previously weed-free areas. Several simple practices will be employed to prevent most weed infestations. The following practices may be adopted for any activity to reduce the costs of noxious weed control through prevention. The practices include:  Prior to delivery to the site, equipment should be thoroughly cleaned of soils remaining from previous construction sites which may be contaminated with noxious weeds.  If working in sites with weed-seed contaminated soil, equipment should be cleaned of potentially seed-bearing soils and vegetative debris at the infested area prior to moving to uncontaminated terrain.  All maintenance vehicles should be regularly cleaned of soil.  Avoid driving vehicles through areas where weed infestations exist. D. Habitat Compensation Placement of this project within the boundaries of a COGCC approved well pad will result in avoidance of additional contributions to cumulative effects of habitat alteration and fragmentation in the region. The proposed well pad is located on agricultural pasture land. The development of the project is not expected to significantly affect any critical environmental resources. E. Domestic Animal Controls Livestock and big game will likely avoid the project site. Dogs and other domestic animals are not allowed on site. SECTION 7-203. PROTECTION OF WATERBODIES A. Minimum Setback 1. The proposed natural gas well pad, where the proposed injection well will be located, is planned to be built in an irrigated pasture and approximately 6.85 acres of surface disturbance will be required. One natural drainage and several irrigation ditches will be affected. No Army Corps of Engineers (ACOE) jurisdictional wetlands would be affected by the project. 2. There are no entrenched or incised streams on or adjacent to the proposed project site. 3. No hazardous material will be stored on the project site. Please see SPCC Plan included in this submittal for measures to protect surface and ground water from spills. The SPCC Plan does not include site specific information for the proposed well Ursa Operating Company, LLC Watson Ranch B Injection Well Standards Analysis Page 8 pad. Final site specific information is required within six months of completion of construction at the site, so that as built conditions are shown. B. Structures Permitted in Setback No structures will be located within the 35 foot setback. C. Structures and Activity Prohibited in Setback No structures will be located within the 35 foot setback . No work of any kind will occur within the 35 foot setback. D. Compliance with State and Federal Laws The proposed injection well will not impact any Waterbody of the US. SECTION 7-204. DRAINAGE AND EROSION A. Erosion and Sedimentation The proposed injection well will not require clearing or vegetation removal beyond the COGCC approved well pad area. BMPs such as sediment basins, top soil berms and wattles will be utilized to ensure the continued protection of water bodies from stormwater runoff during construction and operation of the facility. B. Drainage 1. This standard requires that lots be laid out to provide positive drainage. Lots are not proposed as part of this land use application. The proposed project will not create any impacts to existing drainage patterns. 2. This standard also addresses individual lot drainage within a residential development and is not applicable to this use. The proposed facility will not impact natural drainage patterns. C. Stormwater Run-Off The site has been designed to COGCC standards for stormwater management to control stormwater runoff in a manner that minimizes erosion, transport of sediment offsite, and site degradation. BMPs will be maintained until the facility is abandoned and final reclamation is achieved pursuant to COGCC Rule 1004. The proposed injection well site is not within 100 feet of a Waterbody, and it will not create 10,000 square feet or more of impervious surface area. The well pad will be graveled. 1. Avoid Direct Discharge to Streams or Other Waterbodies. Stormwater Runoff from the project areas will be controlled by use of BMPs such as sediment basins, top soil berms and wattles. 2. Minimize Directly-Connected Impervious Areas. The site design will not create more than 10,000 square feet of impervious surface area. Ursa Operating Company, LLC Watson Ranch B Injection Well Standards Analysis Page 9 3. Detain and Treat Runoff. Ursa has incorporated a number of stormwater detention facilities into the design for this site. Stormwater runoff will be controlled via a combination of sediment basins, top soil berms and wattles. a. Due to the magnitude of the contributing basins, and low imperviousness of the proposed developments, flow from the two inspected basins will not be altered greatly by the addition of the proposed pad, and thus there will be no 25-year detention on the site. The larger impact of the developments is with regards to water quality and protecting the surrounding environment. Sediment traps, 8 ft x 6 ft in size, are proposed at each ditch discharge point for water quality measures and possible secondary spill containment. b. The project site is above the 100- and 500-year floodplain of the Colorado River, therefore a 100-year storm event should not cause property damage. c. Channels downstream from the stormwater detention pond discharge have been designed to prevent increased channel scour, bank instability, and erosion and sedimentation from the 25-year return frequency, 24-hour design storm. d. See item 3.a above for details related to the need for detention. e. All culverts, and drainage pipes, utilized at this facility are designed and constructed according to the AASHTO recommendations for a water live load. SECTION 7-205. ENVIRONMENTAL QUALITY A. Air Quality The injection well will not require an air quality permit or Air Pollution Emissions Notice (APEN). Any associated equipment that emits greater than two tons per year criteria pollutants, i.e. production tanks, will need an APEN. The injection well will be fed by an electric pump. This pump is exempt from an air permit/APEN. The only APEN required for the Watson Ranch B injection well facility is specific to the injection well storage tank battery. Ursa will obtain the appropriate air quality permits prior to commencing operation of the injection well. B. Water Quality No hazardous materials will be stored on site. An SPCC plan will be in effect for the tank batteries associated with the injection well. A copy of the plan is included with this submittal. SECTION 7-206. WILDFIRE HAZARDS A. Location Restrictions The proposed injection well facility is not located in an area designated as a severe wildfire hazard area according to the Garfield County on-line GIS map resources, nor is it located within a fire chimney as identified by the Colorado State Forest Service. Ursa Operating Company, LLC Watson Ranch B Injection Well Standards Analysis Page 10 B. Development Does Not Increase Potential Hazard The proposed injection well will not increase the potential intensity or duration of a wildfire, or adversely affect wildfire behavior or fuel composition. C. Roof Materials and Design Roof materials for the pump house will be made of noncombustible materials. Any proposed construction will comply with requirements of the 2003 International Fire Code. SECTION 7-207. NATURAL AND GEOLOGIC HAZARDS A. Utilities Trenches for water pipelines, natural gas pipelines, and electrical lines are expected to be associated with the proposed development. The slopes and corrosive soil may pose technical challenges to the installation of these utilities; however, it is expected that these limitations can be overcome with proper design and installation. B. Development in Avalanche Hazard Areas Avalanche conditions are not expected to be present in area of the Site. C. Development in Landslide Hazards Areas The site is located on mudflow and fan gravels overlying alluvial terrace deposits and bedrock consisting of the Wasatch Formation. The site is within the town limits for Battlement Mesa, but outside the planned unit development (PUD), and there are existing gas wells and other structures in the area. The landslide, alluvial terrace, and fan gravels are not expected to constitute a geologic hazard for the Watson Ranch B UIC site development. D. Development in Rockfall Hazard Areas Rockfall areas are not present in the area of the site and are not expected to be a geologic hazard affecting the site. E. Development in Alluvial Fan Hazard Area The site is not in an area mapped as an alluvial fan hazard area; however, the site is underlain by alluvium and fan gravels. The area has been mapped at large scale as landslide deposits. These landslide deposits formed at the end of the last ice age when the climate was wetter, and are not expected to pose a hazard to the proposed Watson Ranch B UIC well site. F. Slope Development Slope is listed as a moderate limitation for the Potts loam (Unit #56) soils and a severe limitation for the Potts-Ildefonso complex (Unit #58); however, it is expected that with appropriate design and engineering controls, the site can be developed for its intended use. Ursa Operating Company, LLC Watson Ranch B Injection Well Standards Analysis Page 11 G. Development on Corrosive or Expansive Soils and Rock The Potts loam and Potts-Ildefonso complex soils are listed as a high corrosion risk to uncoated steel, but the potential of corrosion to concrete is moderate to low. Corrosion can be mitigated by coating steel or by using appropriate cathodic protection, and using concrete formulation that is resistant to corrosion. The Potts loam and Potts-Ildefonso complex soils have a low shrink-swell potential. Expansive soils are not a hazard at the Watson Ranch B UIC site. H. Development in Mudflow Areas Collapsible soils are not present in the vicinity of the proposed Watson Ranch B UIC site. I. Development Over Faults No significant faults have been mapped or are known in the Watson Ranch B UIC site. SECTION 7-208. RECLAMATION A. Applicability No ISDS will be installed. No new access is being proposed beyond the access road from the Watson Ranch A well pad to the proposed Watson Ranch B well pad. The injection well will be drilled on an approved COGCC well pad. Ursa will abide by all reclamation requirements set out by COGCC Rules 1003 and 1004 for interim and final reclamation. All of Ursa’s surface disturbances are covered under a statewide bond, held by the COGCC. B. Reclamation of Disturbed Areas A copy of Ursa’s Reclamation Plan is included in this submittal. Areas disturbed during development will be restored as natural-appearing landforms that blend in with adjacent undisturbed topography at the end of the life of the injection well. 1. Contouring and Revegetation. Areas disturbed by grading will be contoured so they can be revegetated as appropriate for interim and final reclamation. At the end of the life for the well pad, it will be planted and have vegetation established and growing based on 70% coverage as compared with the original on-site vegetation within 2 growing seasons of reclamation, using species as noted in the accompanying Reclamation Plan. 2. Application of Top Soil. Top soil will be stockpiled as berms around the perimeter of the well pad. Unused top soil will be stockpiled and vegetated temporarily to reduce erosion until it can be reused during reclamation. 3. Retaining Walls. No retaining walls are planned for this project. 4. Slash Around Homes. No residences will be part of the proposed project. Ursa Operating Company, LLC Watson Ranch B Injection Well Standards Analysis Page 12 5. Removal of Debris. The proposed injection well will be located on a COGCC approved natural gas well pad. All debris will be disposed of appropriately. 6. Time Line Plan. The site will be reclaimed in 20-30 years, at the end of the life for the natural gas wells serving the injection well. DIVISION 3. SITE PLANNING AND DEVELOPMENT STANDARDS SECTION 7-301. COMPATIBLE DESIGN Operation of the proposed facility will be consistent with nearby uses. The facility will be unmanned, except during times of water deliveries and maintenance. There will be minimal impacts to the existing roadway system during the operational phase. A. Site Organization The site has one access point to Gardner Road at the southern edge of the project site. The site will be organized to provide safe access to and from the site and parking off the public right-of-way. It will not disrupt solar access to adjacent properties, pedestrian access, nor access to common areas along Gardner Road. B. Operational Characteristics 1. Adjacent lands will not be impacted by the generation of vapor, odor, smoke, glare, noise or vibration beyond the impacts already associated with the operation of the existing natural gas well pad. Generation of dust will be mitigated by use of water or other additives to the road ways to decrease/prevent the generation of dust caused by vehicles accessing the well pad. All lighting will be downcast, shielded, and directed inward to avoid excessive glare. A sound wall will be erected around the well pad to mitigate noise during natural gas drilling and completion activities. The projected sound pressure will not exceed the COGCC and Garfield County Standards for Residential/Agricultural/Rural zones. 2. The pump for the injection well will be powered by electricity and will be located within a pump house. Noise will not exceed State noise standards pursuant to COGCC Rule 802 regarding noise and abatement. 3. Typical hours of operation will be 7:00 am to 6:00 pm, although the site is available to personnel 24 hours a day, in case of emergency. C. Buffering D. The well pad where the proposed injection well will be located will be buffered to mitigate visual and noise impacts to adjacent property during natural gas drilling and completion activities. Ursa Operating Company, LLC Watson Ranch B Injection Well Standards Analysis Page 13 E. Materials Tanks, buildings, and equipment will be painted to blend in with the surrounding landscape. SECTION 7-302. OFF-STREET PARKING AND LOADING STANDARDS Adequate parking will be made available to accommodate Ursa personnel during regular operation, inspection, and maintenance of the facility. All activities on this site will be conducted out of any public right-of-way. All off-loading and loading will take place on the well pad out of the public right-of-way. See Site Plan for truck circulation related to water delivery. Loading and unloading of vehicles will take place in a manner that will not interfere with the flow of traffic on Gardner Road. Parking and loading surfaces have been designed by an engineer to ensure proper drainage of surface and stormwater. See Grading and Drainage Plan section of this submittal. Traffic circulation patterns on site will be such that no vehicle will be required to back on to the public right-of-way. The access driveway for the proposed injection well runs to the south off of the well pad to Gardner Road. The apron to Gardner Road is constructed to accommodate the tanker trucks typical for hauling produced water. The driveway has a clear vision area of 300 feet to the east and west. See the Traffic Study for more information. A. Parking and Loading Area Landscaping and Illumination No landscaping is planned for the proposed project site. Any illumination will be downcast and shielded per Garfield County standards. SECTION 7-303. LANDSCAPING STANDARDS This type of industrial use is exempt from the landscape standards of the Development Code. SECTION 7-304. LIGHTING STANDARDS A. Downcast Lighting Any lighting will be directed inward, towards the interior of the site. B. Shielded Lighting Any exterior lighting will be shielded so as not to shine directly onto other properties. C. Hazardous Lighting Light from the site will not create a traffic hazard or be confused as traffic control devices. Ursa Operating Company, LLC Watson Ranch B Injection Well Standards Analysis Page 14 D. Flashing Lights The facility will not contain flashing lights. E. Height Limitations There will be no light sources exceeding 40 feet in height on the site. SECTION 7-305. SNOW STORAGE STANDARDS Snow will be stored in a vacant section of the existing disturbed area. The site will be graded to accommodate snowmelt to insure sufficient drainage. SECTION 7-306. TRAIL AND WALKWAY STANDARDS A. Recreational and Community Facility Access The proposed site is located in a rural area of Garfield County. A connection to public facilities is not appropriate or feasible. DIVISION 10. ADDITIONAL STANDARDS FOR INDUSTRIAL USES SECTION 7-1001. INDUSTRIAL USE A. Residential Subdivisions This site is not located in a platted residential subdivision. B. Setbacks The proposed injection well is located more than 100 feet from all adjacent property lines. C. Concealing and Screening This site is located in a rural area. It is currently screened to mitigate visual impacts to the surrounding area. Aboveground facilities will be managed to minimize visual effects (e.g. painted to blend with environment). D. Storing All products will be stored in compliance with all national, state and local codes and will be a minimum of 100 feet from adjacent property lines. E. Industrial Wastes All industrial wastes will be disposed of in a manner consistent federal and state statutes and requirements of CDPHE and COGCC. F. Noise No significant sound impacts will be generated from the facility. A sound barrier will be erected and will remain in place through completions of the natural gas wells to minimize Ursa Operating Company, LLC Watson Ranch B Injection Well Standards Analysis Page 15 noise. Water truck loading and unloading operations will be conducted to minimize noise impacts as much as possible. The occasional pickup truck for maintenance and monitoring purposes will not impact surrounding operations and properties beyond the impacts of the current natural gas operations on the well pad. Pumps for the injection well are electric and will be housed in a building to reduce any potential noise impacts. Operation of the facility will not exceed the Residential/Agricultural/Rural Zone Standards and Colorado Noise Statute 25-12-103 requirements. G. Ground Vibration Ground vibration will not be measurable at any point outside the property boundary. H. Hours of Operation The facility will not generate noise, odors, or glare beyond the property boundaries greater than what is allowed under the Land Use Development Code. Activities that do generate these impacts within the established standards will occur between the hours of 7:00 am and 6:00 pm Monday through Saturday. I. Interference, Nuisance, or Hazard Adjacent lands will not be impacted by the generation of vapor, dust, smoke, noise, glare, or vibration beyond those impacts of the current natural gas activities taking place on the well pad. Ursa will apply the appropriate level of controls to accommodate potential impacts via adherence to CDPHE Air Quality regulations and the implementation of industry BMPs included in the SWMP and Ursa’s dust control plan. The pad and access road will be graveled to reduce fugitive dust, which will be controlled using water or other dust suppressants. This proposed use will comply with Colorado Revised State Statutes and COGCC Rules regarding noise impacts at all times. Ursa Operating Company, LLC Watson Ranch B Injection Well Standards Analysis Page 16 THIS PAGE LEFT BLANK FOR TWO-SIDED DUPLICATION. November 19, 2014 Ursa Operat i ng Company LL C. Attn : Mr . Honeycutt 792 Buckhorn Drive Rifle, CO 81650 RE: BM Watson Ranch B. Pad Dear Mr . Hon eycutt: 3799 HIGHWAY 82 ·P.O. BOX 2150 GLE NWOOD SPRI NGS, COLORADO 8 1602 (970) 945 -5 491 ·FAX (970) 945-4081 The above mentioned development is within the certificated service area of Holy Cross Energy. Holy Cross Energy has existing power facilities located on or near the above mentioned project . These existing facilities have adequate capacity to provide electric power to the development, subject to the tariffs, rules and regulations on file . Any power line enlargements , relocations , and new extensions necessary to deliver adequate power to and within the development will be undertaken by Holy Cross Energy upon completi on of appropri ate contractual agreements and subject to ne ce ssary governmental approvals . Please advise when you wish to proceed with the development of the electric system for this project. Sincerely, HOLY CROSS ENERGY Allen Goad , Engineering Department agoad @holycross.com (970) 947-5433 AG-:vw W/O#l 4 -22 17 8:17-20:BM Wat so n Ranch B Pa d J 4·221 78 Honeycun A Touchsmm: Energy Cooperative ~;- Article 7-1003.C Emergency Response Plan Ursa Operating Company LLC Watson Ranch B Injection Well OA Project No. 014-3005 BATTLEMENT MESA SITE Emergency Evacuation, Assembly, Accountability and Response Plan Prepared for: Prepared by: 2381 Patterson Road Grand Junction, CO 81505 June 10, 2014 EMERGENCY ACTION PLAN AND WIDLFIRE MITIG ATION Revision 00 10-JUN-14 U r s a R e s o u r c e s G r o u p , I I PAGE 2 of 35 This plan is intended to provide general information about the Battlement Mesa Site owned and operated by Ursa Resources Group II, and to offer guidance for conducting emergency response operations not handled in a routine manner. This information will increase understanding of Ursa’s operations and assist Ursa and the general public should unexpected conditions arise and cause concern for employee and public safety. This procedure is designed to direct emergency response operations and to meet compliance obligations of OSHA in 29 CFR Part 1910.38-39 “Employee Emergency Plans and Fire Preventions Plans”, and more specifically address wildfire mitigation measures by using Best Management Practices in relation to assessing the wildfire potential at the site. EMERGENCY: A sudden and urgent occasion for action; pressing necessity. -New American Webster Dictionary EMERGENCY ACTION PLAN AND WIDLFIRE MITIG ATION Revision 00 10-JUN-14 U r s a R e s o u r c e s G r o u p , I I PAGE 3 of 35 TABLE OF CONTENTS 1.0 PURPOSE AND SCOPE .................................................................................................6 2.0 ROLES AND RESPONSIBILITIES ................................................................................6 2.1 Project Coordinator ...............................................................................................6 2.2 Site Manager/Supervisor or Lead Operator ......................................................7 2.3 Site Safety Officer .................................................................................................7 2.4 Incident Commander ............................................................................................8 3.0 OFF-SITE AND/OR LOCAL EMERGENCY RESPONSE ORGANIZATIONS.......8 3.1 Garfield County Emergency Communications Center ....................................9 3.2 Grand Valley Fire Protection District ..................................................................9 3.3 Grand River Hospital District ...............................................................................9 3.4 Parachute Police Department .............................................................................9 3.5 St. Mary’s CareFlight Helicopter .........................................................................9 4.0 COORDINATION WITH OFF-SITE RESPONSE ORGANIZATIONS....................10 5.0 CONTINGENCY PLANNING ........................................................................................10 6.0 TRAINING ........................................................................................................................10 7.0 DRILLS .............................................................................................................................11 8.0 EMERGENCY ACTIONS ...............................................................................................11 8.1 Actions Common to All Emergencies ...............................................................11 8.1.1 Site Safety Kit ......................................................................................... 12 8.2 Additional Information for Specific Emergencies............................................13 8.2.1 Bomb or Terrorist Threats ..................................................................... 13 8.2.2 Explosions ............................................................................................... 13 8.2.3 Evacuations ............................................................................................. 14 8.2.3.1 Assembly Areas/Muster Point ......................................................... 14 EMERGENCY ACTION PLAN AND WIDLFIRE MITIG ATION Revision 00 10-JUN-14 8.2.3.2 Evacuation Routes .......................................................................... 15 8.2.3.3 Personnel Accountability ................................................................... 15 U r s a R e s o u r c e s G r o u p , I I PAGE 4 of 35 8.2.4 Fire ............................................................................................................ 16 8.2.5 Flood......................................................................................................... 17 8.2.6 Earthquake .............................................................................................. 17 8.2.7 Severe Storms ........................................................................................ 17 8.2.8 Power Failure .......................................................................................... 18 8.2.9 Material or Chemical Release and/or Spills ....................................... 19 8.2.10 Medical Emergencies ............................................................................ 19 8.2.11 Public Disturbance Actions ................................................................... 21 8.2.12 Transportation or Vehicle Incidents ..................................................... 21 8.2.13 Media Response..................................................................................... 22 9.0 WILDFIRE MITIGATION MEASURES ........................................................................23 9.2 Structures and Ignition Potential .......................................................................25 9.3 Vegetation Management ....................................................................................26 9.4 Powerlines ............................................................................................................26 9.5 Debris Piles ..........................................................................................................27 9.6 ATVs and/or Equipment .....................................................................................27 9.6.1 Welding Operations ............................................................................... 28 9.8 General W ildfire Safety Tips ..............................................................................31 10.0 EVENT NOTIFICATIONS AND REPORTING ...........................................................32 10.1 Event Notifications ..............................................................................................32 10.2 Reporting Requirements ....................................................................................32 10.1.1 Emergency Notification ......................................................................... 33 10.1.2 Follow-up Notice Requirements ........................................................... 33 11 POST-EMERGENCY RESPONSE INCIDENT INVESTIGATION ..........................34 U r s a R e s o u r c e s G r o u p , I I PAGE 5 of 35 EMERGENCY ACTION PLAN AND WIDLFIRE MITIG ATION Revision 00 10-JUN-14 11.1 Post-Emergency Assessment ...........................................................................34 11.2 Lessons Learned .................................................................................................34 LIST OF TABLES Table 8-1 Warning Signals and Actions…………………………………………………...…12 ATTACHMENTS Attachment A Agency Emergency Contact List U r s a R e s o u r c e s G r o u p , I I PAGE 6 of 35 EMERGENCY ACTION PLAN AND WIDLFIRE MITIG ATION Revision 00 10-JUN-14 In compliance with: 29 CFR 1910.38-39 Means of Egress – Emergency Action/Fire Prevention Plans NFPA 1 – Fire Prevention Code NFPA 101©, Life Safety Code© Best Management Practices for Wildfire Mitigation 1.0 PURPOSE AND SCOPE This Emergency Evacuation and Response Plan (“EERP”) has been prepared to address activities, including potential wildfires, at the Battlement Mesa Site. The EERP is applicable to emergencies that may occur at the Site and is intended for use by all Ursa Resources Group II (“Company”) personnel, contractors, consultants, and sub-contractors. This plan is intended to minimize the potential for injury, loss of life and/or property, and to define the responsibilities of Ursa Resources’ personnel during emergency situations. In the event of an emergency, it is necessary to establish immediate coordination with local responders, with Ursa corporate officials, and with Ursa representatives in Rifle, Colorado. A contingency plan shall be implemented, as needed, to meet local re sponders’ requirements and response capabilities. Emergency procedures will be updated as needed for all potential incidents, including wildfire, structural f ire, explosion, toxic gas leaks, acid or caustic spills into primary water sources, weather disturbances and civil unrest. Procedures will include details on communications, firefighting, medical, security, evacuation resumption of operations or others as required by the situation and as directed by site supervision. In accordance with 29 CFR 1910.38, this Emergency Action Plan will be kept in at the workplace and readily available to all employees. All personnel will be trained on this policy at the time of hire and any time changes are made thereafter. 2.0 ROLES AND RESPONSIBILITIES This section identifies the roles and responsibilities of project personnel and off-s ite response organizations crucial to handling an emergency. Contact information for key personnel and organizations are included as an attachment to this program. Key project personnel for planning, responding to, and reporting an emergency include Ursa Resources management representative, Battlement Mesa facility personnel, and Emergency Response Organizations involved in the response of a hazmat, fire, or medical emergency. 2.1 Project Coordinator Roles of the Project Coordinator include: • Serve as the primary spokesperson for Ursa Resources (the “Company”) during a response to an emergency involving hazardous materials or events that could potentially affect the public. • Provide interface between the Company and the media. • Delegate or transfer roles or responsibilities to appropriate personnel as necessary. • Notify corporate management, the United States Environmental Protection Agency (EPA) when necessary, and the Supervising Contractor and/or other outside agency contacts of emergency conditions and status, as required. U r s a R e s o u r c e s G r o u p , I I PAGE 7 of 35 EMERGENCY ACTION PLAN AND WIDLFIRE MITIG ATION Revision 00 10-JUN-14 2.2 Site Manager/Supervisor or Lead Operator The Site Manager/Supervisor or Lead Operator shall: • Provide program management, technical oversight, and expertise in Battlement Mesa field activities and assign employees roles and responsibilities. • Review response plans, incident reports, post emergency critiques, and lessons learned. • Ensure all employees possess the proper and adequate training to perform emergency response actions during a hazmat, fire, medical, or other type of emergency. • Perform duties associated with the normal operations of the Battlement Mesa site. • Isolate the response area as directed by the guidance of this document, the Emergency Response Guide (United States Department of Transportation, 2012) (ERG), or per the Project Coordinator, Site Manager, or Site Safety Officer. • Make notifications to appropriate managers/supervisors as well as the applicable emergency response organizations. • Recognize the nature of the hazard. • Call for evacuation or shelter-in-place, as required and if the Incident Commander has not arrived on site. • If prevailing winds preclude the use of a decontamination facility in the assembly area, designate an alternative meeting place for all on-site workers, contractors and consultants in the event of an emergency. • Perform spill response through the use of equipment and/or spill response kits as designated and trained to do so. If Incident Commander has been designated, by either Ursa Resources or a local emergency response agency, the spill response activities shall be dictated by that person’s orders in accordance with industry practices. • If trained to do so, extinguish insipient stage fires using appropriate portable fire extinguishers and initiate emergency fire assistance with local fire services and incident command. • Coordinate and ensure that facilities have been properly and thoroughly evacuated in the event of a fire or emergency. • Ensure all personnel are properly trained on the policies contained herein. • Ensure adequate resources are made available to Battlement Mesa personnel during an emergency or, more importantly, to prevent incidents from occurring. • Act as the Incident Commander until a Company Corporate, Public Agency, or Private Sector Incident Commander with greater incident command experience arrives at the scene to relieve him/her of this responsibility. • Designate primary and alternate supervisors responsible for coordination of the accounting process at all muster points once evacuation has been achieved. 2.3 Site Safety Officer The Site Safety Officer shall: • Provide oversight for emergency planning. • Serve as on-scene coordinator during the emergency and advise the Incident Commander on the emergency condition or event. • Assist the Incident Commander with emergency response actions. • Assist emergency response/medical personnel in making notifications as requested. U r s a R e s o u r c e s G r o u p , I I PAGE 8 of 35 EMERGENCY ACTION PLAN AND WIDLFIRE MITIG ATION Revision 00 10-JUN-14 • Keep emergency response/medical personnel apprised of emergency status. • Provide a current inventory of chemicals and hazardous substances, materials, or wastes present on site and identify storage locations to off-site response organizations. • Ensure emergency response communications systems are available and operational and conduct annual tests of those systems. • Assist in preparing records of emergency response events, including incident investigation reports, for noteworthy practices and emergency response improvements. • Ensure responders meet the requirements for medical surveys prior to and after exclusion zone entries. • Establish a worker, contractor, and consultant sign-in or tag-in system to account for all on-site workers, contractors, or consultants in the event of an emergency. 2.4 Incident Commander The Incident Commander is an Ursa Resources’ employee or local emergency response official who is trained to the level of F irst Responder Operations, including Incident Management (IC) training, and is primarily responsible for responding to an emergency at the Battlement Mesa Site. Incident Commander shall: • Direct emergency response actions using appropriate personnel and resources to control or minimize the emergency. • Authorize site-wide evacuations of personnel or call for shelter-in-place. • Declare an emergency. • Delegate personnel for positions of emergency response, including operations, emergency response coordination, and public relations. • Verify personnel accountability list. • Maintain succession of authority during the emergency. • Protect the health and safety of the public and site personnel. • Conduct a post-emergency assessment as soon as practicable following stabilizatio n of the emergency condition. 3.0 OFF-SITE AND/OR LOCAL EMERGENCY RESPONSE ORGANIZATIONS Off-site agencies or local emergency response services will be used for emergencies requiring specialized training and resources of those organizations. Company employees shall act to provide aid and resources, including information and technical assistance, to off-site response organizations as necessary but shall not be responsible for emergency response activities at a technical level. Company and employees will allow access to the property for all personnel and equipment required for emergency response, such as fire equipment, law enforcement vehicles, ambulances, and flight-for-life helicopters. Depending on the scope and severity of the emergency, any of these organizations, other than the hospital, could provide an Incident Commander who is responsible for managing the emergency. U r s a R e s o u r c e s G r o u p , I I PAGE 9 of 35 EMERGENCY ACTION PLAN AND WIDLFIRE MITIG ATION Revision 00 10-JUN-14 3.1 Garfield County Emergency Communications Center The Garfield County Emergency Communications Center is responsible for all 911 calls received by dispatch and for mobilizing appropriate response agencies during an emergency, including sites located in and around Parachute, Colorado. Local lines calling 911 are directed to this authorized organization. 3.2 Grand Valley Fire Protection District Roles of the Grand Valley Fire Protection District include: • Emergency Medical Services, Ambulatory Services, Fire Suppression, Hazardous Materials Mitigation Fire Prevention, Rescue, Training and Public Education, and other emergency services including ambulance and wild fire responses. • Provides first response medical services for all injured or ill Company, contractor, subcontractor, or vendor employees and for site visitors. • Transports injured or ill personnel by ambulance to medical facilities from Site or related property. • Dispatched by the Garfield County Emergency Communications Authority and a member of a multi-county mutual aid agreement, aiding other departments both locally and within the seven member counties. • There are three locations for the Grand Valley Fire Protection District in Parachute, and they are: o 124 Stone Quarry Road o 200 Grand Valley W ay o 5797 County Road Emergency response shall dispatch emergency responders from one of these locations depending on availability and response times and shall be determined by dispatch at the time the emergency call is made. • The phone number is 970-285-9119 and should be used only to coordinate emergency response planning and related activities. 911 should be dialed in the event of an emergency. 3.3 Grand River Hospital District Roles of the Grand River Hospital District include: • Providing medical treatment of personnel who are ill or have life-threatening injuries associated with a project emergency. • Located at 501 Airport Road, Rifle, CO 81650. 3.4 Parachute Police Department Roles of the Parachute Police Department include: • Providing law enforcement protection, traffic control and coordination, and other law enforcement services. • Coordinating emergency law enforcement services. • Providing a suitable area or accommodations for use as an emergency operations center. • Located at 222 Grand Valley Way, Parachute, CO 81635. 3.5 St. Mary’s CareFlight Helicopter In case of a life threatening situation requiring immediate medical attention that cannot be accommodated or treated by emergency responders located closer to the pond site, St. U r s a R e s o u r c e s G r o u p , I I PAGE 10 of 35 EMERGENCY ACTION PLAN AND WIDLFIRE MITIG ATION Revision 00 10-JUN-14 Mary’s Hospital in Grand Junction can provide medical evacuations via helicopter when necessary. 4.0 COORDINATION WITH OFF-SITE RESPONSE ORGANIZATIONS Effective coordination with off-site organizations will result in effective response to any emergency situation. Training and drills as described in Sections 7.0 and 8.0, respectively, should be periodically made available to off-site emergency response organizations. Under the direction of the Site Manager or Site Safety Officer, a project representative will participate in local emergency planning committee meetings when possible. Ursa Resources recognizes that close coordination with response organizations continuously improves emergency responses by enhancing communication, site familiarity, and lessons learned for all involved. 5.0 CONTINGENCY PLANNING The objective of contingency planning is to prepare for emergency responses. It includes coordinating with emergency response organizations, describing actions during emergencies, conducting training, and performing drills. The Project Coordinator, Site Manager, or Site Safety Officer will coordinate drills and plan for emergencies while synchronizing Ursa’s efforts with off- site emergency response organizations. In order to properly prepare for an emergency response, project personnel shall: • Communicate to the Incident Commander that an emergency is in progress. • Recognize the hazards in the area potentially affected by the emergency. • Know what to do and what not to do. • Understand warning sounds and alarms. • Know where to assemble. The Company will provide first aid, cardiopulmonary resuscitation (CPR), and automated external defibrillator (AED) training to the level of First Responder consistent with the requirements of 29 CFR 1910.151(b). One individual on each shift at the Battlement Mesa location shall be trained to this level. 6.0 TRAINING The Company maintains training programs to ensure personnel are adequately trained and prepared for the work they perform and for potential emergencies. Company personnel, contractors, and consultants who regularly work at the Battlement Mesa Site must receive training on the current EERP. Specific training is provided to workers who have special duties during emergencies, such as the Battlement Mesa Site Supervisor and Site Operator who may need to respond directly to an incident. Site visitors and vendors will be accompanied by trained site personnel and shall log in upon arrival and sign out when leaving. Site-designated First Responders will train and practice procedures for any site EMS responses and off-site emergency responses. EMERGENCY ACTION PLAN AND WIDLFIRE MITIG ATION Revision 00 10-JUN-14 U r s a R e s o u r c e s G r o u p , I I PAGE 11 of 35 Off-site response organizations should be offered training on site hazards; potential injuries and/or illnesses that could result from contamination by contact, ingestion, or inhalation of toxic substances present on site; and contamination risks associated with fires, explosions, or other releases of materials located on site. This training, along with a site tour, shall be offered annually by the Company. 7.0 DRILLS Annual on-site drills shall be conducted to practice emergency response protocol and evaluate those responses. Such drills shall simulate a variety of emergencies and may involve a single field crew, the entire site personnel, and/or off-site emergency response organizations. Drills may also involve detailed coordination and physical role-playing to establish familiarity with these procedures. Drills help improve the Emergency Response process by addressing opportunities for improvement within the Emergency Response System used at this Site. 8.0 EMERGENCY ACTIONS For the purpose of this plan, an emergency is considered to be any condition which requires assistance over and above that which can be supplied by the normal personnel present at the time or which cannot be handled in a routine manner. All emergency situations are unique and present various conditions. Always evaluate the situation before deciding on a course of action. Ursa Resources representatives must ensure that all site personnel do not “rush in” until the following has been considered: • Is there an immediate threat to life from fire, explosion, structure collapse, chemical spill or release? If so, sound the alarm and evacuate. • Is there an immediate potential for release of toxic (poisonous) chemicals or fumes in the air? If so, evacuate uphill and upwind of the release. • Is there an immediate potential for uncontrollable energy release (pressure), electrical shock, chemical spill, fuel to “feed” a fire? If so, de-energize equipment, disconnect power, engage emergency shut off valves to pumps and fuel sources; but only do so if the action will not cause a more serious problem or endanger someone. • Eliminate sources of ignition by shutting down all other powered equipment, including vehicles, pumps, construction equipment, welding equipment, combustors, separator burners, auxiliary generators, power tools, etc. that may be on site at the time. • When in doubt, sound the alarm, evacuate, and call for help. With regard to any emergency observed at the work site, the immediate supervisor must be contacted and the nature of the emergency reported. 8.1 Ac tions Common to All Emergencies Emergency Response actions should account for life safety first, the environment second, and lastly, property (Ursa or non-Ursa). The steps below should be considered during any emergency: • Survey the scene for personal safety. If the area is deemed unsafe, re-locate. EMERGENCY ACTION PLAN AND WIDLFIRE MITIG ATION Revision 00 10-JUN-14 U r s a R e s o u r c e s G r o u p , I I PAGE 12 of 35 • Warn others in the area using whatever means are available (e.g., voice, telephone, radio, portable sirens, car horn). • Implement chain of command notification for an organized response. • Survey the scene and determine resources needed by emergency personnel. • Stop or secure the operation causing the emergency, but only if safe to do so. • Minimize exposure to potential hazardous conditions as part of the emergency. • Identify other hazards present (e.g., the potential for fire or explosion.) • Isolate the area and establish control boundaries, if possible. • Contact and direct emergency response organizations to the scene as necessary. • At no time should an emergency response be performed if the Incident Commander determines the area is unsafe for personnel to enter. Good communication is essential for effective emergency responses. The simple warning system described in Table 8-1 will be used to notify personnel of an emergency. This warning system shall be tested at least annually by the Site Safety Officer. Upon notification of an emergency, the Site Safety Officer will notify the Project Coordinator. Notifications to agencies and organizations will be determined by the Project Coordinator. Supplemental actions will be determined by the on-site Incident Commander and carried out as quickly possible after immediate actions are addressed. All Battlement Mesa employees must be able to identify hazards in the immediate area and be aware of alarm notification procedures. Table 8-1 below describes the alarm method using a handheld air horn. DO NOT use vehicle horns if potential for ignition exists. Battlem ent Mesa personnel should be trained to recognize these alarms. 8.1.1 Table 8-1 Warning Signals and Actions ACTION WARNING SIGNAL AT T ENT ION (Emergency Event) 1. Continuousl y blast horn for 5 seconds. Repeat three times with a 5-second pause in between. 2. Supervisor must then radio employees to communicate further instructions to all personnel. EV ACU AT ION 1. Make five 10-second blasts with horn, with 5-second pauses in between each blast. Repeat two times. 2. Immediatel y evacuate to the designated assembly area for personnel accountability. SHELT ER IN PL ACE 1. Continuousl y blast horn for thirty seconds. Repeat one time if necessar y with a 5-second pause in between. 2. Immediatel y proceed to shelter-in-place and proceed with emergency preparations as indicated herein. 8.1.1 Site Safety Kit The Battlement Mesa Site Safety Officer shall maintain a safety kit specifically designed for that site. It shall be available for transport to an emergency location. The kit s hould include, at a minimum: EMERGENCY ACTION PLAN AND WIDLFIRE MITIG ATION Revision 00 10-JUN-14 U r s a R e s o u r c e s G r o u p , I I PAGE 13 of 35 • First response bags/first aid kits. • AED (available for trained personnel only). • Eye wash kit. • Spill response materials such as absorbent pillows, vermiculite, etc. • Minimum 20 lb. ABC fire extinguisher. • Spotlight/flashlights. 8.2 Additional Information for Specific Emergencies Additional information for specific emergencies includes: • Bomb or Terrorist Threats • Explosions • Evacuations • Fires • Floods • Earthquakes • Severe Storms • Power Failure • Material or Chemical Spills • Medical Emergencies • Public Disturbances • Transportation/Vehicle Incidents • Special Actions at the Pond Site • Shelter in Place 8.2.1 Bomb or Terrorist Threats If a bomb threat is received, stay calm. It is important to keep the caller on the line to obtain as much information as possible. Someone other than the call recipient should notify the Project Coordinator or Site Manager of the threat while the caller is still on the line. A bomb threat may be followed by a site evacuation depending on information obtained from the caller. 8.2.2 Explosions If flammable natural gases or liquids are released, the following action should be taken immediately: • Evacuate all personnel from area. • Shut down all running equipment. • Close all valves upstream and downstream of leak. • Call 911. • Contact appropriate Ursa personnel and implement notification chain of command. • Follow instructions in “Fire” section in case of a fire. • If personnel are injured, apply f irst aid as trained to do so and transport them to nearest medical facility, if possible. Otherwise, wait for emergency responders to arrive. EMERGENCY ACTION PLAN AND WIDLFIRE MITIG ATION Revision 00 10-JUN-14 U r s a R e s o u r c e s G r o u p , I I PAGE 14 of 35 8.2.3 Evacuations Depending on the emergency, personnel shall evacuate to a location upwind and uphill, if possible. Personnel shall meet at the designated safe area and a head count will be taken by the supervisor or designee to ensure that everyone is accounted for. A call for an evacuation may be restricted to a specific work area or executed for the entire site. Area evacuations can be ordered by any Company employee, contractor, subcontractor, or others during an emergency. A site-wide evacuation may be authorized by the Project Coordinator, Site Manager, Site Safety Officer, and/or Incident Commander. All buildings, truck bays, and tank farms must be evacuated if the fire alarm sounds or if authorized personnel orders an evacuation. Never ignore an emergency alarm. Evacuation beyond muster points may be required. The Incident Commander will direct evacuation beyond muster areas to an area of safe refuge. When instructed to evacuate, proceed with the following: • Implement emergency shut-down procedures by activating the emergency shut-off valves on all equipm ent. • Identify the direction of the wind by observing the direction of the wind sock and evacuate immediately cross or upwind of the affected area to the designated assembly area or muster point. • Follow the primary exit route. If the designated route or assembly point is not accessible or safe due to wind direction, proceed to a secondary or alternate assembly area as designated herein or by the Incident Commander. • If primary exit is blocked or unable to be reached, choose secondary evacuation route. • All radio traffic should cease except for those authorized to broadcast emergency information on the main radio channel. A radio channel may be designated for supervisors to communicate with an emergency coordinator or a Company representative. • Assist injured persons evacuating the site as needed and if able and trained to do so. DO NOT CAUSE MORE HARM AND DO NOT BECOME ANOTHER VICTIM BY RUSHING INTO A HAZARDOUS ENVIRONMENT. • All engine-driven equipment should be shut down and engines turned off. Keys should be left in the ignition. • Vehicles should be parked and clear of traffic lanes and access routes. Emergency vehicles and personnel must have clear access to the location. • Move to the predetermined muster point away from the incident. • If individuals are ignoring the alarm, warn them to evacuate immediately. Do not get involved in an altercation, but notify the supervisor immediately of the location of these employees. • Do not reenter the work area until directed to do so by authorized personnel or after the “All Clear” signal has been given by the Site Supervisor. 8.2.3.1 Assembly Areas/Muster Point Assembly areas are designated safe refuge zones during a site emergency. If prevailing winds put either the primary or secondary muster point downwind EMERGENCY ACTION PLAN AND WIDLFIRE MITIG ATION Revision 00 10-JUN-14 U r s a R e s o u r c e s G r o u p , I I PAGE 15 of 35 of the accident site, workers will be directed via radio or cell phone to an alternative area. All personnel must be aware of the primary and secondary muster points, even if they are NOT marked. PRIMARY MUSTER POINT SECOND ARY MUSTER POINT South Entrance Gate at Access Road to the East of Staging Area. South and West of Entrance Gate on the access road across from the Staging Area. HELICOPTER L ANDING ZONE South of the Site, across the access road, on relatively flat ground with no overhead obstructions or trees. Power lines lie to the north of the site and do not cross this area. 8.2.3.2 Evacuation Routes Evacuation routes will be clearly communicated to all personnel by postings or radio directives as mandated by changing conditions. As stated above, the primary evacuation route shall follow the access road that leads away from the site and towards Stone Quarry Road to the north of the location. If conditions warrant, this evacuation route shall be revised to account for upwind possibilities that are safer than traveling downslope along the access road during certain emergency situations. The Incident Commander and Site Safety Supervisor will determine if a change in the primary evacuation route is m andated. • Evacuation routes shall be upwind of any hot zone or exclusion zone and windsocks shall be visible to all site personnel to determine which exit route to take during evacuation. • Travel south or west away from the staging area and the on or offloading area of the site. • If the primary evacuation route is unusable, workers shall be directed via radio to an alternate route. The Project Coordinator or Site Manager will ensure evacuation routes are rehearsed as a part of regularly conducted site emergency drills. 8.2.3.3 Personnel Accountability The Incident Commander or Safety Officer shall use an accountability list to account for all personnel. The accountability list shall be based off the Site’s daily sign-in/sign-out log or sheet. A count of all personnel shall be done at the muster point. The names of missing and/or unaccounted for personnel must be delivered to the Project Coordinator as soon as possible. CAUTION: Searches for missing personnel shall be conducted only if possible to do so safely. No personnel shall conduct a search in dangerous conditions. EMERGENCY ACTION PLAN AND WIDLFIRE MITIG ATION Revision 00 10-JUN-14 U r s a R e s o u r c e s G r o u p , I I PAGE 16 of 35 8.2.4 Fire The objective is to take actions that might reduce the consequences of a fire in the event one occurs at the Pond Site. When a fire alarm sounds, leave immediately. Instruct all employees to leave the area immediately as you evacuate and notify the supervisor. Be aware of individuals who may need assistance. Do not reenter the site until directed to do so by authorized personnel. 8.2.4.1 Extinguishable Fire (Incipient Stage) • Report the fire by activating the nearest fire alarm. • Use a fire extinguisher in your area to extinguish the fire, if trained to do so. • Use the PASS system: a. Pull the safety pin. b. Aim – Remove the hose and aim the nozzle toward the fire. c. Squeeze – Holding the handle, squeeze the trigger. d. Sweep – Extinguish the fire in a sweeping motion, from left to right. • Immediately report the incident to the supervisor. • Rule of thumb: If you have already discharged one 20-30 pound fire extinguisher at the base of a fire and have made no impact on the fire, then it is beyond the incipient stage and steps in Section 8.2.3.2 below must then be followed. 8.2.4.2 Non-Extinguishable Fire • Report the fire by activating the nearest fire alarm and contacting the supervisor on duty. • Call the fire department and give all needed information, referencing the emergency numbers listed herein. • Conduct an emergency shut down and evacuate the area. If a potential wildfire breaks out, the most important thing is accountability. First notify someone of the fire. Second, call the Rifle Fire Protection District immediately. The sooner the fire department is dispatched, the quicker the response time. All fires on federal lands require immediate EMERGENCY ACTION PLAN AND WIDLFIRE MITIG ATION Revision 00 10-JUN-14 U r s a R e s o u r c e s G r o u p , I I PAGE 17 of 35 notification to applicable Ursa personnel. If the fire cannot be put out by the fire extinguisher in the incipient stage, it is time to evacuate the area immediately. 8.2.5 Flood Floods are unlikely to affect operations at the Battlement Mesa Site. Flood conditions will most likely occur from runoff associated with thunderstorms, heavy rain, snow melting, or broken pipelines. It could also occur if an y pipelines or on-site tanks break. The actions taken in the event of a flood will depend upon the amount of warning received before a flood actually occurs. Flooding associated with thunderstorms can result in rapid increase in flow in drainages and flow into the pond. Stay away and out of that area. In the event of such conditions, notify the Site Safety Officer. Flooded roadways may be encountered while traveling to or from the jobsite. Drive with care and never attempt to drive through flooded road sections. 8.2.6 Earthquake The likelihood of an earthquake at or near Western Colorado is highly unlikely. This information is provided for awareness only. Be prepared for additional aftershocks. They are usually smaller, but can cause additional damage or bring weakened structures down. Do not attempt to move seriously injured persons unless they are in immediate danger of further injury. Report the location of the injured person to emergency personnel. 8.2.6.1 Indoors • Stay inside. Falling debris can cause serious injury outside. • Take cover under a sturdy desk, table, or other furniture, in a supported doorway, or along an inside wall. • Stay as far away from glass and windows as possible. • Extinguish open flames and do not use lighters, matches, or candles, due to possible gas leaks. • After tremors have ceased, leave the building until structural safety can be assessed. Do not enter any building until structural integrity can be verified. 8.2.6.2 Outdoors Move away from buildings and utility wires. Once in the open, stay there until the tremors have stopped. 8.2.6.1 Moving Vehicle • Stop as quickly as safety permits. Remain in the vehicle. • When tremors stop, drive carefully and watch for falling objects, downed electrical lines, and broken or undermined roadways. 8.2.7 Severe Storms Colorado weather at all times of the year can be unpredictable. To prepare for contradictory conditions, personnel shall monitor news and weather reports for forecasts. Supervisors should be warned of threatening conditions. EMERGENCY ACTION PLAN AND WIDLFIRE MITIG ATION Revision 00 10-JUN-14 U r s a R e s o u r c e s G r o u p , I I PAGE 18 of 35 Ursa will keep supervisors informed of the changing conditions and the effects of weather on operations. Supervisors will subsequently inform all employees. Supervisors will look at the difference in the drive time to and from the work site due to severe weather and adjust accordingly, if necessary. Supervisors will also review the appropriate PPE for the particular weather condition and inform all employees of any necessary changes. 8.2.7.1 Tornado or Severe Lightning • If a tornado or severe lightning is seen, sound the alarm and evacuate. • Seek shelter away from the pond, trailers, and vehicles. • Get low to the ground, away from trees, preferably in a ditch or depression if no likelihood of flash flooding exists in the area. • If time allows, notify others of your location and situation. • Do not attempt to outrun severe weather or flash floods. • Do not park beneath tress and avoid exposed areas such as ridgelines and natural washes. • Seek shelter if available, otherwise stay in vehicle. • If caught out of your vehicle, proceed downhill to a less exposed side slope location. Avoid trees, fences, large rocks. Squat in the open on the balls of our feet with y our head down. Cover ears with hands, elbows in, and wait the situation out. • Never attempt to walk or drive across flooded roads or ditches. 8.2.7.2 Blizzard • Tune into and monitor local weather radio or news broadcasts. • When blizzard has been issued, immediately notify office and field personnel that may be affected. • Inform others to tune into weather broadcasts and stay abreast of possible conditions and/or weather changes in their area. • Inform personnel if blizzard is underway. • If stranded in blizzard conditions, notify others of deteriorating conditions along with your locatio n and situation before communications are lost. • DO NOT leave your vehicle unless absolutely necessary. Assure exhaust pipe is clear of obstructions (such as snow buildup) and run engine only when needed, so fuel is conserved. • If stranded away from vehicle or if necessary to abandon it, seek shelter in a stable structure and wait for help to arrive. If shelter is not available, build a snow cave and wait for help. If caught outside of shelter, build a fire if possible. • Tray and stay dry. Change to dry and weather resistant gear. • If caught with more than one person in a blizzard, DO NOT SEPARATE. Provide assistance to others if you are capable. • Do not attempt to walk off the mountain during blizzard conditions. 8.2.8 Power Failure If there is a power failure at the Battlement Mesa Site, proceed with the following steps: • Switch off all equipment being used to prevent injury when power returns. EMERGENCY ACTION PLAN AND WIDLFIRE MITIG ATION Revision 00 10-JUN-14 U r s a R e s o u r c e s G r o u p , I I PAGE 19 of 35 • Ensure all other equipment or switches are turned off to prevent possible damage to equipment from power surges when power is restored. • Notify the supervisor in charge of your actions due to the power failure. After the power has been restored, check your area and report any equipment or other damage to your supervisor. Verify that all electronics are up and running, and report any discrepancies. 8.2.9 Material or Chemical Release and/or Spills Actions in the event of a spill of petroleum products or toxic materials, including condensate and process water, will be provided in Ursa Resource’s Spill Prevention, Control and Countermeasure Plan for the Battlement Mesa Site. Notify all employees and other appropriate personnel of the spill and any chemicals involved. All employees will comply with the Company’s personal protective equipment policy for any chemicals they are using or to which they may be exposed at the Site in the event of a spill. 8.2.10 Medical Emergencies While all employees are responsible for immediate action in response to a medical emergency, no employee is required to provide first aid for which he or she has not been trained or if uneasy about doing so. Occasionally accidents will happen where individuals, including the victim, will assume that no injury has occurred and that no medical attention is required. If symptoms become evident later, an Incident Report needs to be filled out and turned into the supervisor on duty. The injury incident will then be investigated and analyzed for root causes to mitigate or e liminate hazards that led to the incident. Different procedures for varying degrees of medical emergencies shall be utilized by site personnel when responding to a medical emergency. 8.2.10.1 Life Threatening EXAMPLES: Unconsciousness, inability to move, potential spinal injuries, seriously broken bones, uncontrollable bleeding, heart attack, stroke, inability to breath, etc. • Do not move the victim unless he or she is in a life-threatening situation or environment. Render first aid applicable to your training and abilities. • Call for emergency help and reference the emergency phone numbers listed herein. If necessary, send someone to meet emergency personnel and bring them to the victim’s location. • Notify supervisor immediately and report the following: - Name of victim. - Date and time of injury. - Description and/or circumstances of the injury. - Brief summary of what happened and include actions taken as a result. - Names of witnesses. - Conditions of the site or location of injury. - Need for Incident Report Form. EMERGENCY ACTION PLAN AND WIDLFIRE MITIG ATION Revision 00 10-JUN-14 U r s a R e s o u r c e s G r o u p , I I PAGE 20 of 35 8.2.10.2 Non-Life Threatening EXAMPLES: cuts, abrasions, sprains, fainting, simple fractures, etc.) • Immediately contact medical services by referencing emergency phone numbers. Render first aid applicable to your training and abilities. • Notify the supervisor of the injury and report the following: - Name of victim - Date and time of injury. - Description and/or circumstances of the injury. - Brief summary of what happened and include actions taken as a result. - Names of witnesses - Conditions of the site or location of injury. - Need for Incident Report Form. 8.2.10.3 General Basic guidelines for medical emergencies: • Make sure it is safe to be in the victim’s area; • Call 911 and request an ambulance. Provide the following information: - Number and location of victim(s); - Nature of injury or illness; - Hazards involved; and, - Nearest entrance (emergency access point.) • Alert trained employees to respond to the victim’s location and bring a first aid kit and/or AED. • Notify the Site Supervisor or Site Manager. • Only trained responders/personnel shall provide first aid and assistance. • Never move a victim in need of medical assistance unless: - Directed by a competent medical authority. - The injury will not be aggravated or complicated by a move. - Greater physical harm to the victim likely if not moved from current location. - Wound severity is life-threatening. • Take “universal precautions” to prevent contact with bodily fluids and exposure to bloodborne pathogens. • Meet the ambulance at the nearest entrance or emergency access point and direct them to the victim(s). Never delay EMS access to the scene while applying administrative controls or prescribing personal protective equipment. Decontamination of victims, emergency medical services (EMS) personnel, and any associated equipment and materials will be performed in proportion to the nature and severity of the medical emergency. EMERGENCY ACTION PLAN AND WIDLFIRE MITIG ATION Revision 00 10-JUN-14 U r s a R e s o u r c e s G r o u p , I I PAGE 21 of 35 8.2.11 Public Disturbance Actions A public disturbance is defined as a demonstration by activists or a threat to operations on the Battlement Mesa Site. Public disturbances can take the form of events that may serve to: • Disrupt Company, contractor, or subcontractor operations. • Adversely affect Company or contractor properties. • Jeopardize the safety and health of Company, contractor, or subcontractor employees. • Adversely affect the reputation or public image of the Company. • Threaten or cause bodily injury or hazardous material exposure to the general public. If there is no immediate threat to personal safety, the Project Coordinator or Site Manager will work with the corporate and off-site emergency response organization(s) to determine the appropriate response actions needed to safeguard personnel and property during a public disturbance, as they often occur with little or no warning. 8.2.12 Transportation or Vehicle Incidents A vehicle collision is defined as any vehicle contact or damage requiring repairs to a Company vehicle, another vehicle, and injury to a pedestrian, animal, or third-party, or damage to Company property. 8.2.12.1 Vehicle Accident • STOP. NEVER LEAVE THE SCENE OF AN ACCIDENT. • Obtain help for injured persons. • Notify policy and a Company supervisor. • Obtain necessary information at the scene. Exchange only driver’s license number and insurance information with other driver. DO NOT make commitments. State the collision will be reported to your company. Any liability will be determined by the Company and its insurance carrier. DO NOT express opinions or become involved in arguments. • Have witnesses provide address and telephone numbers. • If injury results from a vehicle accident, an injury report must be completed. 8.2.12.2 Transportation Incident A transportation incident is an emergency event involving vehicle/truck transport of operation materials (such as sludge, acids, bases, or polymers) being delivered to, or shipped from, the Battlement Mesa Site. • If an injury requiring immediate medical attention occurs, or if there is a potential for impact to the environment that cannot be contained with a small spill kit or hand tools, the incident will be handled by off-site response organizations. • The carrier used for transportation incidents shall be included in all accident investigations involving their transport vehicles. • Conveyance or transportation employee/staff shall be trained to minimize the contamination of property by inspecting shipping EMERGENCY ACTION PLAN AND WIDLFIRE MITIG ATION Revision 00 10-JUN-14 U r s a R e s o u r c e s G r o u p , I I PAGE 22 of 35 equipment for any leaking material, signs of damage or excess wear prior to its use. • Conveyance or transportation employee/staff shall be trained to respond to an emergency without endangering personal safety. • Shipping personnel will immediately notify the Site Manager or Site Safety Officer and/or the off-site emergency response organizations of the potentially hazardous emergency and the possible threat to the public’s health and safety, the potential impact to the environment, and any possible or impending damage to property. • The Project Coordinator, Site Manager, Site Safety Officer, or the conveyance company will coordinate contractor emergency response cleanup support as needed. NOTE: If the amount of material spilled exceeds the reportable quantity (RQ) as defined in the Hazardous Substance/RQ Table by the Department of Transportation and the Environmental Protection Agency, the National Response Center will be contacted by the Project Coordinator within twenty- four (24) hours of the incident at 800-424-8802. 8.2.13 Media Response No personnel will talk to any media representative without prior approval. All comments will be referred to the Ursa Resources Operating Company representative or the Corporate Office in Denver. Employees shall state “no comment” to any media questions posed to them. 8.2.14 Shelter in Place If chemical, biological, or radiological contaminants are released into the environment in such quantity and/or proximity to the rig site, it may be safer to remain indoors, or shelter- in-place, rather than to evacuate. Such releases may be either accidental or intentional. “Shelter-in-place” means selecting a building with few windows, or none at all, in which to take refuge. In many cases, local authorities will issue advice to shelter-in-place via TV or radio. Use common sense and available information to determine if this type of refuge is necessary. In any emergency, local authorities may or may not immediately be able to provide information on what is happening and what you should do. If large amounts of debris are in the air, or if loca l authorities say the air is badly contaminated, a shelter-in- place order should be issued by the Incident Commander. To shelter-in-place, follow these instructio ns: • Lock exterior doors and close windows, air vents and other openings. • Turn off all fans, heating and air conditioning systems where present. • If there is danger of explosion, cover windows to protect against flying glass and debris. • Use duct tape and plastic sheeting to seal all windows, doors and vents. • Gather essential disaster supplies such as food, bottled water, battery-powered radios, first aid supplies, etc. EMERGENCY ACTION PLAN AND WIDLFIRE MITIG ATION Revision 00 10-JUN-14 U r s a R e s o u r c e s G r o u p , I I PAGE 23 of 35 • Write down names of everyone in the room and contact Ursa’s designated emergency contact to report who is in the room with you and their affiliation with the business. • Avoid overcrowding and do not select a room with mechanical equipment like ventilation blowers or pipes because that equipment may not be able to be sealed properly. • Call emergency contacts and have phone available to report a life threatening condition, if necessary. • Listen to radio, etc., for further information and additional emergency notifications. 9.0 WILDFIRE MITIGATION MEASURES The predominant causes of wildf ire are lightning, recreational activities, residents, industry activities (industry category is ranked the third highest human-caused ignition source), railroads or other agents. A contributing factor that poses additional risk to oil and gas installations are traveling embers from existing fires that are carried on the wind and can ignite upon contacting structures and uncontrolled vegetation. Radiant heat from wildfires also poses a risk to structures and personnel at oil sites. Smoke from wildf ires can affect evacuation routes and staging areas. Thus, any emergency response plan specifically addressing wildfires must take into account the following: • Increased safety for personnel; • Reduced risk to industry infrastructure from wildfires; • More secure production schedules less likely to be disrupted in the event of a wildfire; • Reduced liability from wildfires caused by the oil and gas industry; • Increased environmental stewardship and overall corporate responsibility. In addition, several factors affect a site’s susceptibility to wildfire hazards and the potential for wildf ires to be fueled by site installations. By assessing structures, vegetation, powerlines, equipment used on site, and work tasks conducted on site, Ursa Resources has evaluated the Battlement Mesa Site and created the measures herein for dealing with wildfire risk and potential occurrence. 9.1 Definitions CONIFEROUS VEGETATION FUEL TYPE – Any of various needle-leaved (mostly) or scale-leaved, chiefly evergreen, cone-bearing trees or shrubs such as pines, spruces, and firs. DEBRIS – The woody or herbaceous material which results from vegetation clearing operations. DECIDUOUS VEGETATION FUEL TYPE – Typically used in reference to trees or shrubs that lose their leaves seasonally, and other plant structures that shed (such as petals or seed structures) after flowering or fruit when ripe. EMBER TRANSPORT – Embers or fire brands are produced as trees and other combustible objects burn. These embers carry in the atmosphere and by winds over long distances. Hot embers ultimately come to rest and may ignite surfaces far removed from a fire, thus resulting in fire spread. This process is commonly referred to as spotting. EMERGENCY ACTION PLAN AND WIDLFIRE MITIG ATION Revision 00 10-JUN-14 U r s a R e s o u r c e s G r o u p , I I PAGE 24 of 35 FIRE BEHAVIOR – The manner in which fuel ignites, flame develops and fire spreads as determined by the interaction of fuels, weather, and topography. FIRE HAZARD – A hazard based on physical fuel characteristics, such as fuel arrangement, fuel load, condition of herbaceous vegetation and presence of elevated fuels. A general term to describe the potential fire behavior without regards to the state of weather influenced fuel moisture content and/or resistance to fireguard construction for a given fuel type. FIRE OCCURRENCE – The number of fires started in a given area over a given period of time. FUEL BREAK – An existing barrier or change in fuel type (to one that is less flammable) or a wide strip of land in which the native vegetation and topography has been modified or cleared to act as a buffer to fire spread so that fires can be more readily controlled. A strategically planned barrier, either manually or mechanically constructed that is intended to stop or slow down the rate of fire spread and from which suppression action can be carried out to control a fire. LADDER FUELS – Vegetation that will help carry a surface fire up to the tree crown/tops that result in a crown fire (typically in coniferous fuel types.) HAZARD REDUCTION – Treatment of living or dead forest fuels to diminish the likelihood of a fire starting and to lessen the potential rate of spread. MINERAL SOIL – Non-organic soil. MITIGATION – Action that decreases the severity of a fire hazard or risk. MIXED W OOD VEGETATION FUEL TYPE – A ‘mixed’ forest in which two or more tree species are predominant in the canopy. RADIANT HEAT TRANSFER – Heat transfer to the surrounding environment through radiation. RISK FROM WILDFIRE – The potential of loss from wildfire that can be calculated by multiplying damage or loss by uncertainty of occurrence and contributing factors. SUPPRESSION CAPABILITY – The factors and limitations that are related to the ability to contain a wildfire upon detection in order to protect values at risk. STAGING AREA – A location at an incident where resources can be placed while awaiting tactical assignment. Also used to describe an area where tasks are conducted that may be dangerous or hazardous if performed on-site or near installations. EMERGENCY ACTION PLAN AND WIDLFIRE MITIG ATION Revision 00 10-JUN-14 U r s a R e s o u r c e s G r o u p , I I PAGE 25 of 35 VALUES AT RISK – The specific or collective set of natural resources and man-made improvements/developments that have measurable or intrinsic worth that could be destroyed or otherwise altered by fire in any given area. WICKING – Vegetation connectivity or pattern that contributes to an increase in fire spread. WILDFIRE – Any unwanted or unplanned wildland fire that burns in forested or grassland areas. 9.2 Structures and Ignition Potential The distance between structures and flammable vegetation can affect structural ignition potential through ember transport or radiant heat exposure to structures or vegetation. It’s important to note that a wildf ire will burn more rapidly and intensely on slopes compared to flat or level ground. As a result, structures on or adjacent to a slope with vegetation below are more susceptible to wildfires and face a significantly higher probability of ignition due to heat exposure. The radius around structures must be assessed according to the structure’s materials, flammable storage units (e.g., hydrocarbon storage tanks), and on-site vegetation. The roof of a structure is the most vulnerable component for fire ignition and the main cause of structural losses during a fire. Embers and flaming debris from wind-driven fires can travel great distances, and embers landing on a combustible roof surface can start a new fire. Flammable material storage on site, such as hydrocarbons or propane tanks, also creates additional threats to structures based on: 1. Presence or absence of hydrocarbons on site; 2. Flammable material rating; 3. Potential for accumulation of airborne embers on tanks; and, 4. Distance from storage sites to forest vegetation. Structures with metal, tile, asphalt, or n on-combustible materials, such as concrete or metal siding, and that have no eaves or contain screened vents with openings turned down, possess the lowest flammability risk. Those with wood or vinyl siding and/or open eaves and no soil or metal covers at the base of the structure where embers can be trapped, pose the highest flammability risk. The location of petroleum products and combustibles (such as storage tanks) from fuel sources also increases or decreases flammability risk. Storage that is not located near structures, or that is more than ten (10) yards from those structures, pose the lowest risk. Storage sites that are 3-10 yards from a structure pose a mid-level risk, and those that are less than 3 yards from any structure pose the greatest flammability risk. To prevent the entry of airborne embers, all eaves and vents will be inspected to ensure they face downward to decrease the chances of embers accumulating in them and EMERGENCY ACTION PLAN AND WIDLFIRE MITIG ATION Revision 00 10-JUN-14 U r s a R e s o u r c e s G r o u p , I I PAGE 26 of 35 increasing the potential for fire on the site’s structures. Any tanks located on site, such as the saltwater storage tanks, will be handled in this manner. 9.3 Vegetation Management The main point to managing vegetation around the site is to minimize the risk of high- intensity crown fires. This can be done through several steps, beginning with thinning any surrounding forest stands to less than 40% of the surrounding area with at least 3 meters between crowns (of the trees) and decreasing crown cover (the percentage of ground area covered by tree crowns if viewed from above) to that level. At the Battlement Mesa site, there are very few tree stands and even fewer shrubs around the site that could affect the flammability of the landscape. As a result, all measures to mitigate the risk posed by the existing vegetation will focus on vegetation reduction and, in some rare cases, vegetation removal. By partia lly reducing flammable coniferous forest vegetation around the site, Ursa Resources has already reduced crown fire potentia l and lowered the wildfire intensity, spread, and spotting risks. Vegetation removal is recommended as the best management strategy for wildfire mitigation, Ursa Resources has maintained native vegetation for landscaping purposes as requested by local officials, and to mitigate other risks to the site such as soil erosion. Vegetation differs in its flammability as some species are MORE resistant to burning, while others are LESS resistant to burning. The flammability rating of different tree species can be determined, but Battlement Mesa Site has mostly native grasses and noxious weeds on its site. The surrounding areas contain some smaller coniferous trees, but Ursa Resources has eliminated any of that vegetation at the pad site. Because grass vegetation increases soil stability and decreases soil erosion, the existing vegetation will be managed accordingly by keeping it a good distance from any structures (as indicated above) and ensuring any grass near installations is kept relatively short. The Company has reduced all trees from the site location, built a berm to act as a buffer between the pad site and the staging area, which is located uphill from the storage tanks and pipeline fac ilities. Any vegetation management treatment outside the site’s boundaries may require coordination and communication, as well as approval, from any of those agencies listed above, including the Colorado National Forest Service. 9.4 Powerlines Falling trees can come into contact with powerline conductors and thus ignite wildfires and interrupt power to the site. Burned wooden power poles can also interrupt the current in distribution lines. Trees that come in contact with powerlines may also cause a ground arc, which can result in power outages and/or cause a wildfire ignition. None of these risks are present at the Battlement Mesa site because there are no trees large enough or near enough to the powerlines that pose a falling risk, and the power lines are constructed of metal towers and do not have wood power poles. In addition, the local utility company is responsible for the right-of-way easement where the powerlines are constructed to the south of the site and thus fall within the utility company’s responsibility for vegetation and EMERGENCY ACTION PLAN AND WIDLFIRE MITIG ATION Revision 00 10-JUN-14 U r s a R e s o u r c e s G r o u p , I I PAGE 27 of 35 structural management. As a result, Ursa Resources shall contact the local utility company to establish maintenance schedules and responsibilities of those agencies in maintaining the areas surrounding the power lines. Should any potential hazard develop that needs attention, Ursa Resources will contact the utility company and report it immediately. Disruption of a continuous electrical source of power during a wildfire incident may have a significant impact on industrial activities. Ursa Resources has installed back-up measures and power shut-off procedures for the site in the event of a wildfire emergency. 9.5 Debris Piles In order to decrease the risk of holdover fires from debris piles, best management practices require mulching rather than burning. If burning is used, ensure all legislative requirements are met and the proper permits are obtained prior to commencing a burn. After the burn is completed, ensure the remaining debris piles are properly extinguished by using one of the following three approaches: • Use a bare hand to check for hot embers (referred to as cold trailing); • Use a temperature probe or metal rod to detect heat within the piles; or, • Use infrared technology to scan the debris piles for residual hot embers. Where feasible, utilize a portable burning sled to reduce holdover potential and accelerate burning combustion, and reduce the amount of soil contained in the woody piles to allo w for more efficient burning and help reduce the chance for holdover fires. 9.6 ATVs and/or Equipment Personnel will be briefed on proper maintenance of ATVs and inspecting the vehicle’s exhaust system at regular intervals when operating and to park on sites with bare mineral soil, gravel or cement. Best Management Practices also recommend carrying a small container of water that can extinguish small fires if one should ignite from the exhaust system. Use of ATVs and other light vehicles with catalytic converters should not be parked in areas where tall dry grass is prevalent. Consider restricting the use of these vehicles, ATVs, during prolonged periods of extreme fire danger levels and forest closures due to fire risk. In addition, travel on ATVs should occur during the early morning and later evening when relative humidity is usually higher. Heavy equipment exhaust systems can cause wildfire ignition by one of the two fo llowing means: 1. Clearing forest vegetation with heavy equipment can cause an accumulation of very fine organic material on the exhaust systems. This organic material dries and if heated on exhaust systems to high temperatures that can cause it to ignite. Through vibrations, the ignited materials can fall to the forest floor and ignite vegetation, thus causing a wildfire. 2. Diesel engines that idle for long period build up carbon in the exhaust system. When the engine is throttled up and placed under load, small, hot carbon pieces can be expelled, causing wildfire ignition. During windy days, particles can be EMERGENCY ACTION PLAN AND WIDLFIRE MITIG ATION Revision 00 10-JUN-14 U r s a R e s o u r c e s G r o u p , I I PAGE 28 of 35 carried longer distances from the equipment and pose an even greater wildfire hazard. Ursa Resources will ensure that contractors inspect and clean their heavy equipment exhaust systems on a regular basis. While cleaning the equipment, park it on bare mineral soil if possible or spray the area with water before driving the equipment over the wet area to clean. Place heavy equipment with diesel engines over mineral soil or other non- flammable material. Then throttle up and place the diesel engine under load to expel any loose carbon particles after considering wind speed first. 9.6.1 Welding Operations Employees and contractors operating in wildland areas on the site shall conduct their operations on mineral soil if possible. As an alternative, during high fire hazard periods, the work area where welding is to take place can be wet down with water or foam additives if allowed by the Forest Service. Water is not very effective in fibrous soils during high and extreme build up indices (BUI), however. Ursa Resources will also ensure that all employees and contractors performing welding operations will have the appropriate equipment on hand for fire and emergency situations. Another option is to use a non-flammable shield around the area where welding will take place to confine and prevent the sparks from spreading in all directions. If it is essential to conduct welding operations during high and extreme fire danger periods with very high probability of wildfire ignitions, then a water tanker and crew may accompany the welding operation to patrol, detect, and extinguish any fires that may be ignited. W ildfire foam additives can be considered for use when welding on pipelines during high and extreme ignition potential periods to reduce the amount of water required to be on hand and to ensure the water penetrates into the organic layers. Properly mixed foam will increase the effectiveness of water by 3-5 times, depending on the foam and equipment used. Foam solutions act as a fire suppressant rather than a fire retardant. A suppressant extinguishes the flaming and glowing phases of combustion when applied directly to forest vegetation. 9.7 Emergency Response Measures to Wildfires Personnel should always know what to do during a wildfire, and thus URSA Resources will ensure that all personnel are trained on the provisions in this procedure for clarification and knowledge about wildfire hazards that may exist at URSA’s locations. During a wildf ire emergency, personnel should (1) determine the minimum number of personnel required to operate during a wildfire threat; and, (2) issue evacuation alerts. 9.7.1 Wildfire Evacuation Routes Evacuation routes are critical for evacuating personnel from a location during a wildf ire emergency. It should be noted that visib ility during a wildfire may be drastically reduced due to smoke drifting across access roads, and thus knowledge EMERGENCY ACTION PLAN AND WIDLFIRE MITIG ATION Revision 00 10-JUN-14 U r s a R e s o u r c e s G r o u p , I I PAGE 29 of 35 of evacuation routes and training thereon assist personnel in properly evacuating if needed. When identifying evacuation routes: • Identify safe helicopter landing areas for air lift evacuation. If road access has been cut off, helicopters may provide the only means of evacuation. • Identify adjacent waterways that can be accessed by boat if applicable. • Identify current roads into the site. Assess the threat of wildfire on the potential evacuation routes. 9.7.2 Access Roads All-weather gravel roads should be used as evacuation routes for emergency vehicles or workers. Narrow or dead-end roads without proper turnarounds are particularly problematic for wildfire suppression vehicles since they may not be able to turn around when necessary. Road rings are optimal for this purpose. Whenever possible, access or evacuation routes should double as barriers to fire spread by helping to slow or impede the spread of wildfire. During a wildfire, all-weather gravel routes can be used as both access routes for emergency vehicles and evacuation routes for workers. They may need to be used as both, depending on the location. Narrow or dead-end roads without proper turnarounds can be problematic for emergency vehicles. When detailing emergency access, it’s best to identify ring roads and other places where emergency vehicles have the ability to get back out. Access and/or evacuation routes should double as barriers to fire spread as a means for slowing or impeding the spread of wildf ire. 9.7.3 Water Sources W ildfire suppression needs substantial volumes of water from a dependable source. There are local water resources near the Battlement Mesa site, but the local emergency responders will determine how and where water sources will be utilized during a wildfire. By having water sources integrated into the plan, both the wildfire and structural fire suppression capability of the site will be greatly enhanced. 9.7.4 Personnel Safety Employees should know what to do during a wildfire emergency. During a wildfire emergency, determine the minimum number of personnel required to operate during a wildfire threat and know when to issue evacuation alerts. If evacuation alerts have been issued for a site, Ursa personnel should follow these protocols and ensure that all other emergency shut-off measures as identified by the Emergency Action Plan as well as additional site measures determined by the Company, shall also be followed. A proper assessment for access roads and water sources near and around the site should be analyzed to determine the flammability risk of the site and whether or not these resources can be used for proper fire suppression and fire barriers in EMERGENCY ACTION PLAN AND WIDLFIRE MITIG ATION Revision 00 10-JUN-14 U r s a R e s o u r c e s G r o u p , I I PAGE 30 of 35 order to protect personnel. If these resources are deemed adequate to reduce high flammability risk, then they should be included as part of a site drawing and given to local emergency responders who would be responsible for fighting the wildf ire. Obviously, the lowest flammability risk occurs with facilities that have gravel or paved access roads to the facility that can also be used as evacuation routes and which have fire suppression measures located on site (such as natural water resources), and that ensure emergency vehicles have a proper turnaround for entering and leaving the site during an emergency. Employees must be adequately trained on the evacuation plan and routes, the facility management to reduce wildfire risk, flammability of surrounding vegetation, contact numbers for local agencies (including utility company for powerline management), and emergency alarms and local emergency warnings in order to successfully maintain a safe work environment. In case of a nearby wildfire that poses no risk to the site and which has not prompted evacuation orders, employees shall monitor the site for ignitions from embers and extinguish them ONLY to ensure personnel safety if evacuation orders have not been issued and ONLY if employees have been properly trained on how to use the fire extinguishers. Once evacuation orders have been issued, employees shall follow emergency protocol and NOT fight the wildfire. The local emergency responders are responsible for wildfire firefighting and Ursa personnel need to stay out of their way by evacuating and allowing emergency responders to do their job. Ursa will obtain and maintain emergency contact lists, including the numbers of local emergency responders and reporting agencies in case of a wildfire warning or evacuation measure issued due to wildfire risk. The number of on-site personnel should be decreased, or evacuated in its entirety, after emergency shut- down procedures and other measures in the Emergency Action Plan are completed, if possible. In addition, evacuation staging areas to be used during a wildf ire event shall be identified, and then personnel shall be made aware of evacuation alerts, routes, and staging areas away from the wildfire and the method to be used for those alerts so that personnel know what to do in case of a wildfire. The methods of transportation for evacuation shall also be determined and personnel shall be notified of that method during a wildfire event. Short-term food and safe lodging arrangement may also be determined by Ursa as part of its site- specific wildfire emergency measures. In addition, personnel will be trained and tested, such as conducting mock wildfire exercises, to test the evacuation plans and train personnel in the Emergency Action Plan measures in the event of a wildf ire. If the potential exists for Ursa personnel to become trapped by an approaching wildf ire, those individuals will be tra ined to recognize and utilize adequate evacuation staging areas that have been identified prior to commencing operations. Staging areas should have the following characteristics: • Clean burn site, natural cleared area, or constructed site free of vegetation; • Quickly and safety accessed from the worksite; EMERGENCY ACTION PLAN AND WIDLFIRE MITIG ATION Revision 00 10-JUN-14 U r s a R e s o u r c e s G r o u p , I I PAGE 31 of 35 • Free of hazardous materials; and, • Radiant heat and preheated air associated with wildfire flame fronts must also be considered in evacuation staging area selection and size. For successful employee participation, Ursa shall review wildfire safety issues each spring with its employees. They will inform personnel of the implications of wildf ire in the forest environment and be trained upon emergency procedures in preparation for a wildfire event and/or entrapment. In addition, the protocols for reporting a wildfire, or if they see smoke or fire, shall be reviewed. Any wildfire trends, and obtaining and/or monitoring weather information in the surrounding area on days when fire danger is high or extreme, shall also be done by Ursa when necessary. Whenever fire danger ratings are high and extreme and restrictions may be in effect, Ursa will ensure its employees are notified of such conditions and have received proper training for managing those situations (such as obtaining permits, heeding road closures or forest closures, open fire bans, etc.) When possible, Ursa shall coordinate its wildfire prevention measures with state, federal, and local agencies responsible for handling wildfires and other forest management issues. In these instances, Ursa shall attempt to ensure that all items relating to wildfire administration, prevention, pre-suppression, wildfire operations, and training are addressed and understood by its employees and are in coordination with the other agencies’ requirements and wildfire measures. Training prepares personnel for a more coordinated and educated approach to both wildf ire prevention and wildfire emergency response. Training is essential for firefighter safety, equipment compatibility, integrating communications, understanding procedures and wildf ire incident command structures, understanding wildfire management and fire behavior, and developing and implementing consolidated emergency response plans with other agencies as stated above. 9.8 General Wildfire Safety Tips Many incidents that result in tragic and costly losses from wildfire can be attributed to substandard communication and lack of proactive measures in emergency response planning. When planning a wildf ire emergency response plan, the following recommendations shall be analyzed: • Incorporating open spaces such as borrow pits, lay down yards, spoil piles, parking lots, for staging equipment and personnel in wildfire emergencies; • Place open spaces downslope and/or upwind of the site (using the existing wind conditions as a guideline): • Use open spaces as a barrier to fire spread if they are at least thirty (30) yards wide on level ground and up to fifty (50) yards wide when located near slopes; • Open spaces should have trimmed short grass, gravel, or mineral soil. • Main access road surfaces should provide two-way access with a travel surface of not less than 6.1 yards; • Fire service access routes should be identified and connect to principal roadways; • Road gradients should not exceed ten (10%) percent; EMERGENCY ACTION PLAN AND WIDLFIRE MITIG ATION Revision 00 10-JUN-14 U r s a R e s o u r c e s G r o u p , I I PAGE 32 of 35 • Dead-end roadways that are more than ninety (90) yards in length should be constructed with a turnaround at the end and have no less than eighteen (18) yards turning radius or a hammerhead “T” alternate turnaround. A site loop or ring road is the best option for short-term planning; • All gates should be located at least nine (9) yards off the main road and does not open downward. Gate openings should provide a clear opening of not less than 0.6 yards wider than the access or traveled roadway; • Fire service personnel should be provided with ready access to any locking mechanisms at the site; • Bridges should be designed and built with an all-weather surface capable of supporting heavy pieces of equipment traveling across the bridge. Weight limits should be clearly posted at the approaches to each bridge; • If the main access road is cut off by a wildfire, alternative emergency evacuation routes will be identified; • Natural water sources, such as streams, small lakes, and rivers, should be identified and, if not available, a water storage facility can be developed on high value sites such as tank farms and plant sites for emergency use. Non-draining borrow pits or large tanks may be used for storing large volumes of water in extreme cases, but will only be done at the recommendation of local emergency responders when that agency deems it necessary; and, • Ensure access to natural water sources for tanker trucks and portable pump set- up is identified where possible and if located near the site and in coordination with local emergency responders and their requirements for wildfire firefighting. 10.0 EVENT NOTIFICATIONS AND REPORTING All incidents (serious or non-serious) must be reported to the Safety Officer. Note: All near miss incidents and equipm ent damage accidents must be reported to the Battlement Mesa Site Supervisor and/or Safety Officer so corrective actions can be taken to avoid the same or similar situations in the future. 10.1 Event Notifications The notifying first responder or acting Incident Commander will report the emergency to Alternate Project Coordinator or Site Manager. Battlement Mesa Site employees/first responders will endeavor to keep all affected agencies informed of any emergency or incident that may occur. Small incidents that do not pose a human health or environmental hazard shall be remedied immediately by trained personnel. Incidents that pose a serious threat to employees, the public, the environment, or property will immediately be reported to the Alternate Project Coordinator or Site Manager. Notifications to outside regulatory agencies shall be made as required. 10.2 Reporting Requirements Spills or leaks that can be contained wholly on-site or does not represent a reportable quantity (RQ) value as per 40 CFR 117 should be reported to the appropriate Ursa representative. Spills or leaks that meet or exceed RQ values as per 40 CFR 117 will result in the contact of the following agencies: EMERGENCY ACTION PLAN AND WIDLFIRE MITIG ATION Revision 00 10-JUN-14 U r s a R e s o u r c e s G r o u p , I I PAGE 33 of 35 • National Response Center (800-424-8802) • EPA Region 8 – Mountain States (800-227-8917) Spills or leaks which pose a potential threaten public health and safety requires the contact of all the following in addition to those above: • Parachute Police Department (970-285-7630) • Colorado State Patrol (970-328-0249) • Grand Valley Fire Protection District and Emergency Services (970-285-9119) • Grand River Hospital District (970-625-1510) 10.1.1 Emergency Notification Depending on where the incident occurs (on or off the pond site), notification may be required pursuant to the Emergency Planning and Community Right-to-Know Act (EPCRA). The Project Coordinator or Site Manager shall make the determination if reporting is required. Reporting shall contain the following information to the extent known at the time of notice, as long as a delay does not occur in reporting results: • Where is the spill? • What spilled? • How much spilled? • How concentrated is the spilled material? • Who spilled the material? • Is anyone cleaning up the spill? • Are there resource damages (e.g. dead fish or oiled birds)? • Who is reporting the spill? • How can the person reporting the spill be reached? 10.1.2 Follow-up Notice Requirements A nationwide notification system has been established for hazardous material spills during transport. The Chemical Manufacturer’s Association’s Chemical Transportation Emergency Center (CHEMTREC) is located in Washington, D.C. (800-424-9300). The information specialist on duty will ask for the following information: • Name of the caller • Location of the caller • Name of the shipper/Transporter • Product or hazmat involved • Destination of the hazmat • Location of incident • What happened • Weather conditions • Proximity to populated areas. CHEMTREC will give the caller recommendations for controlling the emergency situation until the shipper of the materials and a specialist can contact the caller promptly. EMERGENCY ACTION PLAN AND WIDLFIRE MITIG ATION Revision 00 10-JUN-14 U r s a R e s o u r c e s G r o u p , I I PAGE 34 of 35 11 POST-EMERGENCY RESPONSE INCIDENT INVESTIGATION 11.1 Post-Emergency Assessment A post-emergency assessment will be conducted by the Incident Commander as soon as practicable following stabilization of the emergency condition. If classification of the emergency or results of the assessment indicate that more extensive investigation is required, the Alternate Project Coordinator, Site Manager, or Site Safety Officer will initiate the investigation. 11.2 Lessons Learned Lessons learned from the emergency will be documented and distributed to appropriate project personnel, incorporated into project personnel training, and used to amend this plan and to institute corrective measures and procedures in an effort to prevent a similar emergency condition in the future. In addition, the lessons learned will be incorporated in the project Operating Experience/Lessons Learned program. EMERGENCY ACTION PLAN AND WIDLFIRE MITIG ATION Revision 00 10-JUN-14 U r s a R e s o u r c e s G r o u p , I I PAGE 35 of 35 Attachment A AGENCY EMERGENCY CONTACT LIST N AME PHONE FEDER AL AND ST ATE GOVERNMENT Bureau of Land Management (970) 257-4800 National Response Center (800) 424-9300 Colorado Oil & Gas Conservation Commission (COGCC) (888) 235-1101 CHEMTREC (800) 424-9300 SEPC (State Emergency Planning Committee) (970) 846-3912 Colorado Division of Wildlife (DOW) (970) 255-6100 US Forest Service (USFS) District Ranger in Rifle (970) 625-2371 Colorado Department of Public Health & Environment (CDPHE) (877) 518-5608 Poison Control Hotline (800) 222-1222 LOCAL GOVERNMENT and OTHER AG ENCIES Grand Valley Fire Protection District (970) 285-9119 Garfield County Emergency Communications Center 911 Garfield County Dispatch - Direct (970) 625-8095 Grand River Hospital District (970) 625-1510 Parachute Police Department (970) 285-7630 St. Mary’s CareFlight Helicopter (970) 332-4923 Local Emergency Planning Committee – Garfield County (970) 945-0453 URS A OPER ATIONS Ursa Operating LLC Emergency Number (855) 625-9922 Ursa Resources Group II, Inc. Main Office (713) 456-3000 NOTE: DO NOT USE “911” from a satellite phone. You will likely not be able to reach a local dispatcher. In many oil and gas work areas, cell phones will not connect with a local dispatch either. The above phone numbers can be used from any phone and will reach immediate response teams. It is very crucial that each individual follows this procedure to ensure an appropriate response time of emergency personnel. Site-Specific Emergency Response Plan –All Operations P.U.D. Battlement Mesa IN CASE OF EMERGENCY, CALL 911 FOR FIRE DEPT., AMBULANCE, POLICE URSA 24/7 EMERGENCY NOTIFICATION: 1-855-625-9922 1-(970) 625-8095 GARFIELD COUNTY EMERGENCY COMMUNICATIONS CENTER Report All Emergencies/Spills to Respective Leads Per The Operation: Ursa On-site Surface Drilling Operations Craig Smith 208.816.6803 Ursa On-site Reps Drilling Operations Nate Gill 970.819.3989 or Richard McNeil 720.339.7239 Company Man Shack Rig Phone 970.623.0614 Completions Operations Contact Information Ralph Tolle 307.350.5501 or Luke Grieger 970.985.2332 Ursa Rifle Team Contact Information Shane Vaughn 970.623.9539 (Production) Matt Honeycutt 970.812.2198 (Operations) Pake Younger 970.260.2423 (Completions) Hans Wychgram 303.884.9079 (Drilling) Jeff Powers 970.309.9359 (Land/Community Relations) Tara Mall 970.618.2155 Safety The P.U.D is a parcel of land lying in Sections 5, 6, 7, 8, 9, 10, 16, 17, 18 and 19. Township 7 South, Range 96 West of the Sixth Principal Meridian County of Garfield, State of Colorado. PRIMARY MUSTER AREA AT ENTRANCE OF LOCATION UPON COMPLETION OF PADS. Horn Alarm Signals 1 Long Blast – Well Control Emergency Repeated Short Blasts – Fire Repeated Long Blasts – Evacuate to Muster Area General Emergency Instructions: All emergency situations are unique and present various conditions. Always evaluate the situation before deciding on a course of action. Ursa representative MUST assure that all personnel on location understand the following: ALL EMERGENCIES: DO NOT “RUSH IN” UNTIL YOU HAVE CONSIDERED THE FOLLOWING:  Is there an immediate threat to life from fire, explosion, structure collapse, chemical spill or release? If so, sound the alarm and evacuate  Is there an immediate potential for release of toxic (poisonous) chemicals or fumes into the air? If so, evacuate uphill and upwind of the release  Is there an immediate potential for uncontrollable energy release (pressure), electrical shock, chemical spill, fuel to “feed” a fire? If so, de- energize equipment, disconnect power, shut-off valves and fuel sources, but only if safe to do so and if action will not cause a more serious problem  When in doubt, sound the alarm, evacuate, and call for help FIRE:  Sound the alarm (repeated short blasts on the horn) and call for help  Do not fight a fire until you have alerted someone else  Isolate, shut-off fuel sources  Discharge fire extinguishers using the Pull, Aim, Squeeze, Sweep method  Only fight fires in the incipient (beginning) stage. Rule of thumb: If you have already discharged one 20 – 30 pound fire extinguisher at the base of a fire and have made no impact on the fire, then fire is beyond the incipient stage. Evacuate, shut off fuel sources.  Never fight a fire without planning your escape route first  Never turn your back on a fire while attempting to extinguish – fires can “reignite” even if they appear to be extinguished WELL CONTROL / BLOWOUT EMERGENCY:  Sound the alarm (1 long blast on the horn)  Follow well control / blowout procedures as practiced in weekly drills  Assure that the Ursa Representative is notified General Emergency Instructions: All emergency situations are unique and present various conditions. Always evaluate the situation before deciding on a course of action. Ursa representative MUST assure that all personnel on location understand the following: MEDICAL EMERGENCY:  Make sure it is safe for you to be in the area  Notify supervisor  Assure the airway is open; the patient is breathing and has a pulse. If not Call 911 and start CPR  Control bleeding, treat for shock  Never move an injured person unless there is an immediate threat to his/her life CHEMICAL SPILL EMERGENCY:  Shut off the source of the spill if possible  Notify supervisor  Do not walk or drive through spill areas. If vapors are released, move to a safe distance uphill and upwind of the release and vapor clouds  Attempt to identify spilled material  Follow guidelines in North American Emergency Response Guidebook – 2008 Version  Attempt to contain spills only if determined to be safe to do so by supervisor  Call for help if needed SEVERE WEATHER:  Monitor news and weather reports  Notify supervisor of threatening conditions  The, trailers, and vehicles. Get low to the ground, away from trees, preferably in a ditch or depression if no likelihood of flash-flooding  Seek shelter indoors or under cover during severe lightning  Never attempt to walk or drive across flooded roads or ditches ***IF IN DOUBT ABOUT ANY EMERGENCY, EVACUATE AND CALL 911*** Report All Emergencies to Ursa on-site Representative OR URSA 24/ 7 EMERGENCY NOTIFICATIONS 1-855-625-9922 Ursa Operating Company, LLC: 24 Hour Emergency Contact Number 1.855.625.9922 Ursa Operating Company, LLC 792 Buckhorn Drive Rifle, CO 81650 970.625.9922 Ursa Operating Company, LLC 1050 17th Street #2400 Denver, CO 80265 720.508.8350 Matt Honeycutt- Operations Superintendent Direct Number (970) 625.9922 Cell Number (970) 812.2198 Shane Vaughn- Production Superintendent Direct Number (970) 625.9922 Cell Number (970) 623.9539 Pake Younger- Completions Manager Direct Number (970) 625.9922 Cell Number (970) 260.2423 Tara Mall- Safety Department Direct Number (970) 625.9922 Cell Number (970) 618.2155 Rob Bleil- Regulatory and Environmental Manager Direct Number (970) 625.9922 Cell Number (720) 425-0303 Jeff Powers- Ursa Land Department Direct Number (970) 625.9922 Cell Number (970) 309.9359 Kip Costanzo- Construction and Earthwork Cell Number (970) 379. 2777 Ursa Operating Company Denver Contacts Contact Numbers Dana Johnson- VP Operations Direct Number (720) 508.8350 Cell Number (303) 748.2905 Hans Wychgram- Drilling Manager Direct Number (720) 508.8350 Cell Number (303) 884.9079 Federal and State Agencies Contact Numbers National Poison Control Center Hotline Direct Number (800) 222.1222 National Response Center Direct Number (800) 424.8802 COGCC Oil Spill Response Direct Number (303) 894.2100 COGCC NW Contact- Shawn Kellerby Direct Number (970) 285.7235 Cell Number (970) 712.1248 COGCC Direct Number (888) 235.1101 COGCC- Alex Fischer Direct Number (303) 894.2100 Ext. 5138 EPA Region 8 Colorado Direct Number (800) 227.8917 Colorado Department of Public Health and Environment (CDPHE) Direct Number (877) 518.5608 Garfield County Emergency Communications Center Direct Number (970) 625.8095 911 Local Emergency Planning Committee Direct Number (970) 945. 0453 Garfield County Oil and Gas Liaison- Kirby Wynn Direct Number (970) 625.5905 Cell Number (970) 987.2557 Garfield County Airport Direct Number (970) 625.1091 Garfield County Road and Bridge Direct Number (970) 625.8601 Bureau of Land Management- Julie King LPE Regional Office(970) 257.4800 Direct Number (970) 876.9036 Cell Number (970) 319.2509 Colorado Division of Wildlife (DOW) Direct Number (970) 255.6100 Fish and Wildlife Region 6 Colorado Direct Number (303) 236.7920 Energy Liaison Colorado Division of Wildlife Direct Number (303) 236.7920 US OSHA Direct Number (800) 321.6742 Ursa Contractors Contact Numbers Waste Removal/ Porta Can- Redi Services Direct Number (970) 625.0233 Field Environmental Consultant- Cody Smith Cell Number (303) 902.1532 HCSI Direct Number (970) 243.3271 Kris Rowe Direct Number (970) 243.3271 Cell Number (970) 261.2015 Maurice Foye Direct Number (970) 243.3271 Cell Number (970) 260.3650 Water Hauling and Hydrovacs Contact Numbers A & W Transport Direct Number (970)625.8270 625.8270 Gonzo (970) 283.5555 Truck Pusher/ Field Supervisor- Jason Hartbauer Cell Number (970) 618.4814 Truck Pusher/ Field Supervisor-Travis Tyner Cell Number (970) 618.5486 Elder Trucking Direct Number (970) 625.4189 Jared Elder Cell Phone (970) 618.5612 Water Management Contact Numbers MCS- Bob Direct Number (970) 216.3815 ADESCO Pumps- Cameron Cell Number (970) 589.5552 Drilling: Camps/Cement/Directional/Trucking/Mud Contact Numbers Capstar Drilling- Chris Ellison Superintendent Cell Number (307) 258.4279 Stallion Camps Area Supervisor- Bart Steele Cell Number (970) 274.6549 Payzone Directional-Nick Dean Cell Number (435) 725.3745 RW Jones Trucking- Brett Kempton Cell Number (435) 789.1231 NOV-Anthony Valenti Cell Number (303) 573.6827 NOV Drilling Fluids- Jose Mora Cell Number (727) 612.1460 Redi Cutting Handling-Rick Cowens Cell Number (970) 456.7786 Halliburton- Trevor Courtney Cell Number (970) 628.5928 BGS Mudlogging- Tarin Boxberger Cell Number (970) 623.6626 Completions Frac/ Cement Contact Numbers Calfrac Well Service Direct Number (970) 248.9890 Area Supervisor- John Conrad Cell Number (970) 985.1644 Area Supervisor- Blake Vancuren Cell Number (970) 210.7303 Weatherford- Scott Slaugh Cell Number (435) 393.5898 MCS- Bob Swim Cell Number (970) 216.3815 Mesa Wireline- Josh Nolan Cell Number (970) 640.4033 FMC Wireline Cell Number (970) 245.6752 LEC Services- Eric Moore Cell Number (970) 985.9200 Monument Wells Services - Mark Vandehi Cell Number (970) 257.6169 EXC Snubbing Services- Tom Daniels Cell Number (307) 389.1836 Premier Thru Tubing- Derek Winkler Cell Number (435) 621.3032 Fat Dog Foam- Ted Dexter Cell Number (970) 773.4339 Weatherford Cell Number (970) 263.8501 Direct Number (970) 245.0593 Eagle Well Service Cell Number (970) 812.6258 Production Contract Numbers Mesa Production- Ty Gaylord Cell Number (970) 623.3629 Multichem-Matt Merkel Cell Number (970) 210.3328 Mesa Production- Scott Cell Number(970) 263.7212 JPPS- Jason Hauck Cell Number (970) 618.4468 Basin Western-Erick Brown Cell Number (970) 985.6152 StreamFlo- Cale Labrum Cell Number (970) 366.6381 Misc Vendors Contact Numbers Quadna Pumps- Rob Cell Number (970) 242.9226 Go Rentals- Justin Stanford Cell Number (970) 618.0464 Avalanche Equipment-Bernie Hunt Cell Number (970) 778.5276 Western Colorado Waste Cell Number (970) 210-2330 Emerson- Rod Gladden Cell Number (505) 419.1972 Ensure all OVERSIZE/OVERWEIGHT contractors stand down during school bus schedule. Do not use home owners drive ways and/or block thoroughfares to stage equipment. School Bus Schedule 2014-2015 For Rifle, Silt, Silt Mesa and Peach Valley areas. Re-2 school district doesn’t have school on Fridays. Divide Creek: Mclin B and Mclin C Morning Schedule: 6:05-7:05 a.m. Afternoon Schedule: 4:30-5:15 p.m. Dry Hollow: Valley Farms, Dixon B, Burkle and O’toole: Morning Schedule: 6:05-7:05 a.m. Afternoon Schedule: 4:40-5:55 p.m. Mamm Creek: Eagle Springs Access to Gentry Pads, Dixon A, Dever C and Wasatch Bench Morning Schedule: 6:10-7:10 a.m. Afternoon Schedule: 4:35-5:10 a.m. Hwy 6 & 24 traveling between Rifle and Silt: All North Bank Pads and Coloroso Pad: (ENSURE ALL CONTRACTORS STOP AT RAILROAD CROSSING!!!!) Morning Schedule: 6:20-7:35 a.m. Afternoon Schedule: 3:25-5:25 p.m. North of Hwy 6 & 24: Fenno, Three Siblings and Demos: Silt Mesa and Peach Valley Morning Schedule: 6:25 a.m.-7:15 a.m. Afternoon Schedule: 4:45-5:40 p.m. School Bus Schedule District 16 2014-2015 For Parachute and Battlement Mesa (There are no buses running on Una County Rd 300): District 16 doesn’t have school on Mondays. Monument Ridge and Speakman: Morning Schedule: 6:30-7:30 a.m. Afternoon Schedule: 4:00-5:00 p.m. S M T W Th F Sa 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 1 2 3 4 5 6 S M T W Th F Sa 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 November 2014 March 2015 S M T W Th F Sa 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 February 2015 S M T W Th F Sa 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 Garfield School District No. Re-22014-2015 S M T W Th F Sa 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 1 October 2014 µ August 2014 S M T W Th F Sa 28 29 30 31 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 January 2015S M T W Th F Sa 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31µ September 2014S M T W Th F Sa 31 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 September 1 - Labor Day-THERE IS SCHOOL FRIDAY SEPTEMBER 5November 26-28 - Thanksgiving BreakDecember 22 - January 2 - Winter BreakMarch 23 - 27 - Spring BreakMay 25 - Memorial Day 1st Q - 36 days 2nd Q - 34 days3rd Q - 40 days 4th Q - 39- days December 2014S M T W Th F Sa 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 S M T W Th F Sa 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 April 2015 May 2015 New Teacher Orientation/NO SCHOOLOrientación Para Maestros Nuevos/NO HAY CLASES Holiday/School ClosedDía Festivo/NO HAY CLASES Teacher Workday/NO SCHOOLDía de Trabajo Para Maestros/NO HAY CLASES Collaboration Day/Student HolidayDesarrollo del Personal/NO HAY End of Quarter/Final del Cuarto First/Last & 1st day 2nd semesterPrimer/Último & Primer Día del Segundo Semestre Fridays - No School - There is school Fri. Sept. 5 µ District Holidays District phone numbersDistrict Office 665-7600Rifle High School 7:55 a.m - 4 p.m. 665-7725Rifle Middle School 7:55 a.m. - 4 p.m. 665-7900Highland Elem. 7:55 a.m. - 3:40 665-6800Graham Mesa Elem. 7:55 a.m. - 3:40 665-7500Wamsley Elementary 7:55 a.m. - 3:40 665-7950Cactus Valley Elem. 8:00 a.m. - 3:45 665-7850Coal Ridge H.S. 8:00 a.m. - 4 p.m. 665-6700Riverside M.S. 7:55 a.m. - 4 p.m. 665-7800Kathryn Senor Elem. 8:05 a.m. - 3:50 665-7700Elk Creek Elem. 8:00 a.m. - 3:45 p.m. 665-6900 µ µ GARFIELD COUNTY SCHOOL DISTRICT NO. 16 2014-2015 SCHOOL YEAR File: ICA-E Our Mission …. “As a result of our efforts, all students will be successfully prepared for life in a safe and nurturing environment.” SEPTEMBER 2014 S M T W T F S H 2 3 4 5 6 7 PD 9 10 11 12 13 14 15 16 17 18 19 20 21 PD 23 24 25 26 27 28 29 30 OCTOBER 2014 S M T W T F S 1 2 3 4 5 PT PT 8 9 10 11 12 13 14 15 16 Q 18 19 W 21 22 23 24 25 26 27 28 29 30 31 NOVEMBER 2014 S M T W T F S 1 2 PD 4 5 6 7 8 9 10 11 12 13 14 15 16 PD 18 19 20 21 22 23 24 25 26 H 28 29 30 DECEMBER 2014 S M T W T F S PD 2 3 4 5 6 7 8 9 10 11 12 13 14 PD 16 17 18 Q 20 21 22 23 24 H 26 27 28 29 30 31 JANUARY 2015 S M T W T F S H 2 3 4 W 6 7 8 9 10 11 12 13 14 15 16 17 18 H 20 21 22 23 24 25 PD 27 28 29 30 31 FEBRUARY 2015 S M T W T F S 1 2 3 4 5 6 7 8 PD 10 11 12 13 14 15 H 17 18 19 20 21 22 23 24 25 26 27 28 MARCH 2015 S M T W T F S 1 PD 3 4 5 6 7 8 9 10 11 12 Q 14 15 W 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 APRIL 2015 S M T W T F S 1 2 3 4 5 PT 7 8 9 10 11 12 13 14 15 16 17 18 19 PD 21 22 23 24 25 26 27 28 29 30 MAY 2015 S M T W T F S 1 2 3 PD 5 6 7 8 9 10 11 12 13 14 15 16 17 PD 19 20 Q W 23 24 H 26 27 28 29 30 3 1 JUNE 2015 S M T W T F S 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 JULY 2015 S M T W T F S 1 2 H H 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 Adopted: February 12, 2013 Revised: March 11, 2014 SCHOOLS NOT IN SESSION All School Holidays & Breaks Sept. 1 ~ Labor Day Feb. 16 ~ Presidents’ Day Nov. 25 - 28 ~ Thanksgiving Break Mar. 23 - 27 ~ Spring Break Dec. 22 – Jan. 2 ~ Winter Break May 25 ~ Memorial Day Jan. 19 ~ Martin Luther King Jr. Day July 3 ~ Independence Day Observed July 4 ~ Independence Day Parent/Teacher Conferences October 6 District-Wide ~ Hours to be Determined October 7 CFL, BUE, GVMS Only ~ Hours to be Determined April 6 District-Wide ~ Hours to be Determined Teacher Professional Development & Workdays August 11 New Teacher Boot Camp August 12, 13, 14 Professional Development August 15, 18 Teacher Workdays August 19 First Day of School August 19, 20 CFL Kindergarten Pre-Assessments ~ Mandatory Half-Day Assigned Sessions August 26 First Day of School for Preschool September 8, 22 Professional Development October 6 P/T Conferences ~ District Wide October 7 P/T Conferences ~ CFL, BUE, GVMS Only ~ GVHS in Session October 20 Teacher Workday November 3, 17 Professional Development November 21 CFL Thanksgiving Feast/Community Day ~ No School CFL Only December 1, 15 Professional Development January 5 Teacher Workday January 26 Professional Development February 9 Professional Development March 2 Professional Development March 16 Teacher Workday April 6 P/T Conferences ~ District Wide April 20 Professional Development May 4, 18 Professional Development May 22 Teacher Workday ~ Checkout Statistical Record Data & General Information Classes Begin August 19 First Quarter Ends October 17 CFL/BUE/GVMS ~ 35 days GVHS ~ 36 Days Second Quarter Ends December 19 CFL ~ 31 Days BUE/GVMS/GVHS ~ 32 Days Third Quarter Ends March 13 CFL/BUE/GVMS/GVHS ~ 40 Days Fourth Quarter Ends May 21 CFL/BUE/GVMS/GVHS ~ 35 Days Teachers’ First / Last Day August 12 / May 22 Assistant Principals’ First Day August 1 Assistant Principals’ Last Day June 5 Principals’ First Day Elem., M.S., August 1 H.S., July 24 Principals’ Last Day Elem., M.S., June 12 H.S., June 25 TCAP Testing Window March 9 – April 20 Graduation “Class of 2015” May 23 (10:00 a.m.) KEY H All School Holidays/Breaks Board of Education Regular Meeting (5:30 p.m.) CFL Kindergarten Pre-Assessments CFL Thanksgiving Feast/Community Day ~ No School CFL Only Q End of a Quarter First Day of School First Day of School ~ Preschool Grand Valley High School Graduation (10:00 a.m.) BC New Teacher Boot Camp PT Parent/Teacher Conferences PD Professional Development W Teacher Workday AUGUST 2014 S M T W T F S 1 2 3 4 5 6 7 8 9 10 BC PD PD PD W 16 17 W 19 20 21 22 23 24 25 26 27 28 29 30 31 Colorad o Operat i o n s App•nd lx C TN f.IDF.NTXO TTF TCA TIO'\ & i\olANAGF.i\olr:"iT P ROT OCOT. 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(120;112 G-CtJOO J . ?00.'1'i!J$ (910) ~-9JG9 s .vaop r37o) .:.2J-95Jf.t r .Youngoe : (')1l) 21;0-1A23 srJLL PROC.RA.YI LEAD t.,EOIA.'COMMUl'tfTY H .'Ny ch7atT1 •:303)884.0C~ K.IW11e F.J1!)) 26 1420 IS 0 . Sim~1 (28 1) J67·1 117 H A.S I. C\~<ill (~t'U; 61 tl :!:1b t · :-COTI: )IIDIA J:\Qt 1RII5 s n orLD DC DIREC'II:O TO 00:-C 5ThlP50 :V , Article 7-107 Road Assessment Ursa Operating Company LLC Watson Ranch B Injection Well OA Project No. 014-3005 760 Horizon Drive, Suite 102 TEL 970.263.7800 Grand Junction, CO 81506 FAX 970.263.7456 www.olssonassociates.com Road Assessment Ursa Operating Company LLC Watson Ranch B Injection Well The Ursa Operating Company LLC (Ursa) Access Road begins where it turns off of County Road (CR) 303 (Gardner Lane) in the SW ¼ of the SW ¼ of Section 17, Township 7 South, Range 95 West of the 6th P.M. and terminates at the Ursa Watson Ranch B Injection Well site in the SE ¼ of the SW ¼ of Section 17, Township 7 South, Range 95 West of the 6th P.M. This access road is approximately 1500 feet from CR303 to the Watson Ranch B well pad. Statement of Adequacy This access road is typical of roads providing access to natural gas production facilities in Garfield County. The roadway is adequate for the intended use. Geometry of Road The following tables compare this access road to the Garfield County Roadway Standards found in Table 7-107 of the Land Use and Development Code for Semi Primitive roads. Table 1 Ursa Watson Ranch Access Road Table 7-107: Roadway Standards Design Standards Semi Primitive Ursa Watson Ranch Access Road Design Capacity (ADT) 21-100 6-26 Minimum ROW Width (Feet) 40 0 Lane Width (Feet) 8 8-18.5 Shoulder Width (Feet) 2 0-10.5 Ditch Width (Feet) 4 0 Cross Slope 2% Chip Seal Chip Seal 3% Gravel 1-2.8 Shoulder Slope 5% 1-2.8 Design Speed n/a n/a Minimum Radius (Feet) 50 231 Maximum % Grade 12% 3.5 Surface Gravel Gravel Watson Ranch B Injection Well Ursa Operating Company LLC Access Road Assessment Page 2 Table 2 Ursa Watson Ranch B Access Road Table 7-107: Roadway Standards Design Standards Semi Primitive Ursa Watson Ranch B Access Road Design Capacity (ADT) 21-100 6-26 Minimum ROW Width (Feet) 40 0 Lane Width (Feet) 8 8 Shoulder Width (Feet) 2 4.5 Ditch Width (Feet) 4 0 Cross Slope 2% Chip Seal Chip Seal 3% Gravel 3 Shoulder Slope 5% 5 Design Speed n/a n/a Minimum Radius (Feet) 50 75 Maximum % Grade 12% 4 Surface Gravel Gravel The road analysis is covered by two sections. A portion of the roadway was previously constructed and is referred as Ursa Watson Ranch Access Road in Table 1. The second portion of the roadway is yet to be constructed and is referred as Ursa Watson Ranch B Access Road in Table 2. Field observations and data gathering were conducted on December 10, 2014. The observations are summarized as an attachment to this assessment. River Valley Survey, Inc. provided a plan titled “Construction Layout Drawing” that includes the plan and profile of the roadway yet to be constructed. The road is across private land and currently is not covered by a dedicated access easement or dedicated right-of-way (ROW). Legal access is granted through an easement that is part of the First Amendment to the Surface Use and Easement Agreement between Watson Ranches, Ltd and Ursa, dated September 11, 2014. The road width varies between 16 feet and 37 feet. The portion of the roadway that is 16 feet in width does not allow for a shoulder width of 2 feet minimum. Roadside ditches were not constructed and are not shown within the improvement plan for the proposed roadway. The existing cross slope and shoulder slope varies between 1% and 2.8%. The proposed cross slope is anticipated to be constructed as 3%; however, the improvement plan for the proposed roadway does not include a typical section. The proposed shoulder slope is anticipated to be constructed as 5%; however, the improvement plan for the proposed roadway does not include a typical section. The horizontal radii range from 75 feet to 231 feet. All of the turns meet the minimum 50 foot standard radius. The grade of the road varies between 3.5% to 4%, which is less than the maximum grade allowed of 12%. Watson Ranch B Injection Well Ursa Operating Company LLC Access Road Assessment Page 3 The existing road surface is gravel. The anticipated road surface of the proposed roadway is gravel; however, the improvement plan does not include a typical section. The road geometry changes occasionally with maintenance activities. Cross slopes change during maintenance operations. The road was built to follow the general topography of the area with minimal change to the natural grade. Safety/Structural Issues No obvious safety or structural issues were observed on the date of the field observation, December 10, 2014. Maintenance Ursa oversees all of the maintenance on the road. The road is inspected on a regular basis for maintenance issues. Maintenance includes grading as needed to remove washboard and repair potholes. The road surface is graveled as needed to maintain the road base with attention to dust control. Speeds are low to promote safety and reduce road damage. Travel Demand Average Daily Traffic (ADT) is expected to be between 21 and 100 as shown in the Basic Traffic Study prepared by Olsson Associates, dated January 2015, included with this submittal. This roadway is being assessed according to the standards for a Semi Primitive road. Traffic associated with the additional land use of an injection well at the site includes pickup trucks (2 trips) per day for inspections. There will be a short construction phase. The construction phase will last approximately three (3) days. Daily traffic during the phase will include two (2) lowboys making two round trips (4 one-way trips) for equipment and tanks. One (1) additional lowboy would arrive on day 2 and leave on day 3 to transport the earthmover. There will be two pickups per day arriving in the morning and leaving at the end of the work day. There are expected to be twenty round trips (40 one way trips) per day during the expected drilling and completion activities. There are 20 trucks (40 one-way trips) per day expected during the production phase. Other Evidence of Compliance Section 7-107.A Access to Public Right-of-Way The private road to the site has direct access to CR 303. A copy of the driveway permit is included at the end of this section. Section 7-107.B Safe Access Access to the site is consistent with other similar uses. Section 7-107.C Adequate Capacity Traffic congestion is not anticipated as a result of the proposed Watson Ranch B Injection Well. Section 7-107.D Road Dedications The access road is a private road. No rights-of-way will be dedicated to the public. Watson Ranch B Injection Well Ursa Operating Company LLC Access Road Assessment Page 4 Section 7-107.E Impacts Mitigated Based on the expected trip generation rates discussed in the Basic Traffic Study, the increase in average daily traffic is not expected to be significant on roads generally used by the public. The county road will see only a minor increase in traffic as compared to existing traffic volumes. The addition of traffic generated by the proposed site does not increase existing volumes to levels required for State or County permits. The geometry at all intersections where site traffic will be turning is expected to be adequate for site traffic. Conclusions The Ursa Watson Ranch B Injection Well Access Road deviates from the Design Standards in Table 7- 107 for ROW width, shoulder width, ditch width, cross slope, shoulder slope and surface. The road is across private land and currently is not covered by a dedicated access easement or dedicated right-of-way (ROW). The road width varies between 16 feet and 37 feet. The portion of the roadway that is 16 feet in width does not allow for a shoulder width of 2 feet minimum. However, there is sufficient width to allow for two-way traffic in most areas, and in other areas, there is sufficient width to allow for a parked vehicle to wait while a vehicle traveling in the opposing direction passes prior to entering the portion of the roadway that is narrower. Roadside ditches were not constructed and are not shown within the improvement plan for the proposed roadway. The existing roadway allows for storm drainage to sheet flow across the roadway. The proposed roadway design intent appears to drain the road towards the cut slope. A clearly defined ditch section will be recommended during construction. The existing cross slope and shoulder slope varies between 1% and 2.8%. The proposed cross slope is anticipated to be constructed as 3%; however, the improvement plan for the proposed roadway does not include a typical section. The road geometry changes occasionally with maintenance activities. While ponding may occur in areas of shallow cross slope, the road is inspected on a regular basis for maintenance issues, which are addressed in a timely manner. The anticipated road surface of the proposed roadway is gravel; however, the improvement plan does not include a typical section. The road functions adequately as built and is typical of existing roads providing access to natural gas production in Garfield County. Wyatt E. Popp, PE 5600 5595 5590 5565 5580 5575 5570 5565 5560 5555 5550 - Ot-00 50' O' 100' ---..... -.... I ' I Graphic Scale in Feet 1"=100' ...- 1t-OO Drive Profile DI Grade -~ ----- _.. --1101 --ra !le 2t-OO 3t-OO 4t-OO 5t-OO Project: RVS 06001-318 Field Date: 10-02-14 Scale: 1 "= 100' m River Valley Survey, Inc. 110 East 3rd. Slrect, Suite 213 Rifle, Colorado 81650 Ph: 970-379-7846 t--------t-------11 Datl!: 11-07-14 Sheet: 2 of3 -- ~..a 6t-OO 7t-OO 5600 5595 5590 5565 5580 5575 5570 5565 5560 5555 5550 8t-OO ~Ursa 1 OPERAllNG ~ COMPANY Form 2A -Attachment I Watson Ranch B Pad Construction Layout Drawing Section 17, Town1bip 7 South, Range 95 West