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Home My WebLink About1.10 COGCC Form 2A and Supporting DocumentsCPX Piceance Holdings, LLC 34 S. Wynden Drive, Suite 240 Limited Impact Review Garfield County, Colorado Houston, TX 77056 TPR Well Pad 36A Article 9 Oil and Gas Permit Application Appendix K: COGCC Form 2A and Supporting Documents COGCC Form 2A Materials COGCC Rule 304.b.(3) – Cultural Distances Table A table showing the distance and approximate bearing from the edge of the TPR Pad 36A existing Working Pad Surface to the edge of the nearest building, Residential Building Unit, High Occupancy Building Unit, and School Facility is included both in the Cultural Features Map inset table and in the COGCC Form 2A Cultural Distance and Direction Table in this Appendix (Appendix K). COGCC Rule 304.b.(4) – Location Pictures The Pad 36A Location Pictures are included in this Appendix (Appendix K). COGCC Rule 304.b.(5) – Site Equipment List See the Site Equipment List in the COGCC Form 2A included in this Appendix (Appendix K). COGCC Rule 304.b.(6) – Flowline Descriptions See the Flowline Descriptions in the COGCC Form 2A included in this Appendix (Appendix K). COGCC Rule 304.b.(7) – Drawings The Location Drawing, Layout Drawing, Wildlife Habitat Drawing, Hydrology Maps, Access Road Map, Related Location and Flowline Map, and Geologic Hazard Map required under COGCC Rule 304.b.(7) are included in this Appendix (Appendix K). A Disproportionately Impacted Communities Map is not required under Rule 304.b.(7).J, because Pad 36A is not located within 2,000 feet of a Residential Business Unit, High Occupancy Building Unit, or School Facility located within a Disproportionately Impacted Community. COGCC Rule 304.b.(8) – Geographic Information System (“GIS”) Data The GIS data for the existing TPR Pad 36A Oil and Gas Location and Working Pad Surface is included as part of this application. COGCC Rule 304.b.(9) – Land Use Description See the Land Use Description in the COGCC Form 2A included in this Appendix (Appendix K). The Reference Area Map and Reference Area Pictures are also included in this Appendix. COGCC Rule 304.b.(10) – NRCS Map Unit Description A Soil Unit Map and the associated NRCS soil map unit descriptions are included in this Appendix (Appendix K). COGCC Rule 304.b.(11) – Best Management Practices (“BMPs”) For a description of the proposed site-specific BMPs for Pad 36A, see the COGCC Rule 304.c Plans included in this Appendix (Appendix K), the COGCC Form 2B Mitigation Information included in Appendix O, and the Cumulative Impacts Plan also included in this Appendix. COGCC Rule 304.b.(12) – Surface Owner Information See the Surface Owner Information in the COGCC Form 2A included in this Appendix (Appendix K). COGCC Rule 304.b.(13) – Proximate Local Government Information COGCC Rule 304.b.(13) does not apply as there is no Local Government with land use authority within 2,000 feet of the Pad 36A Working Pad Surface. COGCC Rule 304.b.(14) – Wetlands COGCC Rule 304.b.(14) does not apply as there are no proposed impacts to a wetland that would require federal, state, or local permitting for Pad 36A. COGCC Rule 304.b.(15) – Schools and Child Care Centers COGCC Rule 304.b.(15) does not apply as there are no School Facilities, Future School Facilities, or Child Care Centers within 2,000 feet of the existing Pad 36A Oil and Gas Location. COGCC Rule 304.c.(1) – Emergency Spill Response Program COGCC Rule 304.c.(1) does not apply as Pad 36A is not within 2,640 feet of groundwater under the direct influence of a surface water well or Type III Well or surface water that is 15 miles or less upstream from a Public Water System. COGCC Rule 304.c.(2) – Noise Mitigation Plan A Noise Mitigation Plan is not required under COGCC Rule 304.c.(2), but at the request of Garfield County, a Noise Mitigation Plan for Pad 36A is included as Appendix J. COGCC Rule 304.c.(3) – Light Mitigation Plan A Light Mitigation Plan is not required under COGCC Rule 304.c.(3), but at the request of Garfield County, a Light Mitigation Plan for Pad 36A is included as Appendix J. COGCC Rule 304.c.(4) – Odor Mitigation Plan An Odor Mitigation Plan is not required under COGCC Rule 304.c.(4) as there are no Building Units or Designated Outside Activity Areas within 2,000 feet of the Pad 36A Working Pad Surface. COGCC Rule 304.c.(5) – Dust Mitigation Plan A Dust Mitigation Plan for Pad 36A is included in this Appendix (Appendix K). COGCC Rule 304.c.(6) – Transportation Plan The Transportation Plan for Pad 36A is included in this Appendix (Appendix K). COGCC Rule 304.c.(7) – Operations Safety Management Program The Operations Safety Management Program for Pad 36A is included in this Appendix (Appendix K). COGCC Rule 304.c.(8) – Emergency Response Plan CPX’s Emergency Response Plan is included in this Appendix (Appendix K). COGCC Rule 304.c.(9) – Flood Shut-In Plan COGCC Rule 304.c.(9) does not apply as Pad 36A is not located within a Floodplain. COGCC Rule 304.c.(11) – Waste Management Plan The Waste Management Plan for Pad 36A is included in this Appendix (Appendix K). COGCC Rule 304.c.(14) – Topsoil Protection Plan The Topsoil Protection Plan for Pad 36A is included in this Appendix (Appendix K). COGCC Rule 304.c.(15) – Stormwater Management Plan The Stormwater Management Plan for Pad 36A is included in this Appendix (Appendix K). COGCC Rule 304.c.(16) – Interim Reclamation Plan The Interim Reclamation Plan for Pad 36A is included in this Appendix (Appendix K). COGCC Rule 304.c.(17) – Wildlife Plan The Wildlife Plan for Pad 36A is included in this Appendix (Appendix K). COGCC Rule 304.c.(18) – Water Plan The Water Plan for Pad 36A is included in this Appendix (Appendix K). COGCC Rule 304.c.(19) – Cumulative Impacts Plan The Cumulative Impacts Plan for Pad 36A is included in this Appendix (Appendix K). COGCC Rule 304.c.(20) – Community Outreach Plan A Community Outreach Plan is not required under COGCC Rule 304.c.(20) as there are no Residential Building Units, High Occupancy Building Units, or School Facilities located within a Disproportionately Impacted Community and within 2,000 feet of the existing Pad 36A Oil and Gas Location. COGCC Rule 304.c.(21) – Geologic Hazard Plan A Geologic Hazard Plan is not required under COGCC Rule 304.c.(21) as there were no Geologic Hazards identified pursuant to Rule 304.b.(7).I. See the Geologic Hazards Map included in this Appendix (Appendix K). CPX Piceance Holdings, LLC 34 S. Wynden Drive, Suite 240 Limited Impact Review Garfield County, Colorado Houston, TX 77056 TPR Well Pad 36A Article 9 Oil and Gas Permit Application COGCC Form 2A State of Colorado Oil and Gas Conservation Commission 1120 Lincoln Street, Suite 801, Denver, Colorado 80203 Phone: (303) 894-2100 Fax: (303) 894-2109 Oil and Gas Location Assessment FORM 2A Rev 05/22 This Oil and Gas Location Assessment is to be submitted to the COGCC for approval prior to any ground disturbance activity associated with oil and gas operations. Approval of this Oil and Gas Location Assessment will allow for the construction of the below specified Location; however, it does not supersede any land use rules applied by the local land use authority. Please see the COGCC website at https://cogcc.state.co.us/ for all accompanying information pertinent this Oil and Gas Location Assessment. Document Number: 403218159 Date Received: This Location includes a Rule 309.e.(2).E variance request. This Location is within 2,640 feet of a GUDI or Type III Well per Rule 411.b.(4). This Location or its associated new access road, utility, or Pipeline corridor meets Rule 309.e.(2).A, B, or C. CONSULTATION This location is included in a Comprehensive Area Plan (CAP). CAP ID # X X This location includes a Rule 309.f.(1).A.ii. variance request. nick@cpxpiceance.com (713) 554-9031 ( ) Nick Kurtenbach email: Fax: Phone: Contact Information Name: 77056 TX Zip:State:HOUSTON 34 S WYNDEN DR STE 240 CPX PICEANCE HOLDINGS LLC 10639 City: Address: Name: Operator Operator Number: FINANCIAL ASSURANCE FOR THIS LOCATION (check all that apply) Plugging, Abandonment, and Reclamation 20160118 Gas Gathering, Gas Processing, and Underground Gas Storage Facilities Centralized E&P Waste Management Facility X Federal Financial Assurance In checking this box, the Operator certifies that it has provided or will provide at least this amount of Financial Assurance to the federal government for one or more Wells on this Location. Amount of Federal Financial Assurance $ Surface Owner Protection Bond. New Location Refile Amend Existing Location # If this Location assessment is a component of an Oil and Gas Development Plan (OGDP) application, enter the OGDP docket number(s). Docket Number OGDP ID OGDP Name 220300066 482255 TPR Pad 25A OGDP If this Location assessment is part of an approved Oil and Gas Development Plan, enter the OGDP ID number(s). OGDP ID Number OGDP Name 482255 TPR Pad 25A OGDP X 334460 LOCATION IDENTIFICATION Expiration Date: Location ID:334460 OGDP ID: Page 1 of 15Date Run: 12/27/2022 Doc [#403218159] 08/20/20212.5 Date of Measurement:GPS Quality Value: 9355694W 7S 36 Ground Elevation:Meridian:Township:SWNE QuarterQuarter: 36A Number:TPR Well Pad Section: Provide the location description and the latitude and longitude of a single point near the center of the Working Pad Surface as a reference for this Location. Name: Range: Type of GPS Quality Value:PDOP Latitude:39.395017 Longitude:-107.831908 RELEVANT LOCAL GOVERNMENT SITING INFORMATION GARFIELD Municipality: Per § 34-60-106 (1)(f)(I)(A), the following questions pertain to the “Relevant Local Government approval of the siting of the proposed oil and gas location.” N/ACounty: This proposed Oil and Gas Location is in an area designated as one of State interest and subject to the requirements of § 24-65.1-108, C.R.S. No Does the Relevant Local Government regulate the siting of Oil and Gas Locations, with respect to this location?Yes A siting permit application has been submitted to the Relevant Local Government for this proposed Oil and Gas Location:Yes Date Relevant Local Government permit application submitted:12/30/2022 Current status or disposition of the Relevant Local Government permit application for this proposed Oil and Gas Location:In Process Status/disposition date:12/16/2022 If Relevant Local Government permit has been approved or denied, attach final decision document(s). Provide the contact information for the Relevant Local Government point of contact for the local permit associated with this proposed Oil and Gas Location: Sheryl BowerContact Name:Contact Phone:(970) 945-1377 Contact Email:sbower@garfield-county.com PROXIMATE LOCAL GOVERNMENT INFORMATION For every Proximate Local Government (PLG) associated with this proposed Oil and Gas Location, provide the PLG’s point of contact and their contact information. < No row provided > (Enter as many Related Locations as necessary. Enter the Form 2A document # only if there is no established COGCC Location ID#) Well Site is served by Production Facilities 455779 This proposed Oil and Gas Location is:LOCATION ID #FORM 2A DOC # RELATED REMOTE LOCATIONS FEDERAL PERMIT INFORMATION A Federal drilling permit (or related siting application) has been submitted for this proposed Oil and Gas Location: No Date submitted: Current status or disposition of the Federal drilling permit (or related siting application) for this proposed Oil and Gas Location: Not yet submitted Status/disposition Date: If Federal agency permit has been approved or denied, attach the final decision document(s). Provide the contact information of the Federal point of contact for the Federal permit associated with this proposed Oil and Gas Location. Contact Name:Allen Crockett Contact Phone:(970) 274-9780 Contact Email:acrockett@blm.gov Colorado River Valley Field Office, BLMField Office: Page 2 of 15Date Run: 12/27/2022 Doc [#403218159] Additional explanation of local and/or federal process: Concurrent permitting is in process for a Garfield County Article 9 Oil and Gas Permit and a U.S. Bureau of Land Management (BLM) Application for Permit to Drill (APD). Consultation Summaries are attached to the Form 2A application. Both agencies stated that their application process would proceed in parallel with COGCC. Yes 09/15/2021Date of local government consultation: Complete this section for any pre-application consultation related to this proposed Oil and Gas Location that occurred prior to the submission of this Form 2A. If a pre-application Formal Consultation Process occurred, attach a Consultation Summary. RELEVANT LOCAL GOVERNMENT OR FEDERAL PRE-APPLICATION CONSULTATION Did a pre-application Formal Consultation Process occur with the Federal land manager per Rule 301.f.(3)? Did a pre-application Formal Consultation Process occur with the Relevant Local Government per Rule 301.f.(3)?Yes Date of federal consultation:07/19/2022 Was an ALA that satisfies Rule 304.b.(2).C (or substantially equivalent information per Rule 304.e) developed during a federal or local government permit application process? If yes, attach the ALA to the Form 2A. No Complete this section for any pre-application consultation related to this proposed Oil and Gas Location that occurred prior to the submission of this Form 2A. If a pre-application Formal Consultation Process occurred, attach a Consultation Summary. ALA APPLICABILITY AND CRITERIA If YES, indicate by checking the box for every Rule 304.b.(2).B criterion met by this proposed Location, and attach an ALA. See Rule 304.b.(2).B.i-x for full text of criteria. Does the proposed Oil and Gas Location meet any of the criteria listed in Rule 304.b.(2)B?Yes i. WPS < 2,000 feet from RBU/HOBU ii. WPS < 2,000 feet from School/Child Care Center iii. WPS < 1,500 feet from DOAA iv. WPS < 2,000 feet from jurisdictional boundary and PLG objects/requests ALA v. WPS within a Floodplain vi.aa. WPS within a surface water supply area vi.bb. WPS < 2,640 feet from Type III or GUDI well vii. WPS within/immediately upgradient of wetland/riparian corridor viii. WPS within HPH and CPW did not waive ix. Operator using Surface bond X x. WPS < 2,000 feet from RBU/HOBU/School within a DIC X Is the proposed Oil and Gas Location within the exterior boundaries of the Southern Ute Indian Reservation, and the Tribe objects to the Location or requests an ALA? If YES, attach an ALA to the Form 2A. Operator requests the Director waive the ALA requirement per Rule 304.b. (2).A.i: No Provide an explanation for the waiver request, and attach supporting information (if necessary). Page 3 of 15Date Run: 12/27/2022 Doc [#403218159] ALTERNATIVE LOCATIONS DASHBOARD List every alternative location reviewed and included in the ALA. Provide a latitude and longitude for the approximate center of the alternative location, all Rule 304.b.(2).B Criteria met, if a variance would be required to permit the location, and a brief comment on the key points of the alternative location. #latitude longitude i ii iii iv v vi vii viii ix x Variance Required?Comments 39.391355 -107.830500 Alternative 1 introduces new disturbance and haul traffic for construction of the location, access road, and flowlines. It removes mature aspen, Engelmann spruce, and understory vegetation. It fragments undisturbed habitat. It disturbs an estimated 120,000 cy of soil. It has an 80' cut slope and 4,421' of access road construction with 7 to 21% grades. The road would cross the USFS Battlement Trail and multiple HPH buffers. 39.386676 -107.829265 See above. Alternative 2 disturbs an estimated 160,000 cy of soil. It has an 80' cut slope and 5,831' of access road construction with 7 to 22% grades. The road would cross the USFS Battlement Trail and multiple HPH buffers. The location is designated No Surface Occupancy by the USFS. It requires a change to the Roadless Area boundary or designation. 39.393592 -107.824613 See above. Alternative 3 disturbs an estimated 20,000 cy of soil. It has a 15' cut slope. It has 8,513' of access road construction with 6 to 21% grades and a 900' elevation change. The road would cross the USFS Battlement Trail and multiple HPH buffers. The location on a ridgetop at 10,100' increases exposure and effects of winter conditions on equipment and personnel. Additional engines are needed for horsepower to maintain pressure for flowlines in steep terrain. 39.390927 -107.825075 See above. Alternative 4 disturbs an estimated 30,000 cy of soil. It has a 25' cut slope. It has 8,667' of access road construction with 6 to 22% grades and a 960' elevation change. The road would cross the USFS Battlement Trail and multiple HPH buffers. The location on a ridgetop at 10,170' increases exposure and effects of winter conditions on equipment and personnel. Additional engines are needed for horsepower to maintain pressure for flowlines in steep terrain. 304.b.(2).B.i-x Criteria Met: Page 4 of 15Date Run: 12/27/2022 Doc [#403218159] SURFACE & MINERAL OWNERSHIP Name:CPX Piceance Holdings Phone:(713) 554-9031 Fax:34 S. Wynden Dr. Address: Address:Suite 240 Email:nick@cpxpiceance.com City:Houston State:TX Zip:77056 Surface Owner Info: X IndianFederalStateFeeSurface Owner at this Oil and Gas Location: All operations on this Oil & Gas Location will develop the minerals beneath the Location, and the Operator intends to use a surface bond per Rule 703 to secure access to this Location – attach lease map or provide lease description. All operations on this Oil & Gas Location will develop the minerals beneath the Location, and the surface owner owns the minerals beneath this Location and is committed to an oil and gas lease – attach lease map or provide lease description. The Operator has a signed Surface Use Agreement for this Location – attach SUA. The Operator/Applicant is the surface owner. Check only one:X Minerals beneath this Oil and Gas Location will be developed from or produced to this Oil and Gas Location: Mineral Owner beneath this Oil and Gas Location: Surface Owner protection Financial Assurance type:Surety ID Number: Lease description if necessary: X IndianFederalStateFee Yes N/A Wells Indicate the number and type of major equipment components planned for use on this Oil and Gas Location: SITE EQUIPMENT LIST 32 Drilling Pits 0 Pump Jacks 0 Gas or Diesel Motors 1 Dehydrator Units 0 Oil Tanks 0 Production Pits 0 Separators 32 Electric Motors 3 Vapor Recovery Unit 0 Condensate Tanks 2 Special Purpose Pits 0 Injection Pumps 0 Electric Generators 1 VOC Combustor 1 Water Tanks 2 Multi-Well Pits 0 Heater-Treaters 2 Fuel Tanks 0 Flare 0 Buried Produced Water Vaults 0 Modular Large Volume Tank 0 Gas Compressors 0 LACT Unit 1 Enclosed Combustion Devices 1 Pigging Station 0Meter/Sales Building 1 Vapor Recovery Towers 0 OTHER PERMANENT EQUIPMENT Permanent Equipment Type Number Chemical Storage Tanks/Pumps 8 Condensate Transfer Pump 1 Fuel Gas Scrubber 1 Instrument Air Skid 1 High Pressure Knockout Vessel 1 Produced Water Transfer Pump 1 Low Pressure Knockout Vessel 1 OTHER TEMPORARY EQUIPMENT Page 5 of 15Date Run: 12/27/2022 Doc [#403218159] Temporary Equipment Type Number Frac Pumps and Manifold 8 Snubbing Unit 1 Low Pressure Flowback P-Tank 1 Blender 1 Flowback Produced Water Tanks 3 Dust Mitigation Equipment 1 Water Pump 1 Flowback Enclosed Combustion Device 1 Fluid Pumps 2 Sand Silos 3 Frac tanks (500 bbl)6 High Pressure 4-Phase Separator 2 FLOWLINE DESCRIPTION Per Rule 304.b.(6), provide a description of all onsite and off-location oil, gas, and/or water flowlines. Existing buried off-location flowlines between Well Pad 25A and Pad 2 Tanks: 12" steel natural gas flowline; 2" steel condensate flowline; 8" flexsteel bidirectional water flowline. Buried off-location flowlines between Well Pad 25A and Well Pad 36A were reviewed under approved Well Pad 25A OGDP: 12" steel natural gas flowline; 2" steel condensate flowline; 5" flexpipe bidirectional water flowline. Proposed Well Pad 36A on-location flowlines: 2" flowlines from wells to separators; 2" dump lines from separators to water and condensate tanks. Temporary 4" steel surface frac lines on the private CPX road between remote frac support equipment on Well Pad 25A, Temporary Water Support Pad 25B, and Well Pad 36A. GAS GATHERING COMMITMENT Operator commits to connecting to a gathering system by the Commencement of Production Operations? If the answer is NO, a Gas Capture Plan consistent with the requirements of Rule 903.e MUST be attached on the Plans tab. Yes Provide the distance and direction to the nearest cultural feature as measured from the edge of the Working Pad Surface. Building:260 Feet Designated Outside Activity Area:5280 Feet Public Road:5280 Feet Above Ground Utility:5280 Feet Railroad:5280 Feet Property Line:1830 Feet CULTURAL DISTANCE AND DIRECTION Distance NW NE N N N S Direction School Facility:5280 Feet Child Care Center:5280 Feet N N Rule 604.b Conditions Satisfied (check all that apply): 604.b. (1)Details of Condition(s) Disproportionately Impacted (DI) Community: 5280 Feet E 604.b. (2) 604.b. (3) 604.b. (4) Residential Building Unit (RBU):5280 Feet NW High Occupancy Building Unit(HOBU)5280 Feet NE EFeet5280RBU, HOBU, or School Facility within a DI Community. RULE 604.a.(2). EXCEPTION LOCATION REQUEST Page 6 of 15Date Run: 12/27/2022 Doc [#403218159] Operator requests an Exception Location Request from Rule 604.a.(2) [well is less than 150 feet from a property line]. Exception Location Request Letter and Waiver signed by offset Surface Owner(s) must be attached. CULTURAL FEATURE INFORMATION REQUIRED BY RULE 304.b.(3).B. Provide the number of each Cultural feature identified within the following distances, as measured from the Working Pad Surface: Building Units Residential Building Units High Occupancy Building Units School Properties School Facilities Designated Outside Activity Areas 0 0 0 0 0 1 0-500 feet 0 0 0 0 0 0 501-1,000 feet 0 0 0 0 0 0 1,001-2,000 feet Drilling Fluids Disposal: DRILLING WASTE MANAGEMENT PROGRAM OFFSITE Recycle/reuseDrilling Fluids Disposal Method: Cutting Disposal:ONSITE Cuttings trenchCuttings Disposal Method: Other Disposal Description: Beneficial reuse or land application plan submitted?No Reuse Facility ID:or Document Number: Centralized E&P Waste Management Facility ID, if applicable: Will a closed-loop drilling system be used? Is H2S gas reasonably expected to be encountered during drilling operations at concentrations greater than Will salt based (>15,000 ppm Cl) drilling fluids be used? Will salt sections be encountered during drilling: Estimated post-construction ground elevation: Size of location after interim reclamation in acres: 5.45Size of disturbed area during construction in acres: CONSTRUCTION 1.34 DRILLING PROGRAM Yes No Will oil based drilling fluids be used?No 9355 or equal to 100 ppm?If YES, attach H2S Drilling Operations Plan.No No CURRENT LAND USE Other Residential RecreationForestry CommercialIndustrial Rangeland Conservation Reserve Program (CRP)Non-IrrigatedIrrigated Subdivided: Non-Crop Land: Crop Land: Current Land Use: check all that apply per Rule 304.b.(9). XXX Describe the current land use: CPX Piceance privately owns Tepee Park Ranch (TPR) and the Oil and Gas Location. TPR is operated by CPX predominantly for the exploration and production of natural gas. Page 7 of 15Date Run: 12/27/2022 Doc [#403218159] Describe the Relevant Local Government’s land use or zoning designation: The zoning designation is Rural. Oil and gas drilling and production is a use by right in areas zoned Rural by Garfield County. Describe any applicable Federal land use designation: Other Residential RecreationForestry CommercialIndustrial Rangeland Conservation Reserve Program (CRP)Non-IrrigatedIrrigated Subdivided: Non-Crop Land: Crop Land: Final Land Use: check all that apply per Rule 304.b.(9). XXX FINAL LAND USE Reference Area Latitude: If Final Land Use includes Non-Crop Land (as checked above), the following information is required: Describe landowner’s designated final land use(s): REFERENCE AREA INFORMATION TPR is operated predominantly for the exploration and production of natural gas. 39.393621 -107.832556Reference Area Latitude: Provide a list of plant communities and dominant vegetation found in the Reference Area. Plant Community Dominant vegetation Forest Land Stinging Nettle Forest Land Fireweed Forest Land California Valerian Forest Land Gooseberry Currant Forest Land Tall Ragwort Forest Land Blue Wildrye Forest Land Slender Wheatgrass Forest Land Common Yarrow Forest Land Kentucky Bluegrass Forest Land Smooth Brome Forest Land Silvery Lupine Forest Land Fishlake Thistle Noxious weeds present:No SOILS List all soil map units that occur within the maximum extent of the proposed Oil and Gas Location. Attach the National Resource Conservation Service (NRCS) report showing the "Map Unit Description" listing the typical vertical soil profile(s). This data is to be used when segregating topsoil. The required information can be obtained from the NRCS website at https://www.nrcs.usda.gov/wps/portal/nrcs/surveylist/soils/survey/state/ or from the COGCC website GIS Online map page. Instructions are provided within the COGCC website help section. NRCS Map Unit Name:104A: Haplocryolls-Cryaquolls complex 0 to 15 percent slopes NRCS Map Unit Name:331C: Woodrock-Angostura families complex, 40 to 65 percent slopes NRCS Map Unit Name: Page 8 of 15Date Run: 12/27/2022 Doc [#403218159] GROUNDWATER AND WATER WELL INFORMATION Provide the distance and direction, as measured from the Working Pad Surface, to the nearest: water well:320 Feet W Spring or Seep:5280 Feet NE Estimated depth to shallowest groundwater that can be encountered at this Oil and Gas Location:Feet Basis for estimated depth to and description of shallowest groundwater occurrence: Drill Report for Well 132-36 (Facility ID 05-045-16949) 60 SURFACE WATER AND WETLANDS Provide the distance and direction to the nearest downgradient surface Waters of the State, as defined in the 100-Series Rules, measured from the Working Pad Surface: Land surveyed perennial stream Feet W130 If less than 2,640 feet, is the Waters of the State identified above within 15 stream miles upstream of a Public Water System intake?No Provide the distance and direction to the nearest downgradient wetland, measured from the Working Provide a description of the nearest downgradient surface Waters of the State: If the proposed Oil and Gas Location is within a Rule 411.a Surface Water Supply Area buffer zone, select the buffer If the proposed Oil and Gas Location is within a Rule 411.b GUDI/Type III buffer zone, select the buffer Is a U.S. Army Corps of Engineers Section 404 permit required for the proposed Oil and Gas Location, access road, or If a U.S. Army Corps of Engineers Section 404 permit is required, provide the permit status, and permit number if available: zone type: associated pipeline corridor?No Pad Surface:NWFeet190 zone type: Public Water System Administrator - Contact Name Email Public Water System Administrator - Contact Name Email Is the Location within a Floodplain?No Floodplain Data Sources Reviewed (check all that apply): Federal (FEMA)X State X County Local Does this proposed Oil and Gas Location lie within a Sensitive Area for water resources, as defined in the Yes Other 100-Series Rules? CONSULTATION, WAIVERS, AND EXCEPTIONS This Oil and Gas Location or associated new access road, utility, or pipeline corridor falls within federally designated critical habitat or an area with a known occurrence for a federal or Colorado threatened or endangered species. Provide description in Comments section of Submit tab. When Rule 309.e.(2) Consultation must occur, check all that apply: This location is included in a Wildlife Mitigation Plan Page 9 of 15Date Run: 12/27/2022 Doc [#403218159] This Oil and Gas Location or associated new access road, utility, or pipeline corridor falls within an existing conservation easement established wholly or partly for wildlife habitat. Provide description in Comments section of Submit tab. When Rule 309.e.(3) Consultation is not required, check all that apply: This Oil and Gas Location has been included in a previously approved, applicable Wildlife Protection Plan. This Oil and Gas Location has been included in a previously approved, applicable Wildlife Mitigation Plan. This Oil and Gas Location has been included in a previously approved, applicable conservation plan. Pre-application Consultation: X A pre-application consultation with CPW, regarding this Oil and Gas Location, occurred on: 05/27/2021 CPW Waivers and Exceptions (check all that apply and attach all CPW waivers to this Form 2A): The applicant has obtained a Rule 304.b.(2).B.viii CPW waiver for the requirement to complete an ALA. The applicant has obtained a Rule 309.e.(2).G CPW waiver and consultation is not required. X The applicant has obtained a Rule 309.e.(5).D.i CPW waiver and is requesting an exception from Rule 1202.c. (1).R. The applicant has obtained a Rule 309.e.(5).D.ii CPW waiver and is requesting an exception from Rule 1202.c. (1).S. The applicant has obtained a Rule 309.e.(5).D.iii CPW waiver of Rule 1202.c.(1).T. The applicant has obtained a Rule 309.e.(5).D.iv CPW waiver and is requesting an exception from Rule 1202.c.(1) in accordance with an approved CAP. X The applicant has obtained a Rule 1202.a CPW waiver. The applicant has obtained a Rule 1202.b CPW waiver. In accordance with Rule 1203.a.(3), the applicant requests an exception from compensatory mitigation Rule(s): HIGH PRIORITY HABITAT AND COMPENSATORY MITIGATION This Oil and Gas Location, associated access roads, utility, or Pipeline corridor falls wholly or partially within the following High Priority Habitats (Note: dropdown options are abbreviated - see Rule 1202 for full rule text): High Priority Habitat (list all that apply) Oil and Gas Location Access Road Utility or Pipeline Corridor 1202.c.(1).R - Cutthroat trout habitat and others x x x The following questions are for Oil and Gas Locations that cause the density to exceed one Oil and Gas Location per square mile in Rule 1202.d High Priority Habitat: Direct Impacts: Is Compensatory Mitigation required per Rule 1203.a for this Oil and Gas Location? Is a Compensatory Mitigation Plan proposed to address direct impacts for this Oil and Gas Location? Have all Compensatory Mitigation Plans been approved for this Location? If not, what is the current status of each Plan? Compensatory Mitigation is not required for this location. Is a Compensatory Mitigation Fee proposed for this Oil and Gas Location? Direct impact habitat mitigation fee amount: $ No No No No Page 10 of 15Date Run: 12/27/2022 Doc [#403218159] No BMP Operator Proposed Wildlife BMPs Indirect Impacts: Is a Compensatory Mitigation Plan proposed to address indirect impacts for this Oil and Gas Location? Have all Compensatory Mitigation Plans been approved for this Location? If not, what is the current status of each Plan? Compensatory Mitigation is not required for this location. Is a Compensatory Mitigation Fee proposed for this Oil and Gas Location? Indirect impact habitat mitigation fee amount: $ No No No No Is Compensatory Mitigation required per Rule 1203.d for this Oil and Gas Location? AIR QUALITY MONITORING PROGRAM Will the Operator install and administer an air quality monitoring program at this Location?Yes No BMP Operator Proposed BMPs PLANS Total Plans Uploaded: 12 (1) Emergency Spill Response Program consistent with the requirements of Rules 411.a.(4).B, 411.b.(5).B, & 602.j (2) Noise Mitigation Plan consistent with the requirements of Rule 423.a (3) Light Mitigation Plan consistent with the requirements of Rule 424.a (4) Odor Mitigation Plan consistent with the requirements of Rule 426.a (5) Dust Mitigation Plan consistent with the requirements of Rule 427.aX X (6) Transportation Plan X (7) Operations Safety Management Program consistent with the requirements of Rule 602.d X (8) Emergency Response Plan consistent with the requirements of Rule 602.j (9) Flood Shut-In Plan consistent with the requirements of Rule 421.b.(1) (10) Hydrogen Sulfide Drilling Operations Plan consistent with the requirements of Rule 612.d (11) Waste Management Plan consistent with the requirements of Rule 905.a.(4)X (12) Gas Capture Plan consistent with the requirements of Rule 903.e (13) Fluid Leak Detection PlanX (14) Topsoil Protection Plan consistent with the requirements of Rule 1002.cX (15) Stormwater Management Plan consistent with the requirements of Rule 1002.fX X (16) Interim Reclamation Plan consistent with the requirements of Rule 1003 X Page 11 of 15Date Run: 12/27/2022 Doc [#403218159] (17) Wildlife Plan consistent with the requirements of Rule 1201 X (18) Water Plan X (19) Cumulative Impacts Plan (20) Community Outreach Plan (21) Geologic Hazard Plan VARIANCE REQUESTS Check all that apply: This proposed Oil and Gas Location requires the approval of a Rule 502.a variance from COGCC Rule or CommissionX Order number:220300066 ALL exceptions and variances require attached Request Letter(s). Refer to applicable rule for additional required attachments (e.g. waivers, certifications, SUAs). RULE 304.d LESSER IMPACT AREA EXEMPTION REQUESTS Check the boxes below for all Exemptions being requested. Lesser Impact Area Exemption Request must be attached, and will include all requested exemptions. 304.b.(1). Local Government Siting Information 304.b.(2). Alternative Location Analysis 304.b.(3). Cultural Distances 304.b.(4). Location Pictures 304.b.(5). Site Equipment List 304.b.(6). Flowline Descriptions 304.b.(7). Drawings 304.b.(8). Geographic Information System (GIS) Data 304.b.(9). Land Use Description 304.b.(10). NRCS Map Unit Description 304.b.(11). Best Management Practices 304.b.(12). Surface Owner Information 304.b.(13). Proximate Local Government 304.b.(14). Wetlands 304.b.(15). Schools and Child Care Centers 304.c.(1). Emergency Spill Response Program X 304.c.(2). Noise Mitigation Plan 304.c.(3). Light Mitigation Plan X 304.c.(4). Odor Mitigation Plan 304.c.(5). Dust Mitigation Plan 304.c.(6). Transportation Plan 304.c.(7). Operations Safety Management Program 304.c.(8). Emergency Response Plan 304.c.(9). Flood Shut-In Plan 304.c.(10). Hydrogen Sulfide Drilling Operations Plan 304.c.(11). Waste Management Plan 304.c.(12). Gas Capture Plan 304.c.(13). Fluid Leak Detection Plan 304.c.(14). Topsoil Protection Plan 304.c.(15). Stormwater Management Plan 304.c.(16). Interim Reclamation Plan 304.c.(17). Wildlife Plan 304.c.(18). Water Plan 304.c.(19). Cumulative Impacts Plan 304.c.(20). Community Outreach Plan 304.c.(21). Geologic Hazard Plan Comments OPERATOR COMMENTS AND SUBMITTAL Page 12 of 15Date Run: 12/27/2022 Doc [#403218159] nick@cpxpiceance.com Principal Nick Kurtenbach COGCC Approved:Director of COGCC Date: Based on the information provided herein, this Oil and Gas Location Assessment complies with COGCC Rules, applicable orders, and SB 19-181 and is hereby approved. Title: Email:Date: Print Name: Signed: I hereby certify that the statements made in this form are, to the best of my knowledge, true, correct and complete. CPX Piceance Holdings (CPX) proposes the continued development of existing Well Pad 36A on Tepee Park Ranch (TPR). The application is submitted as an amendment to approved OGDP ID 482255. TPR is privately owned and operated by CPX, predominantly for the exploration and production of natural gas. Well Pad 36A has one well that was spud but not completed (DG). It has two permitted wells with expired permits (EP). CPX proposes to use the location to develop 32 new natural gas wells and to plug and abandon the spud but not completed well (Well 132-36; Facility ID 05-045-16949). CPX proposes to use Well Pad 36A as a remote frac location to support completions operations for new natural gas wells authorized on TPR Well Pad 25A (Location ID 334457). Additionally: 1. Well Pad 36A has been established and stable since 2008. 2. The well pad represents centralized, continued use of an existing location and access without creating new soil disturbance and habitat fragmentation from relocating the well pad. 3. The well pad surfaces and berms are hardened and stable to avoid erosion. The berms are 2' high and compacted to 95% soil/moisture density. They are vegetated with 80% cover on the outside slopes. 4. There is no uncontrolled stormwater on the well pad. An engineered 6" drain on the well pad flows to a lined perimeter trench. The trench flows to a lined stormwater catchment basin. 5. During well drilling and completions, operators will be on location 24/7 to inspect and monitor the location and flowlines. 6. During production, tanks and flowlines will be continuously monitored using a SCADA platform for remote monitoring, alerting, and shut-in capabilities. 7. Lined steel secondary containment will be sized to contain 150% of the largest tank for spill prevention. 8. Takeaway capacity for natural gas, condensate, and produced water will use buried flowlines to avoid truck trips on and off of the location. 9. After viewing the location, engineered controls, and BMPs, Colorado Parks & Wildlife provided a written waiver and a recommendation for a variance for the well pad's proximity to Rule 1202.c.(1).R HPH on June 18, 2021. CPW renewed the waiver and recommendation for a variance on July 13, 2022. Existing CPX Well Pad 25A was approved by COGCC on 9/21/22. It is proposed to be used as a remote frac support pad for SIMOPs operation on Well Pad 36A. Alternatively, the same frac support equipment would be located on Well Pad 36A under non-SIMOPs completions. Likewise, Well Pad 36A is proposed to be used as a remote frac support pad for SIMOPs operation on Well Pad 25A. Frac support equipment is shown on the Well Pad 36A Layout Drawings. Temporary Water Support Pad 25B was approved by COGCC on 9/21/22. It is proposed to be used to store recycled produced water and water from well completions for use in subsequent well completions. Use of Pad 25B is shown on the Well Pad 36A Layout Drawings and Process Flow Diagrams. Together, Pads 25A, 25B, and 36A centralize CPX facilities, reuse existing disturbances, and enable CPX to source 97% of the water that is needed for completions from recycled water. No BMP/COA Type Description Best Management Practices COA Type Description 0 COA Conditions Of Approval All representations, stipulations and conditions of approval stated in this Form 2A for this location shall constitute representations, stipulations and conditions of approval for any and all subsequent operations on the location unless this Form 2A is modified by Sundry Notice, Form 4 or an Amended Form 2A. Page 13 of 15Date Run: 12/27/2022 Doc [#403218159] User Group Comment Comment Date Stamp Upon Approval Total: 0 comment(s) General Comments Attachment List Att Doc Num Name 403260159 LOCATION DRAWING 403260160 CULTURAL FEATURES MAP 403260161 WILDLIFE HABITAT DRAWING 403260162 HYDROLOGY MAP 403260163 ACCESS ROAD MAP 403260164 GEOLOGIC HAZARD MAP 403260165 RELATED LOCATION AND FLOWLINE MAP 403260166 REFERENCE AREA MAP 403260167 NRCS MAP UNIT DESC 403260170 ALA NARRATIVE SUMMARY 403260171 CPW CONSULTATION 403260172 CONSULTATION SUMMARY 403260173 LGD CONSULTATION 403260174 CORRESPONDENCE 403260175 CPW WAIVER 403260176 CPW WAIVER 403260177 CPW WAIVER 403260178 DIRECTIONAL WELL PLAT 403260179 EXCEPTION REQUEST LETTER 403260180 LOCATION AND WORKING PAD GIS SHP 403260181 LAYOUT DRAWING 403260182 LESSER IMPACT AREA EXEMPTION REQUEST 403260183 LOCATION PICTURES 403260184 NRCS MAP UNIT DESC 403260185 PRELIMINARY PROCESS FLOW DIAGRAMS 403260186 REFERENCE AREA PICTURES 403260187 SENSITIVE AREA DATA Total Attach: 27 Files Page 14 of 15Date Run: 12/27/2022 Doc [#403218159] Public Comments No public comments were received on this application during the comment period. Date Run: 12/27/2022 Doc [#403218159] Page 15 of 15 Public Comments No public comments were received on this application during the comment period. Page 15 of 15Date Run: 12/27/2022 Doc [#403218159] CPX Piceance Holdings, LLC 34 S. Wynden Drive, Suite 240 Limited Impact Review Garfield County, Colorado Houston, TX 77056 TPR Well Pad 36A Article 9 Oil and Gas Permit Application Cultural Features Map Existing Well Pad 25A White River National Forest CPX PICEANCE HOLDINGS LLC CPX PICEANCE HOLDINGS LLC Existing Well Pad 36A 1,000' from Working Pad Surface 500' from Working Pad Surface Property Boundary 1,830' S 2,000' from Working Pad Surface White River National Forest Section 25 Section 36 Section 31 Section 6 Section 7 Section 1 Section 12 T7S R94W T8S R94W T7S R94WT8S R93WT8S R93W T7S R93W Legend Oil & Gas Wells Drilled and Producing Drilled Drilled/Uncompleted "DUC" Well Permitted Building Working Pad Surface Oil and Gas Location 500' from Working Pad Surface 1,000' from Working Pad Surface 2,000' from Working Pad Surface Private Access Road Forest Service Jurisdiction Parcels Property Boundary Figure 2 CPX Piceance Holdings, LLC Tepee Park Ranch Well Pad 36A Aota Technical, LLC Figure No. Cultural Features Map 10/18/22 Date Data Source: COGCC GIS Online Garfield County SW1/4NE1/4 Sec. 36, T7S R94W, 6th P.M. 0 250 500 750 1,000 Feet 1Building Unit is an unimproved cabin owned by CPX and used for storage. 1,001- 2,000' Building Units 1; Residential Building Units; High Occupancy Building Units; School Properties; School 1 0 0 Cultural Features within 2,000' of Working Pad Surface 0-500'501-1,000' Building Unit1 260' NW Residential Building Unit 5,280'+ NW High Occupancy Building Unit 5,280'+ NE School Facility 5,280'+ N Designated Outside Activity Area 5,280'+ NE Disproportionately Impacted Community 5,280'+ E Public Road 5,280'+ N Above-ground Utility 5,280'+ N Railroad 5,280'+ N Property Line 1,830' S Cultural Features - Distance/Bearing from Working Pad Surface 1 CPX Piceance Holdings, LLC 34 S. Wynden Drive, Suite 240 Limited Impact Review Garfield County, Colorado Houston, TX 77056 TPR Well Pad 36A Article 9 Oil and Gas Permit Application Location Pictures COGCC Rule 304.b.(4) Center of Pad Looking North Center of Pad Looking East Center of Pad Looking West Center of Pad Looking South Operator: CPX Piceance Holdings, LLC Location: TPR Well Pad 36A Photo: 11/04/21 1:20p (North, South, West) Photo: 08/11/22 4:45p (East) Garfield County SW ¼ NE ¼ Sec. 36, T7S R94W 6th P.M. Location Pictures Field of View T7S R94W Section 36 North East South West Legend Location of Picture Field of View Working Pad Surface Oil and Gas Location CPX Piceance Holdings, LLC Tepee Park Ranch Well Pad 36A Aota Technical, LLC Location Pictures Aerial 10/7/22 Date Garfield County SW1/4NE1/4 Sec. 36, T7S R94W, 6th P.M. 0 25 50 75 100 Feet CPX Piceance Holdings, LLC 34 S. Wynden Drive, Suite 240 Limited Impact Review Garfield County, Colorado Houston, TX 77056 TPR Well Pad 36A Article 9 Oil and Gas Permit Application Drawings COGCC Rule 304.b.(7) CPX Piceance Holdings, LLC 34 S. Wynden Drive, Suite 240 Limited Impact Review Garfield County, Colorado Houston, TX 77056 TPR Well Pad 36A Article 9 Oil and Gas Permit Application Location Drawing Existing Well Pad 25A White River National Forest 2,000' from Working Pad Surface CPX Water Well No. 321677 CPX PICEANCE HOLDINGS LLC CPX PICEANCE HOLDINGS LLC Existing Well Pad 36A See Inset BattlementTrail CPX PICEANCE HOLDINGS LLC White River National Forest T7S R94WT8S R93WT7S R94WT7S R93WT8S R93W T7S R93W Section 25 Section 36 Section 31 Section 6 Legend Oil & Gas Wells Drilled and Producing Spud/Uncompleted Drilled/Uncompleted "DUC" Expired Permit Water Well Building Working Pad Surface Oil and Gas Location 2,000' from Working Pad Surface Private Road Trail Forest Service Jurisdiction Parcels Property Line Figure 1 CPX Piceance Holdings, LLC Tepee Park Ranch Well Pad 36A Aota Technical, LLC Figure No. Location Drawing 10/18/22 Date Data Sources: COGCC GIS Online COTREX Garfield County SW1/4NE1/4 Sec. 36, T7S R94W, 6th P.M. 132-36 TPR 112-6 TPR 143-36 TPR Well Pad 36A Inset 0 125 250 375 500 Feet Garfield County Mesa County Project Location RifleRifle 13 6 70 Improvements within 2,000' of Working Pad Surface Battlement Trail CPX Water Well No. 321677 390' E 320' W 1Building Unit is an unimproved cabin owned by CPX and used for storage.1 CPX Piceance Holdings, LLC 34 S. Wynden Drive, Suite 240 Limited Impact Review Garfield County, Colorado Houston, TX 77056 TPR Well Pad 36A Article 9 Oil and Gas Permit Application Layout Drawings Bmp-sucg g¢ Ped\ge AvaleL0z Xd OH ZZOZISL/LL Section 36 T. 78S. R. 94W. Garfield County Proposed Sediment g Trap with 6" Outlet Pipe oO to Lower Drainage Ditch a. Maintain Existing Bs Diversion Ditchs —a Exist. Oil & a. Gas Location Se & ar v v Jp — ~ ° oy — K : - aa Se ae a: —~- rn la Exist. Topsoil Area 3 =~ fi: = 425'x56', 10.5' max depth 9350 (£2,330 cy) Existing v Diversion Ditch Exist. Oil and Gas Location | ™ Proposed Lined | \ \ = GRAPHIC SCALE IN FEET 1 INCH = 60 FEET Contour Interval = 2 ft. Exist. Topsoil Area 2 \ | £142'x83', 6.3' max depth ~, / ie Sediment Trap < 2 oo : v—... a Exist. Lined | a —_ . —— a Sh is (+950 cy) a \ \ Proposed Diversion Ditch iy —-_ — SS “\ — ao | Sediment Trap i ’ | Edge of Working 2’ Earthen Berm | \ y) Pad. Surface L / ( Existing A / : > < Drain Pipe 9 oo > : ~ a : oN Aj 2 093 ee ger / Toy ES bs feast Tha 3 9 an S = 3 ago XtO 9 320 9 / / s | ° 9 £ (eer ’ / Proposed Lined PN. 2 3.54 J / Diversion Ditch = . Lf po=3 Exist. Pad Elev.: +9355 3 Sf / | 7 CS ays > : ° w i NAz. 27.10 FSPESPFSPPEPTHESP BS 8 _— Df \ 113’ 105' f 15'© 15" 117’ 4 a \Y EXISTING WELL DATA: : } \ 5 a AZ WELL NORTHING EASTING | \ 3 8 —s yo a i TPR 132-36 1577222.4 2341062.9 9379 > ral = NS ee CNDCTR #2 1577208.4 2341055.8 : \ a g Exist, ficcess Rdad se CNDCTR#3 1577195.4 2341049.1 e 8 _~ _L Jol S : Drive Over | Berm mn SEY : : J a ele °| = EEE Edge of Working 9380 | —a A ee ee ‘ ; \ ‘ a — Pad Surface \ : DISTURBANCE AREAS Z aN Oil and Gas Location 5.45 ac . . aa Working Pad Surface: +2.06 ac ,—... —» Proposed, Cuttings Pit... . “ : ae ‘ Access Road :+0.0 ac 19' Depth (8,320 bbl) ~ Y ~\ Maintain Existing — Sediment Trap 9390 a - 9360 *Notes dl a2 9370 1) Excavation of Cuttings Trench is the Only Nz Construction Anticipated at this Location. ue on 9380 2) Pit Interior Slope: 1:1 N 9390 3) 20% Swell Factor Applied to Earthwork Cut Volume. £ Pp K 4 fe) 9400 a oa'0 ESTIMATED EARTHWORK QUANTITIES (cy) _ ITEM CUT FILL | TOPSOIL | EXCESS 9420 ——— 9430 PAD 0 0 0 0 a - SS SS TRENCH) 9,990 | 210 9,780 Exist. Oil and Gas Location 9430 TOTALS] 9,990 210 0 9,780 9440 . A REVISED: 11/15/22 Construction Plan Prepared for: 3 yo 136 East Third Street Rifle, Colorado 81650 Ph. (970) 625-1330 Fax (970) 625-2773 DATE: 2/28/21 big BOOK | [FF PROJECT: CPX “i SCALE: 1" = 60’ CPX Piceance Holdings, LLC TPR Well Pad 36A CONSTRUCTION LAYOUT DRA WING PLAN VIEW Survey Services, Inc. iii cs 11/15/2022 K:\CPX 2018\PAD 36\Pad 36 Constr.dwg Oil and Gas Location 5.45 ac19' Depth (8,320 bbl) Bmp'ysuod 9E PEd\SE GWA\8L0Z XdO\:4 Section 36 L 7S, R. 94 W. Garfield County 9380 9360 9340 9320 Exist. Oil & Gas Location NY 9420 ¢ Construction 9400 / / / 9380 / / ah / Exist. Working 2' High Berm / Pad Surface 9360 see ag _/ [ft 100" a Z / 7 / 19' Depth 9340 _ =v, 4 Proposed \ Cuttings Trench Exist. Oil & Gas Location 9320) 100 200 300 400 Section A | 9380 Exist. Oil & Gas Location Exist. Working _ i - \ Pad Surface 120' \ 9360 \ 114' Cellar 121' SS oe ae ae Orme —<=ern— —_: eee asaaaoteeaaeee | ee | Saree 9340 | 9320, 100 200 300 Section B ‘a Exist. Oil & Gas Location \ \ Exist. Oil & Gas Location 9380 \ > = \ / \ / A F a a | —i— J. 19! Depth Proposed Exist. Sediment Trap | Cuttings Trench 9340 0 100 200 300 400 9320 Section C _ “ oe Rifle, Colorado 81650 DATE: Fax (970) 625.2773 PROJECT: 9420 9400 9380 9360 9340 9320 9380 Excess Soil Stockpile 9360 Exist. Oil & Gas Location Yo 9340 SN ie 500 600 9320 SCALE: Horiz.: 1" = 60' Vert. : 1" = 30° “NOTE: CUT SLOPES: 1.5:1 FILL SLOPES: 1.5:1, UNLESS OTHERWISE NOTED. REVISED: 9/13/22 Construction Plan Prepared for: ‘\ > Survey Services, Inc. Fag / a . . As Noted cea CPX Piceance Holdings, LLC 10/14/21 wee CPX TeePee Park Ranch Pad 36A cs CONSTRUCTION LAYOUT CROSS SECTIONS’ K:\CPX 2018\PAD 36\Pad 36 Constr.dwg 212215 1820 19Suction Tank &MOC SkidBoilerProcess SkidMixing SkidMud P umpSk id s Proposed LinedDiversion DitchProposedSediment TrapDrive OverBermExist. Oil and Gas LocationProposed Cuttings Pit19' depth (±8,320 cy) 21433213241311125126897Skidding RailSkidding RailPDS3D Catwalk DRILLINGFLOORUtilitty ShedVFD HOUSEDiesel Tank Proposed LinedDiversion DitchExist. Oil andGas LocationSee Drilling Cellar Detailfor Well DesignationsProposed SedimentTrap with 6" Outlet Pipeto Lower Drainage DitchCuttings ManagementAreaExcess Soil Stockpile(±9,780 cy)Shale ShakerDragon FireGen. House 14 1716 12345678910111213141516ABDATE:DRAWN BY:DESIGNED BY:PROJECT:FEET1 INCH =0GRAPHIC SCALE IN FEET8080Contour Interval = 2'11/29/22CPXJASTPP- LEGEND -1. WASTE WATER ABOVEGROUND TANK (1500 gal)2. POTABLE WATER ABOVEGROUND TANK (3360 gal)3. PORTABLE TOILETS4. WILDLIFE - PROOF DUMPSTER5. COMPANY MAN HOUSING6. DIRECTIONAL HOUSE7. MUD ENGINEERING - SOLIDS8. TOOL PUSHER SHED9. CHANGE HOUSE10. UTILITY SHED (NOT USED ON THIS SITE)11. AIR HANDLER12. OFFICE13. FLARE STACK14. MUD STORAGE TANKS (6)15. DeWATER TANK16. CEMENT WATER TANKS (2)17. CEMENT TANKS (2)18. BAR TANK19. GELL TANK20. PREMIX TANK21. DRYING SHAKERS22. CUTTINGS TANK23. SEPARATORS (2 - 10'x8')24. AIR FUELSW1/4SE1/4 Section 36T. 7 S., R. 94 W.Garfield CountyExisting Oil & Gas LocationEdge of WorkingPad SurfaceTemporary Pad BermPROPOSED WORKING PAD SURFACETEMPORARY PAD BERMEXISTING OIL & GAS LOCATIONDRIVE OVER BERM ^^^^^^^^^^^^^^^^^^^^^^^^ ^^^^^^^^^^^^^^^^^^^^^^^^^^^^ ^^^^ ^ ^^^^^ ^ ^^^DATE: DRAWN BY: DESIGNED BY: PROJECT: FEET1 INCH = 0 GRAPHIC SCALE IN FEET 80 80 Contour Interval = 2' 5/02/22 CPX JAS TPPExist. TPR 132-36Exist. Conductor #1Edge of Working Pad Surface Existing Sediment Trap - LEGEND - PRODUCTION GAS WELL EXISTING CONDUCTOR DRIVE OVER BERM EXISTING WORKING PAD SURFACE PROPOSED PERIMETER BERM PROPOSED TANK MANIFOLD PROPOSED TRANSFER HOSE FRAC WATER SUPPLY (2-4.5 STEEL) PROPOSED FRAC LINES (2-4.5" STEEL) EXISTING OIL & GAS LOCATION EXISTING ACCESS ROAD EXISTING TOE TRENCH FRAC EQUIPMENT BLENDER FRAC PUMP FRAC PUMP MANIFOLD FRAC TANK (500bbl) SAND SILOExist. Conductor #2EXISTING ACCESS ROAD Edge of Working Pad SurfaceProposed Perimeter Berm Proposed Perimeter Berm Edge of Working Pad Surface SW1/4NE1/4 Section 36 T. 7 S., R. 94 W. Garfield County Notes: 1. Drawing shows the proposed SIMOPs layout on existing Well Pad 36A. Well Pad 36A will be reviewed under a separate Oil and Gas Development Plan. Using the same configuration, equipment would be located on existing Well Pad 25A under non-SIMOPs operation. 2. Exhibit depicts the preliminary frac equipment layout on Pad 36 (COGCC Loc ID: 334460) supporting remote well completion operations for the proposed wells on Pad 25A. 3. Six (6) total tanks. Total Capacity 3,000bbls. Working Capacity 2,500bbls. 4. Two-and one-half foot (2.5') high perimeter berm with a total site capacity of 55,400bbls. Perimeter berm capacity does not account for equipment displacement. 5. Equipment used during well completion operations may vary depending on availability at the time of operations. 6. Equipment location may vary depending on site conditions and availability of space on the site during well completions operations. FRAC WATER SUPPLY (2-4.5" STEEL) PROPOSED FRAC LINES (2-4.5" STEEL) Existing Sediment Trap Existing Toe Trench Existing Toe Trench Existing Toe Trench on Existing Well Pad 36A Exist. Access Road123456789 10 11 12 13 14 15 16 17 18 ^^^^^^^^^^^^^^^^^^^^F 9.9'F 6.5'F 14.7'F 10.1'F 13.2'F 14.8' Exist. A c c e s s R o a d 7+008+009+0090'70'C 21.7' C 18.2' C 17.3' C 18.4'915091609170914091809 1 3 0 91409150916091709180 9090909091009110910091109120910091009110912091309140 90909090DATE:DRAWN BY:DESIGNED BY:PROJECT:FEET1 INCH =0GRAPHIC SCALE IN FEET6060Contour Interval = 2'11/03/22CPXJASTPP- LEGEND -EXIST.SED TRAPEXIST.SED TRAPSW1/4SE1/4 Section 36T.7S, R 94 W.Garfield CountyPROPOSEDSED TRAPProposed Cuttings Trench19' Depth (±7,390 bbl)PROPOSEDDIVERSION DITCHPROPOSEDSED TRAPEXIST. DIVERSIONDITCHPROPOSED DIVERSIONDITCHExist. TPR 132-36 Exist. Conductor #1 Exist. Conductor #2 PRODUCTION GAS WELLEXISTING CONDUCTORDRIVE OVER BERMEXISTING WORKING PAD SURFACEPERIMETER BERMPROPOSED TANK MANIFOLDPROPOSED TRANSFER HOSEFRAC WATER SUPPLY (2-4.5 STEEL)PROPOSED FRAC LINES (2-4.5" STEEL)EXISTING OIL & GAS LOCATIONEXISTING ACCESS ROADEXISTING TOE TRENCHFRAC EQUIPMENTBLENDERFRAC PUMPFRAC PUMP MANIFOLDFRAC TANK (500bbl)SAND SILOSEE NOTE 6TANK BATTERY CONDENSATETRANSFERPUMPPIGLAUNCHERTANK VAPORSCOMBUSTORLIQUIDSKNOCK-OUTSALT WATERDISPOSAL EQUIPMENT:CHARGE PUMPSFILTERSINJECTION PUMPSSEPARATION EQUIPMENT:9 QUAD SEPARATORSFUEL GASSKIDINSTRUMENTAIRCOMPRESSORUTILITIES / CONTROLS:POWER GENERATIONPLC SITE CONTROLLERREMOTE TELEMETRYUNIT / RADIOBLOWDOWNCOMBUSTORHEATER TREATERSECONDARYCONTAINMENT:METALLIC WALLIMPERMEABLE LINERNotes:1. Exhibit depicts the preliminary frac equipment layout on Pad 25A (COGCC Loc ID: 334457) supporting remote well completion operations for the proposed wells on Pad 36A.2. Six (6) total tanks. Total Capacity 3,000bbls. Working Capacity 2,500bbls.3. Two-and one-half foot (2.5') high perimeter berm with a total site capacity of 55,400bbls. Perimeter berm capacity does not account for equipment displacement.4. Equipment used during well completion operations may vary depending on availability at the time of operations.5. Equipment location may vary depending on site conditions and availability of space on the site during well completions operations.6. Pad Located on Private surface, gate locked at main ranch entrance.FRAC WATERSUPPLY (2-4.5" STEEL)PROPOSED FRACLINES (2-4.5" STEEL) Edge of WorkingPad Surface12345678910111213141516Edge of WorkingPad SurfaceProposed Cuttings Pit19' depth (±8,320 cy) Exist. Pad Elev.: ±9355111'100'62'15'15'Excess Soil Stockpile(±9,780 cy)105'141'113'Exist. Oil andGas LocationExist. Oil and Gas LocationExistingSediment TrapProposed P&A Exist. Conductor #3 Exist. Conductor #2 ABProposed Separators Area(70'x20' and 66'x20')Exist. Oil &Gas LocationExist. LinedDiversion DitchMaintain ExistingDiversion DitchsTrap with 6" Outlet Pipeto Lower Drainage DitchProposedSediment TrapMaintain ExistingSediment TrapDrive OverBerm 25'Temp. Pad BermProposed LinedDiversion DitchCuttings ManagementAreaExis t . Access RoadExist. Topsoil Area 3(±2,330 cy)Exist. Topsoil Area 2(±950 cy)Exist. Topsoil Area 1(±2,320 cy)Proposed LinedDiversion DitchDATE:DRAWN BY:DESIGNED BY:PROJECT:FEET1 INCH =0GRAPHIC SCALE IN FEET8080Contour Interval = 2'11/03/22CPXJASTPPSW1/4NE1/4 Section 36T. 7 S., R. 94 W.Garfield CountySee Note 3FLOWBACKLINE TO PAD 25BPLUG AND ABANDONED WELLPROPOSED GAS WELLPROPOSED FLARE LINEPROPOSED FLOWLINEPROPOSED TRANSFER HOSEPROPOSED WELLHEAD MANIFOLDENCLOSED COMBUSTION DEVICEHP 4-PHASE SEPARATORLOW PRESSURE VESSELPRODUCED WATER TANKWATER PUMPCONDENSATE TANKPRODUCED WATER TANKPROPOSED SURFACE FRAC LINES (2-4.5")PROPOSED FLOWBACK LINEPROPOSED GAS/WATER PIPELINESPROPOSED PRODUCTION EQUIPMENTPROPOSED LAND FARM "EARTH BERM"EXISTING OIL & GAS LOCATIONPROPOSED WORKING PAD SURFACEEXISTING PRODUCTION EQUIPMENTEXISTING ROADDRIVE OVER BERMSURFACE FRACLINE FROMREMOTE FRAC PADPROPOSEDGAS/WATERPIPELINES- LEGEND - SW1/4SE1/4 Section 36T.7S, R 94 W.Garfield CountyDATE:DRAWN BY:DESIGNED BY:PROJECT:0NOT TO SCALE011/03/22CPXJASTPP- LEGEND -WATER STORAGE TANKS2-4.5" FRAC LINESCPX BURIED 8" FLEX STEEL FROM PAD 22-4.5" FRAC WATER SUPPLY8" LAY FLAT TRANSFER LINE 12345678910111213141516ABExis t . Access RoadSection 36T. 7 S., R. 94 W.Garfield CountySee Note 3PLUG AND ABANDONED WELLPROPOSED GAS WELLPRODUCED WATER TANKCONDENSATE TANKWELLHEAD FLOWLINEPRODUCTION PAD SURFACEGAS/WATER/CONDENSATE FLOWLINESEXISTING 2' EARTHEN BERMEXISTING OIL & GAS LOCATIONWORKING PAD SURFACEEXISTING ROADDRIVE OVER BERMDIVERSION DITCHINTERIM RECLAMATION AREA, MULCHEDAND SEEDEDGas/Water/CondensateFlowlines- LEGEND -Exist. Oil andGas LocationExist. TPR 132-36 Drive OverBerm 25'Exist. Oil and Gas LocationExist. Oil &Gas LocationExist. LinedDiversion DitchMaintain ExistingDiversion DitchsSediment Trap with 6"Outlet Pipe to LowerDrainage DitchLinedDiversion DitchSeparation Equipment:8 Quad SeparatorsFuel GasSkidUtilities/Controls:Power GenerationPLC Site ControllerRemote TelemetryUnit/RadioExist. Conductor #3 Exist. Conductor #2 Existing CreekInterim Reclamationarea, Mulched andSeededDATE:DRAWN BY:DESIGNED BY:PROJECT:FEET1 INCH =0GRAPHIC SCALE IN FEET8080Contour Interval = 2'11/16/22CPXTPPTPPProduction PadSurfaceDISTURBANCE AREASOIL AND GAS LOCATION: ± 5.45 ACWORKING PAD SURFACE: ± 2.06 ACACCESS ROAD: ± 0.0 AC PRODUCTION PAD: ± 1.34 AC RE-CLAIMED AREA: ± 4.11 AC ExistingSediment TrapInstrument AirSkidProduced WaterTransfer PumpSediment TrapLinedDiversion DitchCondensateLACT UnitV.O.C.CombustorBlowdown EnclosedCombustion DeviceHeater TreatersWorking PadSurfaceKnockoutVesselsWorkingPad Surface CPX Piceance Holdings, LLC 34 S. Wynden Drive, Suite 240 Limited Impact Review Garfield County, Colorado Houston, TX 77056 TPR Well Pad 36A Article 9 Oil and Gas Permit Application Wildlife Habitat Drawing Existing Well Pad 25A TepeeParkForestServiceRoad8241 Mile from Working Pad Surface CPX PICEANCE HOLDINGS LLC CPX PICEANCE HOLDINGS LLC White River National Forest Existing Well Pad 36A(Private)White River National Forest 1,770' 5,050' 3,860' 1,740' 2,170'RanchRoadDistance = 0' Acreage = 5.45 ac Section 24Section 23 Section 26 Section 25 Section 35 Section 36 Section 19 Section 30 Section 31 Section 6 Section 7 Section 18 Section 12Section 11 Section 14 Section 13 T7S R94W T8S R94W T7S R94WT8S R93WT7S R94WT7S R93WT8S R94WT8S R93WT8S R93W T7S R93W Legend Working Pad Surface Oil and Gas Location 1 Mile from Working Pad Surface Existing Off-location Flowlines Proposed Off-location Flowlines Private Road Forest Service Road Parcels Rule 1202.c Habitats Cutthroat Trout Designated Crucial Habitat Rule 1202.d Density Habitats Elk Production Area Elk Winter Concentration Area Mule Deer Migration Corridor Forest Service Jurisdiction USFS Lynx Habitat Denning Winter Figure 3 CPX Piceance Holdings, LLC Tepee Park Ranch Well Pad 36A Aota Technical, LLC Figure No. Wildlife Habitat Drawing 10/18/22 Date Garfield County SW1/4NE1/4 Sec. 36, T7S R94W, 6th P.M.0 375 750 1,125 1,500 Feet The following source information was reviewed during preparation of the Wildlife Habitat Drawing: 1. COGIS High Priority Habitat Layers 2. Critical Habitat IPaC Report: https://ecos.fws.gov/ipac/; Critical habitat is not present. 3. Migratory Birds: https://www.fws.gov/birds/index.php; Operator will comply with Rule 1202.a.(8). 4. State Protected Species: https://cpw.state.co.us/learn/Pages/SpeciesProfiles.aspx 5. Buffer Zones and Seasonal Restrictions for Colorado Raptors: https://cpw.state.co.us/Documents/WildlifeSpecies/LivingWithWildlife/Raptor-Buffer-Guidelines.pdf 6. U.S. Forest Service Habitat Data: https://www.fs.usda.gov/main/whiteriver/landmanagement/gis Notes: (1) Beaver Creek also designated as 1202.c Native Fish and Other Native Aquatic Species Conservation Waters. (2) Tepee Creek also designated as 1202.c Sportfish Management Waters. (3) Rule 309.e.(1) Other Consultation Habitat is not present. CPX Piceance Holdings, LLC 34 S. Wynden Drive, Suite 240 Limited Impact Review Garfield County, Colorado Houston, TX 77056 TPR Well Pad 36A Article 9 Oil and Gas Permit Application Hydrology Maps 2,640' from Working Pad Surface 1,430' NE 60' W 850' N 880' N CPX Water Well No. 321677 CPX PICEANCE HOLDINGS LLC CPX PICEANCE HOLDINGS LLC Existing Well Pad 25A Existing Well Pad 36A 940' SW 1,520' S 610' NE 190' NW 410' N 920' N 580' N 740' N 223' W Section 25 Section 36 Section 31 Section 6 Section 7 Section 1 Section 12 T7S R94W T8S R94W T7S R94WT8S R93WT7S R94WT7S R93WT8S R94WT8S R93WT8S R93W T7S R93W Legend Water Well Working Pad Surface Oil and Gas Location 2,640' from Working Pad Surface Forest Service Jurisdiction Parcels Water Feature is Downgradient from the Oil and Gas Location National Wetlands Inventory Forested/Shrub Wetland Freshwater Pond Figure 4a Aota Technical, LLC Figure No. Hydrology Map 10/18/22 Date Data Sources: COGCC GIS Online U.S. Fish and Wildlife Service, National Wetlands Inventory Note: There are no Public Water System Facilities (intakes, wells, storage facilities, recharge areas, or treatment plants) and no Rule 411 buffer zones within 2,640' of the Working Pad Surface. There are no surface waters within the 2,640' of the Working Pad Surface that are 15 stream miles upstream of a Public Water System intake. 0 125 250 375 500 Feet CPX Piceance Holdings, LLC Tepee Park Ranch Well Pad 36A Garfield County SW1/4NE1/4 Sec. 36, T7S R94W, 6th P.M. 2,640' from Working Pad Surface 1,430' NE 130' W 850' N 880' N CPX Water Well No. 321677 CPX PICEANCE HOLDINGS LLC CPX PICEANCE HOLDINGS LLC Existing Well Pad 25A Existing Well Pad 36A 940' SW 1,520' S 610' NE190' NW 410' N 920' N 740' N 223' W Section 25 Section 36 Section 31 Section 6 Section 7 Section 1 Section 12 T7S R94W T8S R94W T7S R94WT8S R93WT7S R94WT7S R93WT8S R94WT8S R93WT8S R93W T7S R93W Legend Water Well Working Pad Surface Oil and Gas Location 2,640' from Working Pad Surface Forest Service Jurisdiction Parcels Surveyed Stream Actual Water Feature is Downgradient from the Oil and Gas Location National Wetlands Inventory Forested/Shrub Wetland Freshwater PondFigure 4b Aota Technical, LLC Figure No. Hydrology Map 11/1/22 Date Data Sources: COGCC GIS Online U.S. Fish and Wildlife Service, National Wetlands Inventory Note: There are no Public Water System Facilities (intakes, wells, storage facilities, recharge areas, or treatment plants) and no Rule 411 buffer zones within 2,640' of the Working Pad Surface. There are no surface waters within the 2,640' of the Working Pad Surface that are 15 stream miles upstream of a Public Water System intake. 0 125 250 375 500 Feet CPX Piceance Holdings, LLC Tepee Park Ranch Well Pad 36A Garfield County SW1/4NE1/4 Sec. 36, T7S R94W, 6th P.M. CPX Piceance Holdings, LLC 34 S. Wynden Drive, Suite 240 Limited Impact Review Garfield County, Colorado Houston, TX 77056 TPR Well Pad 36A Article 9 Oil and Gas Permit Application Access Road Map Existing Well Pad 25A TepeeParkRanchRoadForestServiceRoad8241 Mile from Working Pad Surface CPX PICEANCE HOLDINGS LLC CPX PICEANCE HOLDINGS LLC White River National Forest Existing Well Pad 36A (Private)White River National Forest Existing access 7,600' 2,000' from Access Road Existing access 300' Section 24 Section 25 Section 36 Section 30 Section 31 Section 6 T7S R94WT8S R93WT7S R94WT7S R93WT8S R93W T7S R93W Legend Working Pad Surface Oil and Gas Location 2,000' from Access Road Existing Access Private Road Forest Service Road Parcels Forest Service Jurisdiction Rule 1202.c NSO Habitats Cutthroat Trout Designated Crucial Habitat USFS Lynx Habitat Denning Winter Figure 5 CPX Piceance Holdings, LLC Tepee Park Ranch Well Pad 36A Aota Technical, LLC Figure No. Access Road Map 10/18/22 Date Garfield County SW1/4NE1/4 Sec. 36, T7S R94W, 6th P.M.0 200 400 600 800 Feet Notes: (1) Beaver Creek also designated as 1202.c Native Fish and Other Native Aquatic Species Conservation Waters. (2) Tepee Creek also designated as 1202.c Sportfish Management Waters. (3) Rule 309.e.(1) Other Consultation Habitat is not present. Data Sources: COGCC GIS Online CPX Piceance Holdings, LLC 34 S. Wynden Drive, Suite 240 Limited Impact Review Garfield County, Colorado Houston, TX 77056 TPR Well Pad 36A Article 9 Oil and Gas Permit Application Related Location and Flowline Map CPX Existing Well Pad 25A Location ID 334457 TepeeParkRanchForestServiceRoad824Area Affected by OGDP (2,000' Radius) CPX PICEANCE HOLDINGS LLC CPX PICEANCE HOLDINGS LLC White River National Forest CPX Existing Well Pad 36A Location ID 334460 Road(Private)White River National Forest CPX Temporary Water Support Pad 25B Location ID 482984 132-36 TPR 112-6 TPR 143-36 TPR 176-25 TPR 112-16 TPR 1 TPR Section 24 Section 25 Section 36 Section 19 Section 30 Section 31 Section 6 Section 7 Section 1 Section 12 T7S R94W T8S R94W T7S R94WT8S R93WT7S R94WT7S R93WT8S R94WT8S R93WT8S R93W T7S R93W Legend Drilled and Producing Drilled Drilled/Uncompleted "DUC" Well Permitted Working Pad Surface Oil and Gas Location Area Affected by OGDP (2,000' Temporary Water Support Pad Proposed Off-location Flowlines Forest Service Road Private Road White River National Forest Lands Parcels Figure 7a CPX Piceance Holdings, LLC Tepee Park Ranch Well Pad 36A Aota Technical, LLC Figure No. Related Location and Flowline Map 10/10/22 Date Garfield County SW1/4NE1/4 Sec. 36, T7S R94W, 6th P.M. 0 250 500 750 1,000 Feet Data Source: COGCC GIS Online CPX Piceance Holdings, LLC 34 S. Wynden Drive, Suite 240 Limited Impact Review Garfield County, Colorado Houston, TX 77056 TPR Well Pad 36A Article 9 Oil and Gas Permit Application Geologic Hazard Map Existing Well Pad 25A TepeeParkForestServiceRoad8241 Mile from Working Pad Surface CPX PICEANCE HOLDINGS LLC CPX PICEANCE HOLDINGS LLC White River National Forest Existing Well Pad 36A (Private)White River National Forest RanchRoadSection 24Section 23 Section 26 Section 25 Section 35 Section 36 Section 19 Section 30 Section 31 Section 6 Section 7Section 12Section 11 T7S R94W T8S R94W T7S R94WT8S R93WT7S R94WT7S R93WT8S R94WT8S R93WT8S R93W T7S R93W Legend Working Pad Surface Oil and Gas Location 1 Mile from Working Pad Surface Forest Service Jurisdiction Parcels Landslides Permitted Shale Excavation Forest Service Road Private Road Figure 6a CPX Piceance Holdings, LLC Tepee Park Ranch Well Pad 36A Geologic Hazard Map Garfield County SW1/4NE1/4 Sec. 36, T7S R94W, 6th P.M. Aota Technical, LLC Figure No. 10/7/22 Date 0 250 500 750 1,000 Feet Data Source: COGCC GIS Online Colorado Department of Natural Resources Colorado Geological Survey U.S. Geological Survey, Prospect and Mine Related Features Existing Well Pad 25A 1 Mile from Working Pad Surface White River National Forest Existing Well Pad 36A White River National Forest Section 14 Section 13Section 15 Section 22 Section 24Section 23 Section 26 Section 27 Section 25 Section 35 Section 34 Section 36 Section 18 Section 20 Section 19 Section 30 Section 29 Section 32 Section 31 Section 6 Section 5 Section 8 Section 7 Section 17Section 18 Section 20Section 19 Section 12Section 10 Section 11 Section 15 Section 14 Section 13 Section 24Section 22 Section 23 T7S R94W T8S R94W T7S R94WT7S R93WT8S R94WT8S R93WT8S R93W T7S R93W Legend Working Pad Surface Oil and Gas Location 1 Mile from Working Pad Surface Forest Service Jurisdiction Parcels Landslides Permitted Shale Excavation Forest Service Road Private Road Figure 6b CPX Piceance Holdings, LLC Tepee Park Ranch Well Pad 36A Geologic Hazard Map Garfield County SW1/4NE1/4 Sec. 36, T7S R94W, 6th P.M. Aota Technical, LLC Figure No. 10/7/22 Date 0 440 880 1,320 1,760 Feet Data Source: COGCC GIS Online Colorado Department of Natural Resources Colorado Geological Survey U.S. Geological Survey, Prospect and Mine Related Features SELF-CERTIFICATION (21) GEOLOGIC HAZARD PLAN LESSER IMPACT AREA EXEMPTION REQUEST Requirement Response Exemption Requested Rule 304.c.(21) Geologic Hazard Plan Resource Concern Geologic hazard to the Oil and Gas Location Exemption Circumstance The impact to the resource is so minimal as to pose no concern. Description A professional geologist has made the determination that the only mapped geologic hazard at the Oil and Gas Location, one mapped landslide area, is so minimal as to pose no concern. The professional geologist’s self-certification statement is provided below. The individual’s qualifications meet the statutory definition at C.R.S. 23-41-208(1)(b) as follows: the individual is engaged in the practice of geology. He is a graduate of Queens College of the City University of New York (BA Geology 1978) and the University of Massachusetts at Amherst (MS Engineering Geology 1982). He has been professionally engaged in hydrogeology since 1984. He has been the principal scientist for Walter Environmental & Engineering Group, Inc. since 1998. These detailed Geologic Hazard Maps, self-certification, and citations are submitted as part of the Form 2A application. SELF-CERTIFICATION The geological information I reviewed for relevance to the Oil and Gas Location includes the following listed material and citations provided below under Sources: Colorado Hazard Mapping; Colorado Landslide Hazard Mitigation Plan; Department of Public Health and Environment radon data; Geologic Map of the North Mamm Peak Quadrangle; FEMA flood mapping; Garfield County Multi-Jurisdictional Hazard Mitigation Plan; Google Earth Pro Aerial Image; Historical Coal Mines Online Data; NRCS soil resource mapping; Radioactive Mineral Occurrences of Colorado; U.S. Landslide Inventory Online Data; and U.S. Quaternary I certify that I am a Professional Geologist, having met the educational requirements and professional work experience required by C.R.S. 23-41- 208(1)(b). I have reviewed information pertaining to this Oil and Gas Location and the surrounding area and have found no Geologic Hazard within a 1-mile radius which is so adverse to past, current, or foreseeable construction or land use as to constitute a significant hazard to public health, safety, or property. 10/31/22 _____________________________ ___________________ Kenneth L. Walter Date Walter Environmental & Engineering Group, Inc. B.A., M.S., Professional Geologist Recognized Environmental Professional, Colorado, No. 58 Requirement Response Faults. The information was used to assess avalanches, landslides, rockfalls, mudflows or debris flows, soils, seismic effects, radioactivity, subsidence, and flooding. The single geologic hazard identified within 1 mile of the Oil and Gas Location is one mapped landslide area. In accordance with Rule 304.b.(7).I, the Geologic Hazard Maps show the mapped landslide area within 1 mile of the location (Figure 6a) and an expanded view of the landslide area (Figure 6b). A finding of a geologic hazard from a landslide, and an associated Geologic Hazard Plan, are believed to be unnecessary for this location. My finding is detailed in the attached Geological Hazard Assessment (October 31, 2022) and is summarized here. The mapped landslide area is approximately 0.4 miles west of the Oil and Gas Location. The U.S. Geological Survey assigned the area the lowest rating of 1 out of 5 for a possible landslide (USGS Landslide Hazard Program, U.S. Landslide Inventory Online Data). This is because Well Pad 36A is located south (upgradient) of the Tepee Creek drainage. The Site is also separated from the mapped landslide area by an unnamed ridgeline and timbered area. Based on the topography and separation, the Site is not within the flow path of a possible landslide. In addition, the timbered area provides additional energy-dissipating armoring against a possible landslide. Based on this evaluation, there is no risk of landslide affecting the Oil and Gas Location. ________________________ 10/31/22 Kenneth L. Walter Date Walter Environmental & Engineering Group, Inc. B.A., M.S., Professional Geologist Recognized Environmental Professional, Colorado, No. 58 Sources 1. Colorado Hazard Mapping & Risk MAP Portal: https://coloradohazardmapping.com/hazardMapping/debrisFlowMapping/Map (reviewed January 18, 2022). 2. Colorado Landslide Hazard Mitigation Plan, Bulletin 48, 1988; pp. 11-15. 3. Department of Public Health and Environment – Radon: https://cdphe.colorado.gov/understanding-radon (reviewed January 20, 2022). 4. Donnell, J. R.; Yeend, W. E.; and Smith, M. C.; 1989. Geologic Map of the North Mamm Peak Quadrangle, Garfield County, Colorado. 5. FEMA Flood Map Service Center: Search All Products: https://msc.fema.gov/portal/advanceSearch#searchresultsanchor (reviewed January 20, 2022). 6. Garfield County Multi-Jurisdictional Hazard Mitigation Plan, August 2017, Section 4, pp. 69-83; 89-94. 7. Google Earth Pro Aerial Image; Image dated June 16, 2016. 8. Historical Coal Mines Online Data: https://cologeosurvey.maps.arcgis.com/apps/webappviewer/index.html?id=1891e3149eda44af 9dc8af81c4dc58a8 (reviewed January 20, 2022). 9. NRCS Custom Soil Resource Report for Grand Mesa - West Elk Area, Colorado, Parts of Delta, Garfield, Gunnison, Mesa, and Montrose Counties; Holy Cross Area, Colorado, Parts of Eagle, Garfield, Mesa, Pitkin, and Summit Counties; and Rifle Area, Colorado, Parts of Garfield and Mesa Counties; December 28, 2021. 10. ON-B-40M Radioactive Mineral Occurrences of Colorado, Colorado Geological Survey: https://cologeosurvey.maps.arcgis.com/apps/webappviewer/index.html?id=c5381e1335284d63 bfa5d4b018b3372f (reviewed January 20, 2022). 11. USGS Landslide Hazard Program; U.S. Landslide Inventory Online Data: https://usgs.maps.arcgis.com/apps/webappviewer/index.html?id=ae120962f459434b8c904b45 6c82669d (reviewed January 17, 2022). 12. U.S. Quaternary Faults, USGS Geologic Hazards Science Center Golden, CO: https://usgs.maps.arcgis.com/apps/webappviewer/index.html?id=5a6038b3a1684561a9b0aadf 88412fcf (reviewed January 20, 2022). P.O. Box 3967 Grand Junction, Colorado 81502 phone: (970) 255-8017 toll free: (888) 443-8017 fax: (970) 255-8018 October 31, 2022 CPX Piceance Holdings, LLC Attention: Mr. Nicholas Kurtenbach 34 South Wynden Drive, Suite 240 Houston, Texas 77056 Subject: Geological Hazard Assessment Existing Tepee Park Ranch Well Pad 36A, Garfield County, Colorado Dear Mr. Kurtenbach: This document summarizes the assessment of geologic hazards within 1 mile of the existing Tepee Park Ranch Well Pad 36A location. CPX Piceance Holdings, LLC (CPX) retained Walter Environmental & Engineering Group, Inc. (Walter) to assess geologic hazards within 1 mile of the Working Pad Surface (WPS) of Tepee Park Ranch Well Pad 36A (“Site”). This Tepee Park Ranch Well Pad 36A Geologic Hazards Assessment addresses “Geologic Hazards” as defined by COGCC’s Rules and Regulations and Colorado Revised Statutes (C.R.S.) § 24-65.1-103(8): “Geologic hazard” means a geologic phenomenon which 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 term includes but is not limited to: (a) Avalanches, landslides, rock falls, mudflows, and unstable or potentially unstable slopes; (b) Seismic effects; (c) Radioactivity; and (d) Ground subsidence. The Tepee Park Ranch Well Pad 36A Geologic Hazard Map was prepared in accordance with COGCC Rule 304.b.(7).I.: “Geologic Hazard Map. A map identifying any Geologic Hazards within a 1 mile radius of the proposed Working Pad Surface. For any identified Geologic Hazard that extends beyond the 1 mile radius, a second map scaled to show the extent of that hazard in October 31, 2022 Page 2 of 8 P.O. Box 3967, Grand Junction, CO 81502 phone: (970) 255-8017 fax: (970) 255-8018 relation to the proposed Oil and Gas Location.” The Geologic Hazard Map includes data from: • COGCC GIS Online • Colorado Department of Natural Resources • Colorado Geological Survey • U.S. Geologic Survey, Prospect and Mine Related Features • U.S. Geological Survey, National Hydrology Dataset A single mapped geologic hazard appears within 1-mile of Well Pad 36A. It is specific to landslide data from USGS Landslide Hazard Program; U.S. Landslide Inventory Online Data. There are no other geologic hazards within 1 mile, as discussed below. The landslide data and Walter’s assessment have determined that there is no potential for avalanche, landslides, rockfall, mudflow, and unstable or potentially unstable slopes which 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 the property. Additionally, the area does not have a risk from radioactivity, ground subsidence, or flooding. Based on this finding, a further Geologic Hazard Plan is not indicated for this location. The professional opinions in this report were developed using publicly available information and did not include sample collection, analyses, or site inspections. Site Overview The Site is located on topographic high‐ground approximately 9.5 miles southwest of Rifle Colorado at an approximate elevation of 9,355 feet above mean sea level (msl). The Site is located in the SW¼ NE¼ of Section 36, Township 7 South, Range 94 West, of the 6th principal meridian. Latitude and Longitude for the Site are approximately 39.395017, -107.831908 (WGS 84). Geologic Hazard Assessment The assessment analyzed the potential geologic hazards summarized below. Avalanches According to the Garfield County Multi‐Jurisdictional Hazard Mitigation Plan: “The greatest avalanche threats are in the mountainous areas of Garfield County. Steeply sloped areas (30 to 45 degrees) are highly subject to avalanches, primarily on south exposed slopes where unstable snow conditions are most likely to occur.” October 31, 2022 Page 3 of 8 P.O. Box 3967, Grand Junction, CO 81502 phone: (970) 255-8017 fax: (970) 255-8018 Although localized slope angles do exceed 30 degrees, the Site is located within the Beaver Creek drainage basin which is generally down-to-the-north trending. Thus, limited “south exposed slopes” lie within 1 mile of the site, and no south-facing slopes surround the location. In addition, aerial imagery from 2016 demonstrate no historic avalanche slide paths surrounding the location. These data lead Walter to conclude that avalanches are not a geologic hazard to the Site. Reference Garfield County Multi-Jurisdictional Hazard Mitigation Plan, August 2017; Section 4, pp. 81-83. Google Earth Pro Aerial Image; Image dated June 16, 2016. Landslides USGS data (referenced below) identifies one “Possible Landslide” area within 1 mile of the Site (see Geologic Hazard Map). The area is designated as “Possible Landslide” area with the lowest assigned confidence rating of 1 out of 5 (USGS Landslide Hazard Program; U.S. Landslide Inventory Online Data). The “Possible Landslide” area is approximately 0.4 miles west of the Site. It is located on the northeastern side of North Mamm Peak. The overwhelming majority of the mapped “Possible Landslide” is within the (down-to-the-east trending) Tepee Creek drainage located west of the Site. The Colorado Landslide Hazard Mitigation Plan characterizes key components of landslide material including: “The failure is caused by liquefaction, the process whereby saturated, loose, cohesionless sediments (usually sands and silts) are transformed from a solid into a liquefied state.” “Generally speaking, five conditions must be present for a debris flow to occur: 1) steep slopes, 2) loose rock and soil materials, 3) clay minerals, 4) saturated soils, and 5) rainfall - or snowmelt-generated runoff of sufficient intensity and duration to initiate slope movement.” “In debris avalanches, progressive failure is more rapid, and the whole mass, either because it is quite wet or because it is on a steep slope, liquefies, at least in part, flows, and tumbles downward, commonly along a stream channel, and may advance well beyond the foot of the slope.” The common characteristic identified in this reference is moisture rich (saturated) soils. NRCS data identifies the “Possible Landslide” area to be composed of two soil types (within 1 October 31, 2022 Page 4 of 8 P.O. Box 3967, Grand Junction, CO 81502 phone: (970) 255-8017 fax: (970) 255-8018 mile of the Site): “331C-Woodrock-Angostura Families Complex” “449C-Tampico-Echemoor-Eyre Families Complex” In both cases, the NRCS characterizes the Drainage class of this soil as “Well Drained.” “Well drained” soils typically cannot become the “moisture rich (saturated) soils” specified in the Colorado Landslide Hazard Mitigation Plan. Walter also evaluated whether the Site was located in the likely flow path of the mapped “Possible Landslide” area. Landslides are gravity-driven phenomena. As illustrated on the Geologic Hazard Map, the “Possible Landslide” area is located within the Tepee Creek drainage. The Site is located south (upgradient) of the Tepee Creek drainage. The Site is also separated from the “Possible Landslide” area by an unnamed ridgeline and timbered area. Based upon the topography and separation, Walter believes that the Site is not within the flow path of the “Possible Landslide.” In addition, the timbered area provides additional energy-dissipating armoring against a “Possible Landslide.” Thus, based upon the data summarized above, Walter believes that the mapped “Possible Landslide” is not a geologic hazard to the Site. References Colorado Landslide Hazard Mitigation Plan, Bulletin 48, 1988; pp 11-15. Google Earth Pro Aerial Image; Image dated June 16, 2016. NRCS Custom Soil Resource Report for Grand Mesa - West Elk Area, Colorado, Parts of Delta, Garfield, Gunnison, Mesa, and Montrose Counties; Holy Cross Area, Colorado, Parts of Eagle, Garfield, Mesa, Pitkin, and Summit Counties; and Rifle Area, Colorado, Parts of Garfield and Mesa Counties; December 28, 2021. USGS Landslide Hazard Program; U.S. Landslide Inventory Online Data: https://usgs.maps.arcgis.com/apps/webappviewer/index.html?id=ae120962f459434b8c904b456c 82669d (reviewed January 17, 2022). Rockfalls By definition, rockfalls require (at a minimum) exposed rock faces (a.k.a. outcrops) to serve as the source of the falling rock, as well as the rock face to be located in a topographic upgradient location. Walter reviewed the 2016 Google Earth image for the Site vicinity. The closest outcrop in a topographic upgradient direction is over 3,000 feet west of the Site. Therefore, based upon these data, the rockfalls are not a geologic hazard to the Site. October 31, 2022 Page 5 of 8 P.O. Box 3967, Grand Junction, CO 81502 phone: (970) 255-8017 fax: (970) 255-8018 References Google Earth Pro Image; Image dated June 17, 2016. Mudflows or Debris Flows In accordance with the Garfield County Multi‐Jurisdictional Hazard Mitigation Plan, mudflows and/or debris flows are a subset of the general term “landslide.” The driving forces behind mudflows or debris flows are the same as a landslide. As discussed above, based upon the reported soil characteristics and predicted flow path of a mudflow or debris flow, they are not a geologic hazard(s) to the Site. In addition, Walter reviewed the online Colorado Hazard Mapping and Risk MAP Portal. The Site is not located in or near a mapped debris flow. References Garfield County Multi-Jurisdictional Hazard Mitigation Plan, August 2017; Section 4, pp. 81-83. Colorado Hazard Mapping & Risk MAP Portal: https://coloradohazardmapping.com/hazardMapping/debrisFlowMapping/Map (reviewed January 18, 2022). Unstable or Potentially Unstable Slopes “Unstable or Potentially Unstable Slopes” are addressed in the “Landslides,” “Rockfalls,” and “Mudflows or Debris Flows” sections above. For the reasons summarized above, “Unstable or Potentially Unstable Slopes” are not a geological hazard at this Site. Seismic Effects The Garfield County Multi‐Jurisdictional Hazard Mitigation Plan states: “The locations most likely to experience an earthquake within Garfield County are those near fault lines. Figure 33 shows the faults located within Garfield County. These faults are located in the southeastern and northeastern portions of the County.” The Site, which is located in central Garfield County, is not located above any known mapped faults. Therefore, Walter believes Seismic Effects are not a geologic hazard to the Site. References Donnell, J. R.; Yeend, W. E.; and Smith, M. C.; 1989. Geologic Map of the North Mamm Peak Quadrangle, Garfield County, Colorado. Garfield County Multi-Jurisdictional Hazard Mitigation Plan, August 2017; Section 4, pp. 89-94. October 31, 2022 Page 6 of 8 P.O. Box 3967, Grand Junction, CO 81502 phone: (970) 255-8017 fax: (970) 255-8018 U.S. Quaternary Faults, USGS Geologic Hazards Science Center Golden, CO: https://usgs.maps.arcgis.com/apps/webappviewer/index.html?id=5a6038b3a1684561a9b0aadf88 412fcf (reviewed January 20, 2022). Radioactivity Review of the Colorado Department of Public Health and Environment website for Radon information indicates that the entire State of Colorado, including Garfield County, has high radon potential. It is anticipated that based on the project for the Site, that no enclosed structures or buildings will be developed for use during production. In addition, Walter reviewed the Colorado Geological Survey map of radioactive mineral occurrences. No radioactive minerals are plotted within several miles of the Site. Therefore, Walter believes that radon is not expected to represent a significant geologic or worker exposure health hazard. References Department of Public Health and Environment – Radon: https://cdphe.colorado.gov/understanding-radon (reviewed January 20, 2022). ON-B-40M Radioactive Mineral Occurrences of Colorado, Colorado Geological Survey: https://cologeosurvey.maps.arcgis.com/apps/webappviewer/index.html?id=c5381e1335284d63bf a5d4b018b3372f (reviewed January 20, 2022). Ground Subsidence The Garfield County Multi‐Jurisdictional Hazard Mitigation Plan states: “Ground subsidence is the sinking of the land over human caused or natural underground voids and the settlement of native low density soils. The type of subsidence of greatest concern in Garfield County, and the rest of Colorado, is the settling of the ground over abandoned mines.” Colorado Geologic Survey data (reference below) indicate that the Site is not located in an area that is known to have been impacted by mining operations. Thus, significant subsidence is not anticipated, and therefore not a geologic hazard at this site. References Garfield County Multi-Jurisdictional Hazard Mitigation Plan, August 2017; Section 4, pp. 69-83. Historical Coal Mines Online Data: https://cologeosurvey.maps.arcgis.com/apps/webappviewer/index.html?id=1891e3149eda44af9d c8af81c4dc58a8 (reviewed January 20, 2022). October 31, 2022 Page 7 of 8 P.O. Box 3967, Grand Junction, CO 81502 phone: (970) 255-8017 fax: (970) 255-8018 Flooding Facility is located in an upland area with no natural drainages within the site boundary. The NRCS soil type at the Site is: “104A—Haplocryolis-Cryaquolls complex” Flood Frequency for this soil type is “None”, meaning that the chance of flooding is nearly 0% in any year. The site may be subject to sheet flow from precipitation events, however, storm water control measures are in place to mitigate or prevent storm water from entering the facility and disrupting operations. In addition, Walter searched for FEMA online data for the Site and vicinity. There is no floodplain mapping for this location. Based upon these data, Walter believes that flooding is not a geologic hazard at this site. References FEMA Flood Map Service Center: Search All Products: https://msc.fema.gov/portal/advanceSearch#searchresultsanchor (reviewed January 20, 2022). NRCS Custom Soil Resource Report for Grand Mesa - West Elk Area, Colorado, Parts of Delta, Garfield, Gunnison, Mesa, and Montrose Counties; Holy Cross Area, Colorado, Parts of Eagle, Garfield, Mesa, Pitkin, and Summit Counties; and Rifle Area, Colorado, Parts of Garfield and Mesa Counties; December 28, 2021. Conclusions and Summary Based on this Geological Hazards Assessment of publicly available information, there are no known Geological Hazards within the Tepee Park Ranch Well Pad 36A Site. I certify that I am a Professional Geologist, having met the educational requirements and professional work experience required by C.R.S. § 23-41-208(b). I have reviewed information pertaining to this Oil and Gas location and the surrounding area and have identified no Geologic Hazards within a 1 mile radius. Respectfully submitted, Walter Environmental & Engineering Group, Inc. Kenneth L. Walter B.A., M.S., Professional Geologist, Colorado ASTM Environmental Professional Recognized Environmental Professional, No. 58, Colorado Resume of KENNETH L. WALTER Principal, Walter Environmental & Engineering Group, Inc. EDUCATION Master of Science, Engineering Geology: University of Massachusetts at Amherst, 1982 Bachelor of Arts, Geology: Queens College of the City University of New York, 1978 EXPERIENCE Walter Environmental & Engineering Group, Inc., Principal Scientist, 1998-Present Mesa Environmental, Inc., Senior Scientist, 1997-1998 Walsh Environmental, Inc., Principal Hydrogeologist, 1991-1997 EnecoTech, Inc., Associate Hydrogeologist, 1988-1991 CTL/Thompson, Inc., Engineering Hydrogeologist, 1984-1988 SELECTED PROJECT EXPERIENCE The following pages provide a brief summary of Ken’s 30+ years of diverse project experience. Petroleum Industry - Upstream Due Diligence • Multiple Ohio Brine-Injection Disposal Facilities Due-Diligence Assessment • Augustus Energy Partners, LLC, Natural Gas Well Sites and Gas Processing Plant, Colorado and Utah, Due-Diligence Assessment • Shell Properties Acquisition, Due Diligence Investigation, Western Colorado • Post Oak Energy Natural Gas Well Sites and Gas Processing Plant, Colorado and Utah, Due- Diligence Assessment Assessment • Williams Drilling Mud Disposal Options Investigation, Piceance Basin • WPX Pit Monitoring-Well Installations, Western Colorado • COGCC Fugitive Gas Migration Fracture Study, Silt, Colorado • COGCC Domestic Water Sampling Program, Western Colorado • COGCC Brine-Affected Soil Investigations, DeBeque, Colorado • BOPCO Gas-Plant Acquisition Assessment, Meeker, Colorado Remediation • Halliburton Yard Blast-Media Disposal Permitting and Cleanup, Clifton, Colorado Compliance • Encana Comprehensive Waste-Management Plan, Piceance, Colorado • WPX SPCC Plans, Western Colorado Petroleum Industry - Downstream Closure • Former Landmark Refinery, Fruita Colorado • 55k-Barrel Tank Closures • API Separator Closure • VCUP Closure Sampling/Reporting • Drum-Storage Yard Closure Resume of KENNETH L. WALTER (continued) Principal, Walter Environmental & Engineering Group, Inc. SELECTED PROJECT EXPERIENCE (continued) Assessment • More than 250 retail UST sites in Kansas, Missouri, Iowa, North Dakota, South Dakota, Florida, Nebraska, Colorado, Wyoming, Arizona, Oklahoma, and California. • Rangely Colorado Brownfield Former Gas Stations Assessment/Tank Closure • Ground-Water Characterization, Former Landmark Refinery, Fruita, Colorado • Former Landmark Refinery Brownfield Grant Application, Fruita Colorado. Remediation • Former Landmark Refinery CAMU Treatment Optimization Study, Fruita Colorado • 5S Station SVE/Sparge Remediation, Rangely, Colorado • Amoco Terminal Ground Water Remediation & LNAPL Recovery, Council Bluffs, Iowa • LNAPL Recovery System Design, Installation, and O&M, Former Landmark Refinery, Fruita, Colorado • LNAPL Recovery System Design, Installation, and O&M, Frontier Refinery, Cheyenne, WY • Building 941 LNAPL Recovery Design and O&M, Sioux Gateway Airport, Sioux City, IA • LNAPL & Ground-Water Containment System, Frontier Refinery, Cheyenne, Wyoming Due Diligence • Westcourt’s Diamond Shamrock Retail Station Acquisition Assessments, Utah and Colorado Compliance • SPCC Plans - Multiple Clients, Western Colorado • Facility Response Plans - Multiple Clients, Western Colorado • Former Landmark Refinery Waste-Management Plan, Fruita, Colorado General Environmental Assessment • More than 1,250 ASTM Phase I Environmental Site Assessments throughout the United States • Greater than 50 Phase II Environmental Site Assessments throughout the United States • Riverside Parkway Concept Plan Environmental Assessment, Grand Junction, Colorado • Combined Sewer Elimination Project, Environmental Risk Investigation, Grand Junction, Colorado. • Engineering Design and Operations Plan, Soil and Ground Water Investigations, Produced- Water Evaporation Pond Facilities, Utah and Colorado • Assessment and Remediation - Leightner/Poma Yard Metals Contamination, Grand Junction, Colorado • Bureau of Reclamation Aamodt Environmental Due-Diligence Investigations, New Mexico Resume of KENNETH L. WALTER (continued) Principal, Walter Environmental & Engineering Group, Inc. SELECTED PROJECT EXPERIENCE (continued) Mining • Brohm Mining Spring and Seep Study, Lead, South Dakota • Red Arrow Illegal Mine and Mill, Emergency-Response Assessment, Mancos, Colorado • High-Wall Slope Stability Design, Peabody Coal Company, Craig, Colorado • Moraine Lake Stability Evaluation, Colorado Springs, Colorado • Former Coal Basin Mine Due Diligence Investigation, Redstone, Colorado Environmental Compliance • Industrial Stormwater Management Plans, Multiple Clients, Western Colorado • Moab DOE UMTRA Facility, Comprehensive Environmental-Compliance Audit, Moab, UT Hydrogeology • Hydrogeologic (Water Supply) Investigation, Thornton Municipal Golf Course, Thornton, Colorado. • Ground Water Investigation, Green Valley Ranch, Colorado. • Water Supply Evaluation, Gilt Edge Mine, Brohm Mining Corp., Deadwood, South Dakota • Cool Springs Ranch Water Supply Investigation, Archuleta County, Colorado REGISTRATIONS and AFFILIATIONS Colorado Professional Geologist ASTM Environmental Professional Recognized Environmental Professional No. 58, Colorado OSHA 40-Hour, 8-Hour Training Courses in Hazardous Waste Operations FAA Remote Pilot (Small Unmanned Aircraft System) Certificate No. 3916454 C:\TWG\Marketing\Quals\2020\QualResumes\KLW Resume v011320-kw.wpd January 13, 2020 (1:57pm) CPX Piceance Holdings, LLC 34 S. Wynden Drive, Suite 240 Limited Impact Review Garfield County, Colorado Houston, TX 77056 TPR Well Pad 36A Article 9 Oil and Gas Permit Application Reference Area Data COGCC Rule 304.b.(9) CPX Piceance Holdings, LLC 34 S. Wynden Drive, Suite 240 Limited Impact Review Garfield County, Colorado Houston, TX 77056 TPR Well Pad 36A Article 9 Oil and Gas Permit Application Reference Area Map Existing Well Pad 25A 2,000' from Working Pad Surface CPX PICEANCE HOLDINGS LLC CPX PICEANCE HOLDINGS LLC Existing Well Pad 36A White River National Forest Reference Area 39.3936216, -107.8325564 T7S R94W T8S R94W T7S R94WT8S R93WT7S R94WT7S R93WT8S R93W T7S R93W Section 25 Section 36 Section 31 Section 6 Section 1 Section 12 Legend Working Pad Surface Oil and Gas Location 2,000' from Working Pad Surface Forest Service Road Private Road Existing Off-location Flowlines Proposed Off-location Flowlines Forest Service Jurisdiction Parcels Figure 8 CPX Piceance Holdings, LLC Tepee Park Ranch Well Pad 36A Aota Technical, LLC Figure No. Reference Area Map 10/19/22 Date Garfield County SW1/4NE1/4 Sec. 36, T7S R94W, 6th P.M. 0 200 400 600 800 Feet Data Source: COGCC GIS Online CPX Piceance Holdings, LLC 34 S. Wynden Drive, Suite 240 Limited Impact Review Garfield County, Colorado Houston, TX 77056 TPR Well Pad 36A Article 9 Oil and Gas Permit Application Reference Area Pictures Looking North Looking East Looking West Looking South Operator: CPX Piceance Holdings, LLC Location: TPR Well Pad 36A Photo: 08/15/22 12:20p (East, West, North, South) Photo: 09/27/22 12:15p (Above) Garfield County SW ¼ NE ¼ Sec. 36, T7S R94W 6th P.M. Reference Area Pictures Field of View View from Above Reference Area Lat/Lon 39.3936216 -107.8325564 View from Above Reference Area Lat/Lon 39.3936216 -107.8325564 CPX Piceance Holdings, LLC 34 S. Wynden Drive, Suite 240 Limited Impact Review Garfield County, Colorado Houston, TX 77056 TPR Well Pad 36A Article 9 Oil and Gas Permit Application NRCS Map Unit Description COGCC Rule 304.b.(10) Existing Well Pad 25A TepeeParkRanchRoad CPX PICEANCE HOLDINGS LLC CPX PICEANCE HOLDINGS LLC Existing Well Pad 36A (Private)338B 338B 449C 220B 220B 338B 338B 104A 220B 104A 449C 338B 104A 104A 331C Section 25 Section 36 Section 30 Section 31 Section 6 T7S R94WT8S R93WT7S R94WT7S R93WT8S R93W T7S R93W 302D 220B 449C 449C 449C 331B 317C 317C 352C 382B 104A 331C 331C 338B Legend Working Pad Surface Oil and Gas Location Forest Service Road Private Road Forest Service Jurisdiction Parcels NRCS Soil Survey Soil Map Unit Soil Map Unit Description 104A: Haplocryolls-Cryaquolls complex, 0 to 15 percent slopes 220B: Angostura family, till substratum, 5 to 40 percent slopes 331C: Woodrock-Angostura families complex, 40 to 65 percent slopes 338B: Wetopa-Doughspon-Echemoor families complex, 5 to 40 percent slopes 449C: Tampico-Echemoor-Eyre families complex, 30 to 65 percent slopes CPX Piceance Holdings, LLC Tepee Park Ranch Well Pad 36A Aota Technical, LLC Soil Unit Map 10/7/22 Date Garfield County SW1/4NE1/4 Sec. 36, T7S R94W, 6th P.M. 0 125 250 375 500 Feet Data Source: COGCC GIS Online Natural Resources Conservation Service. Web Soil Survey Holy Cross Area, Colorado, Parts of Eagle, Garfield, Mesa, Pitkin, and Summit Counties 104A—Haplocryolls-Cryaquolls complex, 0 to 15 percent slopes Map Unit Setting National map unit symbol: 1jh8f Elevation: 6,990 to 11,640 feet Mean annual precipitation: 20 to 40 inches Mean annual air temperature: 32 to 40 degrees F Frost-free period: 30 to 80 days Farmland classification: Not prime farmland Map Unit Composition Haplocryolls and similar soils:65 percent Cryaquolls and similar soils:30 percent Estimates are based on observations, descriptions, and transects of the mapunit. Description of Haplocryolls Setting Landform:Stream terraces on mountain valleys Down-slope shape:Linear Across-slope shape:Linear Parent material:Alluvium derived from igneous and sedimentary rock Typical profile A1 - 0 to 2 inches: channery silt loam A2 - 2 to 12 inches: silt loam E - 12 to 20 inches: silt loam Bw - 20 to 47 inches: channery silt loam C - 47 to 60 inches: channery silt loam Properties and qualities Slope:0 to 15 percent Depth to restrictive feature:More than 80 inches Drainage class:Well drained Capacity of the most limiting layer to transmit water (Ksat):Moderately high (0.21 to 0.71 in/hr) Depth to water table:More than 80 inches Frequency of flooding:None Frequency of ponding:None Maximum salinity:Nonsaline (0.0 to 1.0 mmhos/cm) Available water supply, 0 to 60 inches: Moderate (about 8.7 inches) Interpretive groups Land capability classification (irrigated): 6c Land capability classification (nonirrigated): 6c Map Unit Description: Haplocryolls-Cryaquolls complex, 0 to 15 percent slopes---Holy Cross Area, Colorado, Parts of Eagle, Garfield, Mesa, Pitkin, and Summit Counties 104A Natural Resources Conservation Service Web Soil Survey National Cooperative Soil Survey 12/22/2021 Page 1 of 2 Hydrologic Soil Group: C Other vegetative classification: Quaking aspen/mountain snowberry (POTR5/SYOR2) (D0511) Hydric soil rating: No Description of Cryaquolls Setting Landform:Flood plains on mountain valleys Down-slope shape:Concave Across-slope shape:Concave Parent material:Alluvium derived from igneous and sedimentary rock Typical profile Oi - 0 to 2 inches: slightly decomposed plant material A - 2 to 13 inches: silt loam 2Cg1 - 13 to 22 inches: gravelly sandy clay loam 2Cg2 - 22 to 60 inches: clay loam Properties and qualities Slope:0 to 5 percent Depth to restrictive feature:More than 80 inches Drainage class:Very poorly drained Capacity of the most limiting layer to transmit water (Ksat):Moderately high (0.21 to 0.71 in/hr) Depth to water table:About 0 to 6 inches Frequency of flooding:FrequentNone Frequency of ponding:None Maximum salinity:Nonsaline (0.0 to 1.0 mmhos/cm) Available water supply, 0 to 60 inches: High (about 10.9 inches) Interpretive groups Land capability classification (irrigated): 6w Land capability classification (nonirrigated): 6w Hydrologic Soil Group: C/D Other vegetative classification: Planeleaf willow/water sedge (SAPLP2/CAAQ) (S1405) Hydric soil rating: Yes Data Source Information Soil Survey Area: Holy Cross Area, Colorado, Parts of Eagle, Garfield, Mesa, Pitkin, and Summit Counties Survey Area Data: Version 4, Sep 2, 2021 Map Unit Description: Haplocryolls-Cryaquolls complex, 0 to 15 percent slopes---Holy Cross Area, Colorado, Parts of Eagle, Garfield, Mesa, Pitkin, and Summit Counties 104A Natural Resources Conservation Service Web Soil Survey National Cooperative Soil Survey 12/22/2021 Page 2 of 2 Soils that have profiles that are almost alike make up a soil series. All the soils of a series have major horizons that are similar in composition, thickness, and arrangement. Soils of a given series can differ in texture of the surface layer, slope, stoniness, salinity, degree of erosion, and other characteristics that affect their use. On the basis of such differences, a soil series is divided into soil phases. Most of the areas shown on the detailed soil maps are phases of soil series. The name of a soil phase commonly indicates a feature that affects use or management. For example, Alpha silt loam, 0 to 2 percent slopes, is a phase of the Alpha series. Some map units are made up of two or more major soils or miscellaneous areas. These map units are complexes, associations, or undifferentiated groups. A complex consists of two or more soils or miscellaneous areas in such an intricate pattern or in such small areas that they cannot be shown separately on the maps. The pattern and proportion of the soils or miscellaneous areas are somewhat similar in all areas. Alpha-Beta complex, 0 to 6 percent slopes, is an example. An association is made up of two or more geographically associated soils or miscellaneous areas that are shown as one unit on the maps. Because of present or anticipated uses of the map units in the survey area, it was not considered practical or necessary to map the soils or miscellaneous areas separately. The pattern and relative proportion of the soils or miscellaneous areas are somewhat similar. Alpha-Beta association, 0 to 2 percent slopes, is an example. An undifferentiated group is made up of two or more soils or miscellaneous areas that could be mapped individually but are mapped as one unit because similar interpretations can be made for use and management. The pattern and proportion of the soils or miscellaneous areas in a mapped area are not uniform. An area can be made up of only one of the major soils or miscellaneous areas, or it can be made up of all of them. Alpha and Beta soils, 0 to 2 percent slopes, is an example. Some surveys include miscellaneous areas. Such areas have little or no soil material and support little or no vegetation. Rock outcrop is an example. Additional information about the map units described in this report is available in other soil reports, which give properties of the soils and the limitations, capabilities, and potentials for many uses. Also, the narratives that accompany the soil reports define some of the properties included in the map unit descriptions. Holy Cross Area, Colorado, Parts of Eagle, Garfield, Mesa, Pitkin, and Summit Counties 331C—Woodrock-Angostura families complex, 40 to 65 percent slopes Map Unit Setting National map unit symbol: 1jhbw Elevation: 8,990 to 10,500 feet Map Unit Description: Woodrock-Angostura families complex, 40 to 65 percent slopes---Holy Cross Area, Colorado, Parts of Eagle, Garfield, Mesa, Pitkin, and Summit Counties Natural Resources Conservation Service Web Soil Survey National Cooperative Soil Survey 10/18/2022 Page 2 of 4 Mean annual precipitation: 25 to 40 inches Mean annual air temperature: 32 to 36 degrees F Frost-free period: 30 to 50 days Farmland classification: Not prime farmland Map Unit Composition Woodrock family and similar soils:50 percent Angostura family and similar soils:35 percent Estimates are based on observations, descriptions, and transects of the mapunit. Description of Woodrock Family Setting Landform:Landslides on mountain slopes Down-slope shape:Concave, linear Across-slope shape:Linear Parent material:Colluvium derived from igneous and sedimentary rock Typical profile Oi - 0 to 1 inches: slightly decomposed plant material A - 1 to 2 inches: silt loam E - 2 to 17 inches: loam Bt/E1 - 17 to 28 inches: loam Bt/E2 - 28 to 45 inches: gravelly clay loam C - 45 to 60 inches: sandy loam Properties and qualities Slope:40 to 65 percent Depth to restrictive feature:40 to 72 inches to lithic bedrock Drainage class:Well drained Capacity of the most limiting layer to transmit water (Ksat):Moderately high (0.21 to 0.71 in/hr) Depth to water table:More than 80 inches Frequency of flooding:None Frequency of ponding:None Available water supply, 0 to 60 inches: Moderate (about 8.9 inches) Interpretive groups Land capability classification (irrigated): 7e Land capability classification (nonirrigated): 7e Hydrologic Soil Group: C Ecological site: F048AY918CO - Spruce-Fir Woodland Other vegetative classification: Subalpine fir - Engelmann spruce/elk sedge (ABLA-PIEN/CAGE2) (C0307) Hydric soil rating: No Description of Angostura Family Setting Landform:Landslides on mountain slopes Down-slope shape:Linear, concave Map Unit Description: Woodrock-Angostura families complex, 40 to 65 percent slopes---Holy Cross Area, Colorado, Parts of Eagle, Garfield, Mesa, Pitkin, and Summit Counties Natural Resources Conservation Service Web Soil Survey National Cooperative Soil Survey 10/18/2022 Page 3 of 4 Across-slope shape:Linear Parent material:Colluvium derived from igneous and sedimentary rock Typical profile Oe - 0 to 2 inches: moderately decomposed plant material A1 - 2 to 3 inches: loam A2 - 3 to 9 inches: gravelly silt loam E1 - 9 to 17 inches: very cobbly silt loam E2 - 17 to 22 inches: very cobbly fine sandy loam Bt/E - 22 to 33 inches: extremely cobbly sandy clay loam Bt1 - 33 to 42 inches: extremely cobbly clay loam Bt2 - 42 to 59 inches: very cobbly clay loam Properties and qualities Slope:40 to 65 percent Depth to restrictive feature:40 to 72 inches to lithic bedrock Drainage class:Well drained Capacity of the most limiting layer to transmit water (Ksat):Moderately high (0.21 to 0.71 in/hr) Depth to water table:More than 80 inches Frequency of flooding:None Frequency of ponding:None Available water supply, 0 to 60 inches: Low (about 5.2 inches) Interpretive groups Land capability classification (irrigated): 7e Land capability classification (nonirrigated): 7e Hydrologic Soil Group: C Ecological site: F048AY918CO - Spruce-Fir Woodland Other vegetative classification: Subalpine fir - Engelmann spruce/elk sedge (ABLA-PIEN/CAGE2) (C0307) Hydric soil rating: No Data Source Information Soil Survey Area: Holy Cross Area, Colorado, Parts of Eagle, Garfield, Mesa, Pitkin, and Summit Counties Survey Area Data: Version 5, Sep 7, 2022 Map Unit Description: Woodrock-Angostura families complex, 40 to 65 percent slopes---Holy Cross Area, Colorado, Parts of Eagle, Garfield, Mesa, Pitkin, and Summit Counties Natural Resources Conservation Service Web Soil Survey National Cooperative Soil Survey 10/18/2022 Page 4 of 4 CPX Piceance Holdings, LLC 34 S. Wynden Drive, Suite 240 Limited Impact Review Garfield County, Colorado Houston, TX 77056 TPR Well Pad 36A Article 9 Oil and Gas Permit Application Dust Mitigation Plan COGCC Rule 304.c.(5) DUST MITIGATION PLAN TPR Well Pad 36A November 2022 CPX Piceance Holdings, LLC (CPX) owns and operates Tepee Park Ranch (TPR) in Garfield County, Colorado. CPX has prepared this Dust Mitigation Plan for continued development of the existing Well Pad 36A on TPR. The sections below correspond to Colorado Oil & Gas Conservation Commission (COGCC) Rule 304.c.(5) to prepare a Dust Mitigation Plan consistent with Rule 427. 1.0 Site Location and Access The existing Well Pad 36A is located in the SW ¼ NE ¼ Section 36, Township 7 South, Range 94 West. It is accessed using the following existing access roads: • West on 7th St. and south on Garden Lane in Rifle • West on County Road (CR) 320 (Rifle-Rulison Road) for approximately 3 miles • South on CR 317 for approximately 5.5 miles • South on Forest Service Road 824 (FS 824) for approximately 2.75 miles • South on private Tepee Park Ranch Road for approximately 1.5 miles CR 317 is an improved gravel road maintained by the Garfield County Road and Bridge Department. FS 824 is an improved dirt road maintained by the U.S. Forest Service. CPX uses FS 824 under a road use permit and annual operating agreement issued by the Forest Service. CPX also financed and made significant improvements to the road in 2018 on behalf of the Forest Service. Improvements included rerouting a portion of the road to increase its setback from Beaver Creek, installation of stormwater culverts and diversions, and construction of new trailheads to support public recreation. Existing off-location flowlines are buried in a single trench on CPX land and across Forest Service land under a pipeline easement granted by the Forest Service. The flowlines transport natural gas, condensate, and fresh or produced water between CPX’s Well Pad 25A on TPR and CPX’s Lot 2 Process Tanks in Section 13, Township 7 South, Range 94 West. The flowlines will be extended to Well Pad 36A, which was included in the approved 2A permit for Well Pad 25A. 2.0 Soil Types Soil types associated with the Oil and Gas Location and dirt access roads from the nearest public roadway are listed in Table 1. The soil types are shown on the Soil Unit Map and detailed in the Soil Unit Descriptions submitted with the Form 2A application. Table 1. Soil Types Area Soil Type Description Existing Well Pad 36A Oil and Gas Location 104A: Haplocryolls- Cryaquolls Haplocryolls-Cryaquolls complex, 0 to 15 percent slopes. The A horizon is 0 to 20 inches of silt loam overlaying 20 to 60 inches of silt loam and clay loam to gravelly sandy clay loam. The soil is well drained. The depth to restrictive feature is more than 80 inches. 331C: Woodrock-Angostura Woodrock-Angostura families complex, 40 to 65 percent slopes. The A horizon is 1 to 3 inches of silt loam and loam overlaying 2 to 17 inches of loam and gravelly silt loam. The soil is well drained. The depth to restrictive feature is 40 to 72 inches. CPX Piceance Holdings, LLC Dust Mitigation Plan TPR Well Pad 36A 2 November 2022 Source: Natural Resources Conservation Service, National Cooperative Soil Survey 3.0 Affected Areas Affected areas by soil type are shown in Table 2. The existing Oil and Gas Location is approximately 5.45 acres of existing disturbance. The existing Working Pad Surface is approximately 2.06 acres. Interim reclamation will reduce the well pad size to 1.34 acres. The reclaimed area will be stabilized and revegetated with a certified weed-free seed mix, in accordance with COGCC Rule 1003 and as described in the Interim Reclamation Plan submitted with the Form 2A application. Flowlines were included in the approved 2A permit for Well Pad 25A. Table 2. Affected Areas Area Soil Type Description Existing TPR Access Road 104A: Haplocryolls- Cryaquolls See description above. 220B: Angostura Family Angostura family, 5 to 40 percent slopes. The surface is slightly decomposed plant material. The A horizon is 2 to 3 inches of loam overlaying 3 to 9 inches of loam, 9 to 17 inches of very cobbly loam, and very to extremely cobbly fine sandy, sandy clay, and clay loams to 59 inches. The soil is well drained. The depth to the restrictive feature is more than 60 inches. 338B: Wetopa-Doughspon- Echemoor Wetopa-Doughspon-Echemoor families complex, 5 to 40 percent slopes. The surface is slightly decomposed plant material. The A horizon is 0 to 13 inches of silty clay loam overlaying 13 to 20 inches of silty clay loam and 20 to 45 inches of silty clay. From 45 to 60 inches is cobbly silty clay loam. The soil is well drained. The depth to the restrictive feature is more than 80 inches. 449C: Tampico-Echemoor- Eyre Timpico-Echemoor-Eyre families complex, 30 to 65 percent slopes. The surface is slightly decomposed plant material. The A horizon is 1 to 4 inches of loam overlaying 4 to 24 inches of clay loam and sandy clay loam. From 24 to 60 inches is bedrock. The soil is well drained. The depth to the restrictive feature is more than 60 inches. Area Soil Type Acres Existing Oil and Gas Location 104A: Haplocryolls-Cryaquolls 331C: Woodrock-Angostura 5.01 Existing disturbance 0.90 After interim reclamation 0.44 Existing disturbance 0.44 After interim reclamation Existing TPR Access Road 104A: Haplocryolls-Cryaquolls 220B: Angostura Family 338B: Wetopa-Doughspon-Echemoor 449C: Tampico-Echemoor-Eyre 0.86 0.23 2.36 0.18 3.63 Total CPX Piceance Holdings, LLC Dust Mitigation Plan TPR Well Pad 36A 3 November 2022 The existing TPR Road is 20 feet wide and approximately 7,900 feet long to Well Pad 36A. For dust control, an estimated 500 bbls of fresh water will be used on a per well basis, or 1 6,000 bbls of water. Fresh water will be sourced from the third-party source listed in the Water Plan submitted with the Form 2A application, the Loesch and Crann Ditch Company. This source of freshwater will also be used for dust control using a water truck on access roads, including on FS 824 under the operating agreement with the Forest Service. Proppant used during completions will be hauled to the location in closed containers. The truck will be a semi hauling an aluminum trailer. Three cones on the trailer will be full of proppant, and an air compressor will be used to push the proppant out of the truck. Offloading will occur within secondary containers around the pr oppant storage silos. Dust control will consist of filtering the proppant when loading the truck and filtering again when dispensing the proppant into silos on the location. 4.0 Whether Access Roads are Paved Access from FS 824, the nearest public roadway, will be provided using the existing unpaved TPR Road. 5.0 Anticipated Truck Trips Table 3 lists anticipated truck trips during each phase of development. Semi-trucks will be used to haul heavy equipment. Bobtail trucks will be used to haul freshwater. CPX personnel and contractors will use light-duty trucks to access the Oil and Gas Location. Because Well Pad 36A is constructed, CPX estimates that 1 month will be needed to prepare the well pad for drilling. Well drilling will be an estimated 8 months. Completions will be an estimated 8 months. Interim reclamation will be an estimated 1 month. The wells are expected to produce for 30 years. Table 3. Anticipated Truck Trips 6.0 Best Management Practices Best management practices (BMPs) for dust mitigation are described in Table 4. Table 4. Best Management Practices Best Management Practice Speed Limits • Employees and contractors will observe posted speed limits on public roads and a 25 mile per hour speed limit on TPR access roads. Regular Road Maintenance • Regular inspection will occur for the access road for evidence of inadequate drainage and formation of potholes. Activity Months Truck Trips (Monthly) Truck Trips (Annual) Construction 1 140 140 Drilling 8 630 5050 Completion 8 372 2966 Interim Reclamation 1 24 24 Production 30 years 115 1380 CPX Piceance Holdings, LLC Dust Mitigation Plan TPR Well Pad 36A 4 November 2022 Best Management Practice • Grading, blading, and filling potholes will be performed to maintain the road surface and discourage vehicles from widening the roadway or contributing to erosion. • Spot graveling will be used to avoid erosion, formation of silts, and to stabilize surfaces for truck travel. Restricting Disturbances During High Wind Days • Well pad construction is complete. Further disturbance is not anticipated. Blowing soil and failure of the soil to stabilize and form a crust during interim reclamation will indicate that a dust suppression BMP is needed. In that event, fresh water from an approved water source will be used to wet the surface for control of fugitive dust on the well pad and access road. Dust Suppression • Areas not needed for production will be reclaimed in accordance with Rule 1003. • Fresh water from an approved water source will be used on disturbed surfaces when needed to minimize fugitive dust. Soil Stockpile • Soil stockpiles will be mounded and maintained to prevent loose soils and promote vegetative growth. • Vegetation will be allowed to establish, with hydroseed and mulch, in order to stabilize a stockpile, outcompete weeds, and promote soil microbial activity. Dust Control on Roadways • A water truck will be used to apply freshwater on access roads to minimize fugitive dust. Proppant • Proppant will be hauled in closed containers and offloaded within secondary containment around the proppant storage silos. CPX Piceance Holdings, LLC 34 S. Wynden Drive, Suite 240 Limited Impact Review Garfield County, Colorado Houston, TX 77056 TPR Well Pad 36A Article 9 Oil and Gas Permit Application Transportation Plan COGCC Rule 304.c.(6) kimley-horn.com 4582 South Ulster Street, Suite 1500, Denver, CO 80237 303 228 2300 December 1, 2022 Mr. Nick Kurtenbach, CEO CPX Piceance Holdings, LLC 34 S Wynden Drive Suite 240 Houston, Texas 77056 Re:Pad 36 Basic Traffic Analysis Garfield County, Colorado Dear Mr. Kurtenbach, This letter documents the results of a basic traffic analysis including trip generation, trip distribution, traffic assignment, and intersection analysis for the proposed Pad 36 project located south of Forest Service Road 824 (FS-824) near Beaver Creek, approximately 10 miles south of Rifle in Garfield County, Colorado. A vicinity map is attached in Figure 1. A conceptual site plan with the project location is attached. Pad 36 is already constructed but requests to drill wells on the parcel. Duration of construction activity for the gas wells are all follows: · Construction: 4 weeks · Drilling: 32 weeks · Completions: 32 weeks · Interim Reclamation: 4 weeks · Production Operations: 30 years Construction is planned to begin in the third quarter of 2023. The peak construction traffic activity is anticipated to occur during the drilling and completions phases, which is anticipated to begin in the first quarter of year 2024. The lifespan of the gas well is 30 years but is typically not anticipated to generate significant trips outside of the construction, drilling, completions, and reclamation activities occurring in the first two years. The drilling and completions activities will have an overlap and are expected to generate the highest volume of trips during these activities; therefore, analysis was conducted for the 2024 year during the peak drilling and completions activity. The purpose of this basic traffic analysis is to identify project traffic generation characteristics to determine potential project traffic related impacts at the nearest proximate intersections with State/Federal Highways or county roads likely to receive traffic impact from the development in accordance with Garfield County standards and requirements. However, there are not any State or Federal Highways near the project site with I-70 being located more than 10 miles from the project site. The nearest county road intersection of CR-320 and CR-317, located approximately nine (9) miles from the project site, was incorporated into this traffic study in accordance with Garfield County standards and requirements. Regional access to Pad 36 will be provided by Interstate 70 (I-70). Primary access will be provided by Rifle-Rulison Road (CR-320), CR-317, and FS-824. Direct access will be provided from a private access along Tepee Park Ranch Road. Pad 36 196635000 Page 2 kimley-horn.com 4852 South Ulster Street, Suite 1500, Denver, CO 80237 303 228 2300 EXISTING ROADWAY NETWORK Rifle-Rulison Road (CR-320) extends mostly in the north/south direction with some intersections oriented with Rifle-Rulison Road (CR-320) as the east/west roadway. Rifle-Rulison Road (CR-320) provides one through lane in each direction with no exclusive turn lanes being provided at any intersections. It has a posted speed limit of 35 miles per hour. Beaver Creek Road (CR-317) extends in the north/south direction, southwest of Rifle-Rulison Road (CR-320). Beaver Creek Road (CR-317) provides one through lane in each direction with a posted speed limit of 35 miles per hour. The intersection of Rifle-Rulison Road (CR-320) and Beaver Creek Road (CR-317) operates with stop control on the northbound Beaver Creek Road (CR-317) approach. The three intersection approaches all provide a single lane shared for all movements. For the analysis, Rifle-Rulison Road (CR-320) was analyzed as the east/west street. An aerial photo that illustrates the existing intersection configuration is below (north is up – typical). Rifle-Rulison Road (CR-320) & Beaver Creek Road (CR-317) The intersection lane configuration and control for this study area intersection is shown in attached Figure 2. EXISTING AND HISTORICAL TRAFFIC VOLUMES Existing weekday morning and afternoon peak hour counts were conducted at the CR-320 / CR-317 intersection on Tuesday, February 8, 2022. The counts were conducted during the morning and afternoon peak hours of adjacent street traffic in 15-minute intervals from 7:00 AM to 9:00 AM and 4:00 PM to 6:00 PM on this count date. The existing intersection traffic volumes are also shown in attached Figure 3 with count sheets attached. Historical daily traffic volumes provided from Garfield Field Road Pad 36 196635000 Page 3 kimley-horn.com 4852 South Ulster Street, Suite 1500, Denver, CO 80237 303 228 2300 & Bridge indicated that CR-317 had an average daily traffic volume of 768 vehicles per day in 2014 and 102 vehicles per day in 2019 south of CR-320. TRIP GENERATION Site-generated traffic estimates are determined through a process known as trip generation. Rates and equations are applied to the proposed land use to estimate traffic generated by the development during a specific time interval. Trip generation was developed based on user provided information. As stated previously, the peak construction traffic activity overlaps during the drilling and completion phases. The client specified that the trucks associated with the drilling phase occurs heavily during the beginning of the phase and tapers to less trips until the end of the duration. Therefore, the drilling phase is separated into a higher volume of vehicle trips only for the first couple of weeks and trips associated with the completions phase to provide a conservative analysis. The trips are anticipated to operate 24 hours a day for a conservative five days a week. Therefore, the employees in passenger vehicles/pickup trucks were assumed to arrive in two shifts with these beginning and ending in the studied morning and afternoon peak hours to provide a conservative analysis. The trucks are anticipated to be uniformly distributed throughout the day. This approach is conservative given the actual operations and timing of phases may not end up overlapping. The following Table 1 summarizes the estimated peak trip generation for the development (calculations attached). Table 1 – Pad 36 Peak Traffic Generation Use Weekday Peak Vehicles Trips Daily AM Peak Hour PM Peak Hour In Out Total In Out Total Pad 36 Drilling and Completions (Peak Traffic Operations) Passenger Vehicles 60 15 15 30 15 15 30 Trucks 124 3 3 6 3 3 6 Total Trips 184 18 18 36 18 18 36 As shown in the table, during the peak drilling and completion operations, Pad 36 is anticipated to generate approximately 184 weekday daily trips, with 36 of these trips occurring during each of the morning and afternoon peak hours. TRIP DISTRIBUTION AND TRAFFIC ASSIGNMENT The distribution of traffic is a means to quantify the percentage of site-generated traffic that approaches the site from a given direction and departs the site back to the original source. It is anticipated that most, if not all, traffic will be to and from the north where the Town of Rifle and access to I-70 are located. Attached Figure 4 illustrates the trip distribution and the traffic assignment for this project by multiplying the project trip generation shown in Table 1 with the trip distribution. TOTAL (BACKGROUND PLUS PROJECT) TRAFFIC Site traffic volumes were added to the background volumes to represent estimated total traffic conditions for the 2024 horizon. The background traffic volumes included a one (1) percent annual traffic growth rate plus traffic associated with the South Leverich 13-09 Pad, Honea 19-05 Pad, and WMC 24-17 Pad. These total traffic volumes for the study area are illustrated for the 2024 horizon in attached Figure 5. A comparison of existing average daily traffic volumes and daily truck volumes to project daily traffic volumes and project daily truck volumes is shown in attached Figure 6. Traffic along CR-317 south of CR-320 is anticipated to increase by more than 20 percent during peak drilling and completions temporary operations; however, the ultimate site operations is expected to increase traffic Pad 36 196635000 Page 4 kimley-horn.com 4852 South Ulster Street, Suite 1500, Denver, CO 80237 303 228 2300 volumes by lower than 20 percent. There are currently very low traffic volumes at the intersection of CR-320 and CR-317, and this intersection has significant reserved capacity to accommodate project traffic. CONCLUSIONS AND RECOMMENDATIONS Based on the traffic analysis presented in this report, Kimley-Horn and Associates, Inc. believes traffic volumes from the addition of the Pad 36 will be successfully incorporated into the existing roadway network. Pad 36 is anticipated to generate approximately 184 weekday daily trips, with 36 of these trips occurring during each of the morning and afternoon peak hours. No improvements or recommendations are anticipated to be needed at the surrounding roadways based on the peak construction period of Pad 36 due to very low traffic volumes currently on CR-317 and CR-320 and this project being a low peak hour and daily traffic generator. If you have any questions or require anything further, please feel free to call me at (720) 943-9962. Sincerely, KIMLEY-HORN AND ASSOCIATES, INC. Jeffrey R. Planck, P.E. Project Manager 12/01/2022 FiguresFiguresFigures NCORTF NTS 196635000 a. NASR 320) A oe FIGURE 1 PAD 36 GARFIELD COUNTY, COLORADO VICINITY MAP Kimley»»Horn NCORTF NTS 196635000 a. NASR 320) A oe FIGURE 1 PAD 36 GARFIELD COUNTY, COLORADO VICINITY MAP Kimley»»Horn ho” NORTF NTS 196635000 + + hy CA C CR-317 & CR-320 = c Ww re) | > ( LEGEND © Study Area Key Intersection Stop Controlled Approach Roadway Speed Limit FIGURE 2 PAD 36 GARFIELD COUNTY, COLORADO EXISTING GEOMETRY AND CONTROL Kimley»»Horn}+~ 1) | <—5(25) « 6(6) ‘ ( 21(7) > |S co 2(0) | ~ © Ne wy C CR-317 & CR-320 ) Tuesday, February 8, 2022 7:00 to 8:00AM (4:30 to 5:30PM) LEGEND ) Study Area Key Intersection Weekday AM(PM) XXX(XXX) : Peak Hour Traffic Volumes Estimated Daily Traffic Volume FIGURE 3 PAD 36 GARFIELD COUNTY, COLORADO 2022 EXISTING TRAFFIC VOLUMES 3.5 mi /\\ /\ \J \X ho” NORTH NTS 196635000 Kimley»»Horn}+~ 6(6) 5(25) 2(0) 21(7)6(5)1(0)1 DISTRIBUTION (1) >) -— 100% t yy, C CR-317 & CR-320 ) ASSIGN (1) > _— 18(18) L Ne wy C CR-317 & CR—-320 ) LEGEND Entering[ Exiting] XXX(XXX FIGURE 4 PAD 36 (x) Study Area Key Intersection XXF[XX%] yi Distribution Percentage ) Weekday AM(PM) Peak Hour Traffic Volumes XxX,x00] Estimated Daily Traffic Volume XX%__ External Trip Distribution Percentage GARFIELD COUNTY, COLORADO PROJECT TRIP DISTRIBUTION AND’ TRAFFIC = c Ww re) | > ( ASSIGNMENT ho” NORTH NTS 196635000 Kimley»»Horn}+~ 18(18)18(18)1 100%[100%] ho” NORTH NTS 196635000 LA CR-317 & CR-320 aa 3.5 mi /\ \J \X LEGEND ) Study Area Key Intersection Weekday AM(PM) XXX(XXX) : Peak Hour Traffic Volumes Estimated Daily Traffic Volume FIGURE 5 PAD 36 GARFIELD COUNTY, COLORADO 2024 TOTAL TRAFFIC VOLUMES \ Kimley»»Horn}+~ 41(27) 5(25) 2(0) 21(7)27(40)1(0)1 ho” NORTH NTS 196635000 1) | <—5(25) -—- 41(27) ‘ ( 21(7) > |S e 20)" Ne wy C CR-317 & CR-320 ) LEGEND Study Area Key Intersection 2022 Daily Traffic Volume Daily Project Traffic Volume XX,X00} 2022 Daily Truck Volume Daily Project Truck Volume FIGURE 6 PAD 36 GARFIELD COUNTY, COLORADO 2022 EXISTING DAILY TRAFFIC COMPARISON TO PROJECT TRAFFIC \ Kimley»»Horn}+~ 41(27) 5(25) 2(0) 21(7)27(40)1(0)1 Intersection Count SheetsIntersection Count SheetsIntersection Count Sheets www.idaxdata.com to to Two-Hour Count Summaries Note: Two-hour count summary volumes include heavy vehicles but exclude bicycles in overall count. Total 0 0 0 0 0 0 0 4 4 00000000 2 0 Peak Hr 1 0 1 3 5 0 0 0 0 0 0 2 0Count Total 2 0 2 4 8 0 0 2 00000028:45 AM 0 0 0 0 0 0 0 0 0 0 0 0 8:30 AM 0 0 1 0 1 0 0 0 0 0 0 0 0 0 0 0 8:15 AM 1 0 0 1 2 0 0 0 0 0 0 0 0 0 0 0 8:00 AM 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 7:30 AM 0 0 0 1 1 0 0 0 0 0 0 0 0 0 0 0 0 EB WB NB SB Total East 7:45 AM 1 0 1 2 4 0 0 0 -100%0%HV%-0%-50%- 0 0 7:15 AM 0 0 0 0 0 0 0 0 0 0 0 0 0 West North South 7:00 AM 0 0 0 0 1 6 0 0 0 6200000 0 Interval Start Heavy Vehicle Totals Bicycles Pedestrians (Crossing Leg) EB WB NB SB Total ---17%40%12%--- Peak Hour All 0 21 0 0 0 2 8 0 0 0 0 1 2 5 0000100 5 41 0 HV 0 0 0 1 0 Count Total 0 36 0 2 0 0 0 0 14 12 74 0 5 33000002000000 0 2 2 9 36 8:45 AM 0 3 0 0 0 0 1 1 0 0 11 39 8:30 AM 0 3 0 0 0 0 0 0 0 0 0 4 2000000 0 2 1 8 40 8:15 AM 0 5 0 0 0 0 0 1 0 0 8 41 8:00 AM 0 4 0 0 0 0 0 0 0 0 0 3 2000001 0 3 1 12 0 7:45 AM 0 1 0 1 0 0 0 4 0 0 12 0 7:30 AM 0 4 0 0 0 0 0 0 0 0 0 0 1000000 0 0 1 9 0 7:15 AM 0 10 0 1 0 0 0 2 0 07:00 AM 0 6 0 0 0 0 0 Rolling One HourEastboundWestboundNorthboundSouthbound UT LT TH RT Interval Start RIFLE RULISON RD (CR 320)N/A BEAVER CREEK RD (CR 317)RIFLE RULISON RD (CR 320)15-min TotalUTLTTHRT SB 27.3%0.55 TOTAL 12.2%0.85 TH RTUTLTTHRTUTLT WB -- NB 14.3%0.44 Peak Hour: 7:00 AM 8:00 AM HV %:PHF EB 4.3%0.52 Date: 02/08/2022 Peak Hour Count Period: 7:00 AM 9:00 AM 0 0 00000 00 0N BEAVER CREEK RD (CR 317) RIFLE RULISON RD (CR 320)RIFLE RULISON RD (CR 320)BEAVER CREEK RD (CR 317)RIFLE RULISON RD (CR 320) 41TEV: 0.85PHF:5611270617802 2123 6 0 Project Manager: (415) 310-6469 project.manager.ca@idaxdata.com www.idaxdata.com Two-Hour Count Summaries - Heavy Vehicles Two-Hour Count Summaries - Bikes Note: U-Turn volumes for bikes are included in Left-Turn, if any. 0 0 0000000Peak Hour 0 0 0 0 0 0 0 0 0 0 0Count Total 0 0 0 0 0 0 0 0 0000000 0 0 8:45 AM 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 8:30 AM 0 0 0 0 0 0 0 0 0 0 0 08:15 AM 0 0 0 0 0 0 0 0 0 0 0 0 8:00 AM 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 7:45 AM 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 7:30 AM 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 7:15 AM 0 0 0 0 0 0 0 0 0 0 0 TH RT LT TH RT 7:00 AM 0 0 0 0 Westbound Northbound Southbound LT TH RT LT TH RT LT 5 0 Interval Start RIFLE RULISON RD (CR 320)N/A BEAVER CREEK RD (CR 317)RIFLE RULISON RD (CR 320)15-min Total Rolling One HourEastbound 0 0 0 0 1 2000001 0 2 2 8 0 Peak Hour 0 0 0 1 0 0 1 1 0 0Count Total 0 1 0 1 0 0 0 0 3000000000000 0 0 0 1 7 8:45 AM 0 0 0 0 0 0 0 1 0 0 2 7 8:30 AM 0 0 0 0 0 0 0 0 0 0 0 1 0000000 0 0 0 0 5 8:15 AM 0 1 0 0 0 0 0 0 0 0 4 5 8:00 AM 0 0 0 0 0 0 0 0 0 0 0 1 1000001 0 0 1 1 0 7:45 AM 0 0 0 1 0 0 0 0 0 0 0 0 7:30 AM 0 0 0 0 0 0 0 0 0 0 0 0 0000000 0 0 0 0 0 7:15 AM 0 0 0 0 0 0 0 0 0 0 TH RT 7:00 AM 0 0 0 0 0 0 0 UT LT TH RT UT LT Northbound Southbound UT LT TH RT UT LT TH RT Interval Start RIFLE RULISON RD (CR 320)N/A BEAVER CREEK RD (CR 317)RIFLE RULISON RD (CR 320)15-min Total Rolling One HourEastboundWestbound Project Manager: (415) 310-6469 project.manager.ca@idaxdata.com www.idaxdata.com to to Two-Hour Count Summaries Note: Two-hour count summary volumes include heavy vehicles but exclude bicycles in overall count. Total 0 0 0 0 0 0 0 0 0 00000000 0 0 Peak Hr 0 0 0 1 1 0 0 0 0 0 0 0 0Count Total 0 0 0 2 2 0 0 0 00000005:45 PM 0 0 0 1 1 0 0 0 0 0 0 0 5:30 PM 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 5:15 PM 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 5:00 PM 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 4:30 PM 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 EB WB NB SB Total East 4:45 PM 0 0 0 1 1 0 0 0 --0%HV%-0%--- 0 0 4:15 PM 0 0 0 0 0 0 0 0 0 0 0 0 0 West North South 4:00 PM 0 0 0 0 0 5 0 0 0 6000000 0 Interval Start Heavy Vehicle Totals Bicycles Pedestrians (Crossing Leg) EB WB NB SB Total ---0%3%2%--- Peak Hour All 0 7 0 0 0 0 10 0 0 0 0 0 1 1 0000000 29 47 0 HV 0 0 0 0 0 Count Total 0 14 0 0 0 0 0 0 14 45 83 0 10 38000018000000 0 1 3 9 44 5:45 PM 0 1 0 0 0 0 0 4 0 0 12 47 5:30 PM 0 1 0 0 0 0 0 2 0 0 0 1 7000000 0 0 6 7 40 5:15 PM 0 2 0 0 0 0 0 0 0 0 16 45 5:00 PM 0 1 0 0 0 0 0 1 0 0 0 3 10000000 0 2 6 12 0 4:45 PM 0 2 0 0 0 0 0 2 0 0 5 0 4:30 PM 0 2 0 0 0 0 0 0 0 0 0 1 1000000 0 5 4 12 0 4:15 PM 0 3 0 0 0 0 0 1 0 04:00 PM 0 2 0 0 0 0 0 Rolling One HourEastboundWestboundNorthboundSouthbound UT LT TH RT Interval Start RIFLE RULISON RD (CR 320)N/A BEAVER CREEK RD (CR 317)RIFLE RULISON RD (CR 320)15-min TotalUTLTTHRT SB 2.9%0.67 TOTAL 2.1%0.73 TH RTUTLTTHRTUTLT WB -- NB 0.0%0.63 Peak Hour: 4:30 PM 5:30 PM HV %:PHF EB 0.0%0.88 Date: 02/08/2022 Peak Hour Count Period: 4:00 PM 6:00 PM 0 0 00000 00 0N BEAVER CREEK RD (CR 317) RIFLE RULISON RD (CR 320)RIFLE RULISON RD (CR 320)BEAVER CREEK RD (CR 317)RIFLE RULISON RD (CR 320) 47TEV: 0.73PHF:29635120505600 77 29 0 Project Manager: (415) 310-6469 project.manager.ca@idaxdata.com www.idaxdata.com Two-Hour Count Summaries - Heavy Vehicles Two-Hour Count Summaries - Bikes Note: U-Turn volumes for bikes are included in Left-Turn, if any. 0 0 0000000Peak Hour 0 0 0 0 0 0 0 0 0 0 0Count Total 0 0 0 0 0 0 0 0 0000000 0 0 5:45 PM 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 5:30 PM 0 0 0 0 0 0 0 0 0 0 0 05:15 PM 0 0 0 0 0 0 0 0 0 0 0 0 5:00 PM 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 4:45 PM 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 4:30 PM 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 4:15 PM 0 0 0 0 0 0 0 0 0 0 0 TH RT LT TH RT 4:00 PM 0 0 0 0 Westbound Northbound Southbound LT TH RT LT TH RT LT 1 0 Interval Start RIFLE RULISON RD (CR 320)N/A BEAVER CREEK RD (CR 317)RIFLE RULISON RD (CR 320)15-min Total Rolling One HourEastbound 0 0 0 0 0 1000000 0 0 2 2 0 Peak Hour 0 0 0 0 0 0 0 0 0 0Count Total 0 0 0 0 0 0 0 1 1000001000000 0 0 0 0 1 5:45 PM 0 0 0 0 0 0 0 0 0 0 0 1 5:30 PM 0 0 0 0 0 0 0 0 0 0 0 0 0000000 0 0 0 0 1 5:15 PM 0 0 0 0 0 0 0 0 0 0 1 1 5:00 PM 0 0 0 0 0 0 0 0 0 0 0 0 1000000 0 0 0 0 0 4:45 PM 0 0 0 0 0 0 0 0 0 0 0 0 4:30 PM 0 0 0 0 0 0 0 0 0 0 0 0 0000000 0 0 0 0 0 4:15 PM 0 0 0 0 0 0 0 0 0 0 TH RT 4:00 PM 0 0 0 0 0 0 0 UT LT TH RT UT LT Northbound Southbound UT LT TH RT UT LT TH RT Interval Start RIFLE RULISON RD (CR 320)N/A BEAVER CREEK RD (CR 317)RIFLE RULISON RD (CR 320)15-min Total Rolling One HourEastboundWestbound Project Manager: (415) 310-6469 project.manager.ca@idaxdata.com Client Provided DataClient Provided DataClient Provided Data Pad 36 Duration (Days) Number of Semi-Trucks (ST) Number of Pickup Trucks (PT) Total Number of Trucks Total Semi- Truck Trips Total Pickup Truck Trips Total Daily Semi-Truck Trips Total Daily Pickup Truck Trips Time Frame 5 day work week # ST + # PT # ST * 2 # PT * 2 Total ST Trips / # ST Total PT Trips / # PT Construction 4 20 30 110 140 60 220 4 12 Q3 2023 Drilling1 8 40 2,137 2,137 4,274 108 0 Q1 2024 Drilling 32 160 713 2,200 2,913 1,426 4,400 10 28 Q2 2024 Completion 32 160 446 2,520 2,966 892 5,040 6 32 Q2 2024 Interim Reclaim 4 20 4 20 24 8 40 2 2 2025 Production 1,560 (30 yrs) 7,800 755 625 1,380 1,510 1,250 2 2 2025 1Most of the heavy vehicle trips will occur during the first couple of weeks of the overall 32 week duration and then taper off towards the end of the duration. Development Phase Weeks Surfacing Length (mi.) Pavement 3 Partially Paved 5.5 Unpaved 2.75 Unpaved 1.5 Development Phase Number of Semi-Trucks Number of Pickup Trucks Total Truck Trips Construction 30 110 140 Drilling 2,850 2,200 5,050 Completion 446 2,520 2,966 Interim Reclaim 4 20 24 Production 755 625 1,380 Total 4,085 5,475 9,560 CR-320 Name Estimated Truck Trips per Phase Pad 36A Route Segments CPX Tepee Park Ranch (Private) FS 824 CR-317 Site PlanSite PlanSite Plan BeaverCreekT ep e e C r e e k C R 3 1 7 FS824B e a v er C re e k M a m m C re e kR d Pad 25A Pad 31B Pad 25B Pad 36A Pad 2 WESTEASTTepee Park Ranch Road WHITE RIVER NATIONAL FOREST WHITE RIVER NATIONAL FOREST JOHNSON, R M REVOCABLE TRUST TEP ROCKY MOUNTAIN LLC ROSE, JAMES L TEP ROCKY MOUNTAIN LLCBAUER, GEORGE R WHITE RIVER NATIONAL FOREST TEP ROCKY MOUNTAIN LLC WHITE RIVER NATIONAL FOREST BAUER, GEORGE R WHITE RIVER NATIONAL FOREST FISCHER, JOEL & CINDY MACKLEY, ARNOLD L & E DARLEEN UNITED STATES OF AMERICA BUREAU OF LAND MANAGEMENT MORGAN, RICHARD D & KAY D B & B SIX ACRES LLC BARRETT, THOMAS JOHNNY DOTSON FAMILY TRUST &BUREAU OF LAND MANAGEMENT LULU TRUST MCKEE, ROLAND PAUL & PAMELA S TEP ROCKY MOUNTAIN LLC ENTRUST RETIREMENT SERVICES INC-FBO DAVID ADLER IRA# 13618-11 MCKEE, ROLAND PAUL & PAMELA S BUREAU OF LAND MANAGEMENT GORDMAN LEVERICH LLLP TEP ROCKY MOUNTAIN LLC YOUBERG BEAVER CREEK RANCH YOUBERG BEAVER CREEK RANCH BUREAU OF LAND MANAGEMENT BEAVER CREEK HIGHLANDS LAND AND CATTLE TRUST GORDMAN LEVERICH, LLP1416 13 15 21 22 2423 262827 25 353433 36 18 1617 2120 19 283029 333231 6 5 4 87 9 1234 1291011 T7S R94WT7S R93WT7S R94WT8S R93WT7S R94W T8S R94W T7S R93W T8S R93W T8S R93WT8S R94WT8SR93WT8SR94WWest Mamm CreekBrush CreekProject Location MesaMesa CountyCounty GarfieldGarfield CountyCounty 13 6 70 RifleRifle CPX Piceance Holdings, LLC Tepee Park Ranch Aota Technical, LLC CPX Surface Ownership and Mineral Leasehold Map Date 6/7/22 Figure 1 Figure No. 0 0.5 10.25 Miles Legend Existing Drilling Pad Proposed Pad Off-Location Flowlines Proposed Off-location Flowlines Parcel Boundary CPX Private Surface CPX Federal Mineral Leasehold Bureau of Land Management U.S. Forest Service Forest Service Road Private Road Private Road Reroute and Access Reclaimed Private Road Proposed Access Pad 25 Bottom Hole Locations Pad 31 Bottom Hole Locations Pad 36 Bottom Hole Locations CPX Piceance Holdings, LLC 34 S. Wynden Drive, Suite 240 Limited Impact Review Garfield County, Colorado Houston, TX 77056 TPR Well Pad 36A Article 9 Oil and Gas Permit Application Operations Safety Management Plan COGCC Rule 304.c.(7) OPERATIONS SAFETY MANAGEMENT PROGRAM TPR Well Pad 36A November 2022 CPX Piceance Holdings, LLC (CPX) owns and operates Tepee Park Ranch (TPR) in Garfield County, Colorado. CPX has prepared this Operations Safety Management Program for continued development of the existing Well Pad 36A on TPR. The sections below correspond to Colorado Oil & Gas Conservation Commission (COGCC) Rule 304.c.(7) to prepare an Operations Safety Management Program consistent with Rule 602.d and with COGCC Operations Safety Management Program Guidance (February 16, 2021). 1.0 Change Management Program The purpose of the Change Management Program is to provide for proper planning, execution, and documentation of changes to the Oil and Gas Location. It is an organized process to guide changes to operations and equipment in order to reduce risks and unintended consequences. The Change Management Program is described in Table 1 and in the attached checklist . Table 1. Change Management Program Activity Procedure Procedure for Change Documentation Changes to technology, equipment, procedures, or operations will be documented using (1) a change review meeting between subject matter experts and the principal authorized to approve the change, and (2) a Change Management Checklist (attached). Subject matter experts are managers and principals responsible for Engineering Design and Operations. Records Storage Location CPX will maintain records in hard and electronic files in its Houston, Texas and Rifle, Colorado offices. Records Storage Duration CPX will maintain change management records for a minimum of 5 years. Record Availability CPX will make records available for inspection within 14 days of a request for review. Record Updates CPX will review records annually for information that requires updates. Records will be replaced when necessary, such as parts replacement. Basis and Purpose for Change The Change Management Checklist will be used during an internal change management review that documents the basis and purpose for a change. Typical changes are installation of new equipment, a significant modification to existing equipment, or a significant change in operations. Identifying Potential Impacts The Change Management Checklist will be used to record potential impacts to public health, safety, welfare, and the environment resulting from the change, including beneficial impacts and impacts that may occur from not implementing the change. Consideration of impacts can include air emissions, vehicle operations, stormwater controls, leak detection and spill prevention, and any updates needed for training or inspections. CPX Piceance Holdings, LLC Operations Safety Management Program TPR Well Pad 36A 2 November 2022 Activity Procedure Approval for Changes The Operations Manager is expected to be the primary source to recommend parts or configuration changes for site operations. Changes more significant than basic maintenance will be approved by the CPX Principal. Permanent v. Temporary Change Temporary changes will be designated as temporary on the Change Management Checklist. Duration for Temporary Changes The duration for temporary changes will be identified on the Change Management Checklist for follow up. 2.0 Pre-start Up Safety Review (PSSR) Pre-Start Up Safety Review procedures are listed in the attached checklist. The Operations Manager will review the list with support from the Field Operator and any technical experts (e.g., manufacturer’s representative) as part of facility readiness for new equipment, modified equipment, a new operation, or significant operational change. Review will include features that may represent a risk to the operator, public health, safety, or the environment. Findings will become part of the site records. Subsequent changes to well operations or the location will receive similar review. During pre-start up, newly installed equipment or significantly modified equipment will be inspected before placing the equipment into operation. Inspections will be performed by the Operations Manager, Field Operator, and any associated subject matter expert, like the manufacturer’s representative. Personnel will review the installation against design specifications. They will review and train on operating, maintenance, and safety procedures, including emergency shut offs. They will conduct a site walk and inspection to ensure proper installation necessary function testing. 3.0 Pre-start Up Safety Review (PSSR) The following best management practices will help to implement change management and the PSSR program: Table 2. Best Management Practices Best Management Practice • The Field Operator will receive training for operation, monitoring, and maintenance specific to any changes at the location. • Prior to new operations, the Operations Manager will review site readiness with the Field Operator. Review will include wellheads and valving, process tanks and piping, instrumentation and meters, isolation valves and shutoffs, well pad maintenance, access roads, flowlines, and site safety and security. Potential for risk to public health, safety, welfare, or the environment will be discussed at that time. Discussion will identify whether adjustment is needed for resources, materials, or practices to minimize potential risks. Significant changes will be documented as part of change management for the location. • Contractors and vendors working on the location will be supervised by the Operations Manager or Field Operator when it is necessary to do so to maintain safe operations. • The Operations Manager will be responsible for recommendations to improve operation of the site to avoid impacts to public health, safety, welfare, and the environment. Significant changes will require approval from the CPX Principal. CPX Piceance Holdings, LLC Operations Safety Management Program TPR Well Pad 36A 3 November 2022 Best Management Practice • Vendor sheets and invoices will be attached to the Change Management Checklist where needed to describe changes at the location. • CPX’s standard health and safety practices will be used to supplement the information provided in this Plan. Attachments Change Management Checklist Pre-Start Up Safety Review Checklist CPX Piceance Holdings, LLC Operations Safety Management Program TPR Well Pad 36A 4 November 2022 CHANGE MANAGEMENT CHECKLIST LOCATION NAME: COGCC LOCATION ID: DATE CHANGE OCCURRED: DESCRIPTION OF CHANGE: BASIS AND PURPOSE OF CHANGE: POTENTIAL IMPACTS (To public health, safety, welfare, the environment. Include beneficial impacts. Include impacts that may occur if the change is not implemented. Continue on the reverse, if necessary): Check All That Apply ☐ The change is temporary. Specify duration: ______________________________________________ ☐ Updates are needed for training or inspection procedures. Specify: ____________________________ _________________________________________________________________________________ _________________________________________________________________________________ ☐ The change is documented. Specify documentation and location: _____________________________ _________________________________________________________________________________ Employee Name / Title: Employee Signature: Date: Approver Name / Title: Approver Signature: Date: CPX Piceance Holdings, LLC Operations Safety Management Program TPR Well Pad 36A 5 November 2022 PRE-START UP SAFETY REVIEW CHECKLIST LOCATION NAME: COGCC LOCATION ID: DATE OF PRE-START UP SAFETY REVIEW: START UP IS (Circle One): New Operation Modification To Existing EQUIPMENT CHECK (Check All That Apply, Review Method, and Findings) Visual Function/Pressure Test Calibration  Wellheads and Valving:  Process Tanks and Piping:  Instrumentation and Meters:  Isolation Valves and Shutoffs:  Flowlines and Combustor:  Signage and Labeling:  Material Storage:  Spill Response Material:  Stormwater Controls: Employee Name / Title: Employee Signature: Date: CPX Piceance Holdings, LLC 34 S. Wynden Drive, Suite 240 Limited Impact Review Garfield County, Colorado Houston, TX 77056 TPR Well Pad 36A Article 9 Oil and Gas Permit Application Emergency Response Plan COGCC Rule 304.c.(8) PREPARED BY: CPX Piceance Holdings, LLC 34 S. Wynden Dr., Suite 240 Houston, TX 77056 November 2022 Rev.2 Emergency Response Plan CPX Piceance Holdings, LLC Tepee Park Ranch Garfield County, Colorado Emergency Response Plan CPX Piceance Holdings, LLC Tepee Park Ranch 1 November 2022 1.0 INTRODUCTION CPX Piceance Holdings, LLC (CPX) prepared an Emergency Response Plan (Plan) in February 2022 for the continued drilling and production of natural gas on Well Pad 25A on Tepee Park Ranch (TPR). CPX updated the Plan in June 2022 as Revision 1 (”Rev.1”) to incorporate a Temporary Water Support Pad 25B. This Revision 2 (“Rev.2”) to the Plan adds drilling and production of natural gas wells on CPX’s existing Pad 36A on TPR. Pad 36A is a previously constructed well pad. At full build out, it will contain a total of 32 natural gas wells. TPR is privately owned and operated by CPX. Locations of the pads described above are shown in Table 1. Table 1. Pad Locations Well Pad 25A Temporary Water Support Pad 25B Well Pad 36A Lat 39.404522 39.404901 39.395017 Lon -107.832789 -107.831352 -107.831908 This Plan addresses the requirement from the Colorado Oil & Gas Conservation Commission (COGCC) at Rule 304.c.(8) to prepare an Emergency Response Plan and to coordinate its approval with the local emergency response agency. Specifically, COGCC guidance (February 16, 2021) requires that the Plan contain the information listed in Table 1. Table 2. Required Content for the Emergency Response Plan 1 Local response agency and contact information 2 Date the plan was finalized and approved by the local response agency 3 Directions to the location from the nearest public road intersection 4 Ingress and egress information 5 Legal description (quarter section, township, range, latitude, longitude) 6 Operator and staff emergency contact information 7 Listing of mutual aid agencies 8 Staffing of local and mutual aid agencies 9 Description of site setting including the surrounding area 10 Detailed layout of the Oil & Gas Location 11 Detailed description of the equipment and stored material 12 Sensitive areas 13 Potential impacts, prevention, and mitigation 14 Response equipment, instruments, materials 15 Health and safety action levels, decontamination, staging areas Emergency Response Plan CPX Piceance Holdings, LLC Tepee Park Ranch 2 November 2022 REPONSE PLAN ELEMENTS 1. LOCAL RESPONSE AGENCY Table 2. Local Response Agency and Contact Agency Contact Contact Information Garfield County Sheriff’s Office 107 8th St., Glenwood Springs, CO 81601 Chris Bornholdt Emergency Operations Manager (970) 945-0453 cbornholdt@garcosheriff.com 2. DATE THE PLAN WAS FINALIZED AND APPROVED This Emergency Response Plan was coordinated with the local response agency. Appendix A demonstrates the coordination activity and local response. 3. DIRECTIONS TO THE LOCATION Directions to TPR well pads from 7th St South and Taugenbaugh Blvd. in Rifle: West on 7th St. South L on Garden Lane R on CR 320 At the fork, L on CR 317 for approximately 5.5 miles Continue south on FS 824 mile for approximately 2.75 miles to the TPR gate Continue south on private TPR road for approximately 0.6 mile to Pad 25B, 0.8 mile to Pad 25A, and 1.5 miles to Pad 36A 4. INGRESS AND EGRESS INFORMATION Ingress TPR is accessed through a secured gate at the southern terminus of FS 824. Gate access is provided by CPX Operations Manager, Bryan Clark, whose contact information is shown in Table 4. Egress The private TPR road is approximately 20’ wide. Pad 25A is approximately 2.6 acres. Pad 25B is approximately 1.8 acres. Pad 36A is approximately 2.1 acres. There is sufficient turn-around for emergency vehicles and equipment. Emergency Response Plan CPX Piceance Holdings, LLC Tepee Park Ranch 3 November 2022 5. LEGAL DESCRIPTION Table 3. Legal Description Qtr Qtr SW ¼ SE ¼ SW ¼ NE ¼ Section 25 36 Township 7 South 7 South Range 94 West 94 West County Garfield Garfield 25A 25B 36A Lat 39.404522 39.404901 39.395017 Lon -107.832789 -107.831352 -107.831908 6. OPERATOR AND STAFF EMERGENCY CONTACT INFORMATION Table 4. Operator Contact Information Operator and Staff Contact Principal Nick Kurtenbach (720) 233-8275 nick@cpxpiceance.com Operations Manager Bryan Clark (970) 987-2220 bryan@cpxpiceance.com 7. MUTUAL AID AGENCY Colorado River Fire Rescue – Station 41 1850 Railroad Ave., Rifle, CO 81650 Orrin Moon, Fire Marshall orrin.moon@crfr.us Office (970) 379-2932 (Cell) 8. STAFFING OF LOCAL AND MUTUAL AID AGENCIES Colorado River Fire Rescue is a fire protection district. It is staffed by a combination of approximately 41 full-time, 9 part-time, and 13 volunteer staff. Under normal conditions, the district maintains three staffed and two unstaffed stations. One additional station is staffed with interagency firefighters. After a failed mill levy in 2020, the district closed Station 43 in South Rifle. The district continues to maintain Station 41 in North Rifle. The Garfield County Sheriff’s Office has approximately 144 staff. The Emergency Management Commander reports that the Sheriff and is assigned a sergeant to support staffing for emergency response. 9. SITE SETTING TPR and the surrounding area are shown in Appendix B. The pads are located on private land at approximately 9,100’ to 9,300’ in elevation. Well Pad 25A was constructed in 2008 and is approximately 2.6 acres. Pad 25B is Emergency Response Plan CPX Piceance Holdings, LLC Tepee Park Ranch 4 November 2022 forecasted to be constructed in 2023 and will be approximately 1.8 acres. Pad 36A was constructed in 2008 and is approximately 2.1 acres. The existing pad surfaces are bare ground with no vegetation. They are surrounded by cut and fill dirt work. The surrounding area is aspen woodlands and spruce/fir forest. The border with U.S. Forest Service land is approximately 2,000’ north and 1,800’ south of the pads. Beaver Creek, a perennial stream, runs through TPR and is approximately 130’ to 1,440’ downgradient. The nearest residence is greater than 1 mile northwest. The only structure within a 1/2-mile radius of the well pad is an unoccupied, unimproved cabin on TPR used to store outdoor gear, tables, tools, and other non-hazardous supplies. 10. DETAILED LAYOUT Detailed layouts of the pads are shown in Appendix C. At full build out, the well pads will have quad separators, heater treaters, motors, produced water and condensate tanks inside of lined steel secondary containment , enclosed combustors, and ancillary equipment. Pad 25B will have an anticipated 12 10,000-bbl or 15,000-bbl water tanks inside of containment. Pad 25B will be decommissioned when well completions are finished on TPR. Three existing buried flowlines tie into the northwest side of Well Pad 25A, cross TPR, and continue in a buried flowline trench adjacent to FS 824 to CPX’s production pad on private property near the intersection of FS 824 and CR 317. The flowlines transport natural gas, condensate, and produced water or freshwater. The buried flowlines will be extended to Pad 36A. 11. EQUIPMENT AND STORED MATERIALS New well drilling will require the equipment and stored material listed below. The equipment will be removed when drilling and well completion is finished. A Facility Drawing with production equipment is shown in Appendix C. • Support trailers • Drill cuttings trench • Dust mitigation equipment • Separators • Crane • Generator house • Fluid pumps • Diesel tank • Drill rig • Pump skid • Frac tanks • Mixing skid • Air handler • Process skid • Blender • Suction tank • Water tanks • Shale shaker • Sand silos • Mud tanks • Gel tank and bar tank • Totes of drilling support chemicals A Spill Prevention Control and Countermeasure (SPCC) Plan will be updated and maintained for the location. 12. SENSITIVE AREAS Beaver Creek is located approximately 130’ to 1,440’ downgradient of the pads. Pursuant to COGCC Rule 309.e.(5).E, Colorado Parks & Wildlife (CPW) made a written recommendation to COGCC on June 18, 2021 for a variance for Pad 36A’s proximity to Beaver Creek. CPW reaffirmed is recommendation for a variance on July 13, 2022. Groundwater in this area is an estimated 40’ to 80’ deep. There is no residential development. The nearest residence is greater than 1 mile northwest. Emergency Response Plan CPX Piceance Holdings, LLC Tepee Park Ranch 5 November 2022 13. POTENTIAL IMPACTS, PREVENTION, AND MITIGATION Potential impacts include: • Storm damage • Spill or release • Lightening • Equipment failure • Wildfire • Motor vehicle or on-site accident Personnel will be on site continuously during well drilling and completions. During production, CPX personnel will be on site daily for operations and maintenance. The field staff live within 15 minutes of TPR, which facilitates a consistent on-site presence to detect a problem at the location. Staff will monitor for storm-related damages, equipment failure and maintenance needs, and accidental spills or releases. Tanks are inside of lined steel secondary containment sized to contain 150 percent of the volume of the largest tank. This prevents release of a spill to the environment. The SPCC Plan for the location describes additional controls and response. Material used on a pad will be properly containerized and stored to prevent exposure to elements and spills. Site equipment will be maintained in good working condition and operated according to training and manufacturer specifications. Pads will be kept weed free to avoid ignition of vegetation with a vehicle catalytic converter. Staff and vendors will be expected to limit speeds to avoid accidents and overturned vehicles. 14. RESPONSE EQUIPMENT CPX maintains spill response material to respond to a spill or accident, consisting of booms and absorbents. The response materials will support cleanup of small leaks or spills, such as produced water, oil, lubricants, or incidental fuel leaks. The drum where response material is stored will be inspected a minimum of annually, and material will be replenished, if needed. In the event of a larger incident, CPX will manage and oversee support from a third-party provider to respond to an unintentional release and any potential soil contamination. In the event of a significant water loss on Pad 25B, water will be contained inside of secondary containment and will flow to a 5-foot by 5-foot steel sump installed at grade on the pad. If the capacity of the sump is exceeded, a 5-hp pump will be used to pump water to an emergency standby tank on CPX’s Pad 2 in Section 13, Township 7 South, Range 94 West, at the intersection of FS 824 and CR 317. Water will flow to Pad 2 using CPX’s existing bidirectional 8” water flowline. Residual water, if any, will be removed using a vacuum truck. The emergency standby tank on Pad 2 will be 10,000 or 15,000 bbl. 15. HEALTH AND SAFETY ACTION LEVELS Personnel will be on site continuously during well drilling and completions. Their presence will provide continuous communication about site conditions and site safety. During production CPX personnel will be on site daily for operations and maintenance. During completions, the operator will monitor tank and flowline integrity, volumes, and secondary containment for evidence of leaks or spills. During production, the operator will observe secondary containment, the separators, and wellhead areas. The operator will monitor for pressure drops in pipelines that could indicate an iss ue with equipment or valves. Emergency Response Plan CPX Piceance Holdings, LLC Tepee Park Ranch 6 November 2022 An operation and maintenance log will document health, safety, maintenance, and repair issues. The log will be used to record repairs, any preventative maintenance scheduling, and incidents. This information will help to identify site conditions requiring attention. In the event of an incident, Well Pad 25A will be used for a staging area. If Well Pad 25A is not available, nearby Well Pad 36A will be used for staging. 16. TRAINING COORDINATED WITH LOCAL RESPONDERS In the event of an emergency requiring first responders, a unified command will be established between the CPX appointed representative on location and first responders from Colorado River Fire Rescue. A command post will be established based on conditions present at the time of an incident. Site personnel will be trained on the types of incidents that may occur on site and the appropriate response. Incidents include those listed below. Through this Plan, potential incidents are being coordinated with Colorado River Fire Rescue for agency input. • Injury from equipment operation • Medical emergency • Equipment failure causing injury • Slips, trips, falls • Equipment failure causing fire • Insect stings and bites • Equipment failure causing pressure release • Weather-related incident • Grass fire or wildfire • Motor vehicle accident Most accidents consist of minor injuries, such as cuts, scrapes, trips, and sprains. Most medical incidents typically involve cold or heat exposure, sunburn, and insect stings and bites. Vehicles operating at the site will be required to carry general first aid supplies. On -site self-treatment is typically sufficient for an incident until personnel are able to leave the site and, if warranted, receive any additional follow up treatment. Notification to the CPX Principal will occur within 24 hours for all health and safety incidents. Serious incidents may require a 911 response. Personnel will be instructed that the nearest major medical facility is the Grand River Hospital in Rifle, CO. It is approximately 12 miles from Well Pad 25A . NEAREST MEDICAL FACILITY Grand River Hospital 501 Airport Road Rifle, CO 81650 (970) 625-1510 24-hour Emergency Room Directions from TPR North on TPR road to FS 824 North on FS to CR 317 L on CR 317 for approximately 5.5 miles R at the fork with CR 320 L on Garden Lane R on 7th St. South East on 7th St. South Stay straight at the traffic circle 7th St. South becomes Airport Rd. In 1/3 mile, R into the hospital entrance Emergency Response Plan CPX Piceance Holdings, LLC Tepee Park Ranch 7 November 2022 Appendices Appendix A Demonstration of Local Response Agency Coordination Appendix B Location Drawings Appendix C Layout Drawings Appendix A Demonstration of Local Response Agency Coordination Appendix A Demonstration of Local Response Agency Coordination 1 gwen.brodsky@aota.tech From:gwen.brodsky@aota.tech Sent:Wednesday, November 16, 2022 1:32 PM To:'Chris Bornholdt' Cc:Nick Kurtenbach; 'Bryan Clark' Subject:CPX Piceance Holdings Emergency Response Plan - Rev.2 Attachments:(8) Emergency Response Plan_TPR 36A.pdf Commander Bornholdt, This email provides the updated Emergency Response Plan for CPX Piceance Holdings, LLC. It’s updated from the version you reviewed in June 2022. Your previous reviews were for CPX Well Pad 25A and Temporary Water Storage Pad 25B. With the current update, CPX is submitting a request to the Colorado Oil and Gas Conservation Commission for permit application approval for continued development of CPX’s existing Well Pad 36A. Pads 25A, 25B, and 36A are described and shown in the Emergency Response Plan. Your response to this email will help us demonstrate to COGCC our coordination with the local emergency response agency. Thank you, and please don’t hesitate to let me know if you have any questions. Regards, Gwen Gwen Brodsky | Principal Cell (303) 818-4462 gwen.brodsky@aota.tech Aota Technical, LLC | Denver, CO aota.tech Archived: Tuesday, June 21, 2022 8:32:32 AM From: Chris Bornholdt Sent: Tuesday, June 21, 2022 8:11:36 AM To: gwen.brodsky@aota.tech Subject: RE: CPX Piceance Holdings Emergency Response Plan Sensitivity: Normal Received From: gwen.brodsky@aota.tech <gwen.brodsky@aota.tech> Sent: Thursday, June 16, 2022 2:59 PM To: Chris Bornholdt <cbornholdt@garcosheriff.com> Cc: Nick Kurtenbach <nick@cpxpiceance.com>; 'Bryan Clark' <bryan@cpxpiceance.com> Subject: CPX Piceance Holdings Emergency Response Plan Commander Bornholdt, This email provides the Emergency Response Plan for CPX Piceance Holdings, LLC. It’s updated from the version you reviewed in March 2022. Your previous review for CPX’s Well Pad 25A is documented in Appendix A of the Plan. The current update describes a new proposed Temporary Water Support Pad, Pad 25B. CPX plans to apply for a Colorado Oil and Gas Conservation Commission permit for Pad 25B during Q3 2022. The Emergency Response Plan is a requirement under state rules administered by COGCC. The Emergency Response Plan is cumulative. It describes the original Well Pad 25A and this addition of Pad 25B. Pad 25B will be located on CPX’s privately owned Tepee Park Ranch, south of Rifle. Your response to this email will help us to demonstrate to COGCC our coordination with the local emergency response agency. Thank you, and please don’t hesitate to let me know if you have questions that we can help with. Regards, Gwen Gwen Brodsky | Principal Planner Cell (303) 818-4462 gwen.brodsky@aota.tech Aota Technical, LLC | Denver, CO aota.tech ---------- Forwarded message --------- From: Chris Bornholdt <cbornholdt@garcosheriff.com> Date: Thu, Mar 24, 2022 at 11:28 AM Subject: Tepee Park Ranch Emergency Response Plan To: bryan@cpxpiceance.com <bryan@cpxpiceance.com> Hello, Sorry for the delay in getting back to you on this, not sure where it ended up. I reviewed your plan and approve it as the LEPC chair. Thanks for your hard work and making sure the proper channels are followed. Thanks Again Commander Chris Bornholdt Emergency Operations Garfield County Sheriff’s Office 107 8th Street Glenwood Springs, CO 81601 1-970-945-0453 x 1012 cbornholdt@garcosheriff.com Archived: Tuesday, February 8, 2022 10:00:44 AM From: gwen.brodsky@aota.tech Sent: Tuesday, February 8, 2022 8:57:01 AM To: cbornholdt@garcosheriff.com Cc: Nick Kurtenbach; 'Bryan Clark' Subject: Emergency Response Plan - CPX Piceance Holdings Sensitivity: Normal Attachments: Emergency Response Plan_CPX Piceance Holdings 0222.pdf ; Mr. Bornholdt, On behalf of CPX Piceance Holdings, LLC, this email provides an Emergency Response Plan for the continued development of natural gas wells that CPX proposes to develop on CPX’s privately owned Tepee Park Ranch, south of Rifle. I believe you have previously reviewed similar plans submitted by other operations. The Emergency Response Plan is a permit requirement under state rules administered by the Colorado Oil and Gas Conservation Commission (COGCC). CPX plans to apply for a COGCC permit for the well locations in early 2022. The Emergency Response Plan provides details on the well locations, access, equipment on site, potential for hazards, and response materials and procedures. Your response to this email will help us to demonstrate to the COGCC our coordination with the local emergency response agency. Thank you, and please don’t hesitate to let me know if you have questions that we can help with. Regards, Gwen Gwen Brodsky | Principal Planner Cell (303) 818-4462 gwen.brodsky@aota.tech Aota Technical, LLC | Denver, CO aota.tech Appendix B Location Drawing Existing Well Pad 25A TepeeParkRanchRoadBeaverCreekT e p e e C r e e k ForestServiceRoad8242,000' from Working Pad Surface CPX Water Well No. 321677 CPX PICEANCE HOLDINGS LLC CPX PICEANCE HOLDINGS LLC White River National Forest Existing Well Pad 36A 132-36 TPR 112-6 TPR 143-36 TPR(Private)BeaverCreekTrailBattlementTrailTemporary Water Support Pad 25B 176-25 TPR 112-16 TPR 1 TPR Section 25 Section 36 Section 30 Section 31 Section 6 T7S R94WT8S R93WT7S R94WT7S R93WT8S R93W T7S R93W Legend Oil & Gas Wells Drilled and Producing Drilled Drilled/Uncompleted "DUC" Well Permitted Water Well Oil and Gas Location Working Pad Surface 2,000 from Working Pad Surface Trail Off-Location Flowlines Forest Service Jurisdiction Parcels Forest Service Road Private Road Private Road Reroute and Access Reclaimed Private Road Perennial Stream Intermittent Stream Figure 1 CPX Piceance Holdings, LLC Tepee Park Ranch Temporary Water Support Pad 25B Aota Technical, LLC Figure No. Location Drawing 6/3/22 Date Data Sources: COGCC GIS Online COTREX U.S. Geologic Survey, National Hydrography Dataset Garfield County Mesa County Project Location RifleRifle 13 6 70 Garfield County SW1/4SE1/4 Sec. 25, T7S R94W, 6th P.M. 0 250 500 750 1,000 Feet Improvements within 2,000' of Working Pad Surface Pipelines Battlement Trail Mine/Permitted Shale Excavation 310' W 1,370' SE 1,230' W Existing Well Pad 25A White River National Forest 2,000' from Working Pad Surface CPX Water Well No. 321677 CPX PICEANCE HOLDINGS LLC CPX PICEANCE HOLDINGS LLC Existing Well Pad 36A See Inset BattlementTrail CPX PICEANCE HOLDINGS LLC White River National Forest T7S R94WT8S R93WT7S R94WT7S R93WT8S R93W T7S R93W Section 25 Section 36 Section 31 Section 6 Legend Oil & Gas Wells Drilled and Producing Spud/Uncompleted Drilled/Uncompleted "DUC" Expired Permit Water Well Building Working Pad Surface Oil and Gas Location 2,000' from Working Pad Surface Private Road Trail Forest Service Jurisdiction Parcels Property Line Figure 1 CPX Piceance Holdings, LLC Tepee Park Ranch Well Pad 36A Aota Technical, LLC Figure No. Location Drawing 10/18/22 Date Data Sources: COGCC GIS Online COTREX Garfield County SW1/4NE1/4 Sec. 36, T7S R94W, 6th P.M. 132-36 TPR 112-6 TPR 143-36 TPR Well Pad 36A Inset 0 125 250 375 500 Feet Garfield County Mesa County Project Location RifleRifle 13 6 70 Improvements within 2,000' of Working Pad Surface Battlement Trail CPX Water Well No. 321677 390' E 320' W 1Building Unit is an unimproved cabin owned by CPX and used for storage.1 Appendix C Layout Drawings 123456789101112131415161718^DATE: DRAWN BY: DESIGNED BY: PROJECT: FEET1 INCH = 0 GRAPHIC SCALE IN FEET 80 80 Contour Interval = 2' 7/26/22 CPX JAS TPP EXISTING OIL & GAS LOCATION - LEGEND - EXISTING ACCESS ROAD EXISTING OIL & GAS LOCATION SW1/4SE1/4 Section 25 T. 7 S., R. 94 W. Garfield County EXISTING OIL & GAS LOCATION PROPOSED WORKING PAD SURFACE EXISTING OIL & GAS LOCATION DRIVE OVER BERM PRODUCTION PAD SURFACE BURIED FLOWLINE - CONDENSATE BURIED FLOWLINE - GAS BURIED FLOWLINE - WATER ABOVE GRADE FLOWLINE - CONDENSATE ABOVE GRADE FLOWLINE - GAS ABOVE GRADE FLOWLINE - WATER BLOWDOWN LINE WELLHEAD FLOWLINE PRODUCED WATER INJECTION LINE SEDIMENT CATCH DITCH DIVERSION DITCH CONDENSATE TANK PRODUCED WATER TANK BLOWDOWN TANK INTERIM RECLAMATION AREA, MULCHED AND SEEDED EDGE OF WORKING PAD SURFACE INTERIM RECLAMATION AREA MULCHED & SEEDED INTERIM RECLAMATION AREA MULCHED & SEEDEDTANK BATTERY CONDENSATE TRANSFER PUMP PIG LAUNCHER TANK VAPORS COMBUSTOR LIQUIDS KNOCK-OUT SALT WATER DISPOSAL EQUIPMENT: CHARGE PUMPS FILTERS INJECTION PUMPS SEPARATION EQUIPMENT: 9 QUAD SEPARATORS FUEL GAS SKID INSTRUMENT AIR COMPRESSOR UTILITIES / CONTROLS: POWER GENERATION PLC SITE CONTROLLER REMOTE TELEMETRY UNIT / RADIO FLOWLINE CONNECTIONS FOR FUTURE PADS (PADS 31, 36) CONDENSATE: 2" STEEL GAS: 12" STEEL WATER: 5" FLEXPIPE DISTURBANCE AREAS OIL AND GAS LOCATION: ± 5.47 AC WORKING PAD SURFACE: ± 2.60 AC ACCESS ROAD: ± 0.12 AC UN-RECLAIMED AREA: ± 1.76 AC RE-CLAIMED AREA: ± 3.71 AC PRODUCTION PAD SURFACE LIQUIDS KNOCK-OUT BLOWDOWN COMBUSTOR HEATER TREATER EXIST. SED TRAPEXIST. SED TRAP DIVERSION DITCH DIVERSION DITCH DIVERSION DITCH SECONDARY CONTAINMENT: METALLIC WALL IMPERMEABLE LINER PROPOSED SED TRAP PROPOSED SED TRAP PROPOSED SED TRAP PROPOSED DIVERSION DITCH PROPOSED DIVERSION DITCH PROPOSED DIVERSION DITCH SEE NOTE 3 Exist. Access Roa d 2. 5 : 1 2. 5 : 1 2.7:12 : 1 2 . 5 : 1F 10.7'F 10.7'F 1 0 . 7 ' F 1 0 . 8 'F 10.8'F 10.8'9040903090109030904090609080Proposed Support Pad CenterN:1580817.52E:2341312.05Exist. Elev.: 9068.7Proposed Pad Elev.: 9065.7Prop. Sed. TrapRip-Rap Channelto Sed. TrapTrout HabitatBoundaryDaylight LineTrout Habitat Bndry.Proposed RoadRe-AlignmentRoad ConstructionDaylight LineDiversion Ditchw/ Check DamsRoad Ditchw/ Check DamsSW1/4SE1/4 Section 25T.7S, R 94 W.Garfield CountyDATE:DRAWN BY:DESIGNED BY:PROJECT:FEET1 INCH =0GRAPHIC SCALE IN FEET8080Contour Interval = 2'06/27/22CPXJASTPP- LEGEND -10K bbl WATER STORAGE TANK (50ft DIAMETER)15K bbl HARPOON TANK (55ft DIAMETER)EDGE OF WORKING PAD SURFACEPROPOSED ROADSUPPORT PAD OIL & GAS LOCATIONDRIVE OVER BERM2' MIN EARTH BERMDIVERSION DITCHSTRAW WATTLESWATER FROM WELL COMPLETIONSWATER TRANSFER LINE TO REMOTE FRAC PADWATER TRANSFER LINE FROM 8" FLEX STEEL4' SECONDARY CONTAINMENT (MUSCLE WALL)12" MANIFOLD (STEEL)4" RUBBER HOSEPUMPEMERGENCY FLUID SUMP (STEEL)HYDROMULCHFEET1 INCH =0GRAPHIC SCALE IN FEET8080Contour Interval = 2'Notes:1. Water storage will total approximately 150,000 bbls in modular large volume tanks(MLVTs). Tank procurement is dependent on availability. Tanks are forecasted to be either 10,000-bbl or 15,000-bbl in size, or approximately 10 to 15 tanks.2. Secondary Containment Capacity: +150% total capacity.3. Pad 25B will be used only for temporary water storage. It will not contain wells.4. Pad located on private surface. Gate locked at main entrance.9020Prop. Sed. TrapDrive-OverEarthen BermDiversion Ditchw/ Check DamsProp. Culvert(±71 lf)Prop. Sed. TrapInterimReclamationInterimReclamationDrive-OverEarthen Berm9050Support PadOil & Gas LocationProp. Sed. TrapStraw WattlesInterimReclamationProp. Sed. TrapEmergency Response SumpEdge of WorkingPad Surface2' - Earthen BermEdge of TankContainmentExist. CMP/SEEDOriginal Disturbed Area 4.13 acReclaimed Area 2.30 acUnreclaimed Area 1.83 ac 12345678910111213141516ABExis t . Access RoadSection 36T. 7 S., R. 94 W.Garfield CountySee Note 3PLUG AND ABANDONED WELLPROPOSED GAS WELLPRODUCED WATER TANKCONDENSATE TANKWELLHEAD FLOWLINEPRODUCTION PAD SURFACEGAS/WATER/CONDENSATE FLOWLINESEXISTING 2' EARTHEN BERMEXISTING OIL & GAS LOCATIONWORKING PAD SURFACEEXISTING ROADDRIVE OVER BERMDIVERSION DITCHINTERIM RECLAMATION AREA, MULCHEDAND SEEDEDGas/Water/CondensateFlowlines- LEGEND -Exist. Oil andGas LocationExist. TPR 132-36 Drive OverBerm 25'Exist. Oil and Gas LocationExist. Oil &Gas LocationExist. LinedDiversion DitchMaintain ExistingDiversion DitchsSediment Trap with 6"Outlet Pipe to LowerDrainage DitchLinedDiversion DitchSeparation Equipment:8 Quad SeparatorsFuel GasSkidUtilities/Controls:Power GenerationPLC Site ControllerRemote TelemetryUnit/RadioExist. Conductor #3 Exist. Conductor #2 Existing CreekInterim Reclamationarea, Mulched andSeededDATE:DRAWN BY:DESIGNED BY:PROJECT:FEET1 INCH =0GRAPHIC SCALE IN FEET8080Contour Interval = 2'11/16/22CPXTPPTPPProduction PadSurfaceDISTURBANCE AREASOIL AND GAS LOCATION: ± 5.45 ACWORKING PAD SURFACE: ± 2.06 ACACCESS ROAD: ± 0.0 AC PRODUCTION PAD: ± 1.34 AC RE-CLAIMED AREA: ± 4.11 AC ExistingSediment TrapInstrument AirSkidProduced WaterTransfer PumpSediment TrapLinedDiversion DitchCondensateLACT UnitV.O.C.CombustorBlowdown EnclosedCombustion DeviceHeater TreatersWorking PadSurfaceKnockoutVesselsWorkingPad Surface CPX Piceance Holdings TPR Well Pad 36A Article 9 Oil and Gas Permit Application Waste Management Plan COGCC Rule 304.c.(11) Limited Impact Review CPX Piceance Holdings, LLC Garfield County, Colorado 34 S. Wynden Drive, Suite 240 2022 Houston, TX 77056 Limited Impact Review CPX Piceance Holdings, LLC Garfield County, Colorado 34 S. Wynden Drive, Suite 240 Houston, TX 77056 TPR Well Pad 36A Article 9 Oil and Gas Permit Application Waste Management Plan COGCC Rule 304.c.(11) ~~ CPX Piceance Holdings a WASTE MANAGEMENT PLAN CPX Piceance Holdings, LLC (CPX) owns and operates Tepee Park Ranch (TPR) in Garfield County, Colorado. CPX has prepared this Waste Management Plan for continued development of the existing Well Pad 36A on TPR. The sections below correspond to Colorado Oil & Gas Conservation Commission (COGCC) Rule 304.c.(11) to prepare a Waste Management Plan consistent with Rule 905.a.(4) and COGCC Waste Management Plan Guidance (September 15, 2021). 1.0 Site Description The purpose of the Waste Management Plan (WMP) is to provide a systemic approach to manage waste streams generated by CPX during well drilling, completions, and production. Proper waste management avoids environmental impacts while reducing company liability. Well Pad 36A is an existing well pad on an established disturbed surface. The location is approximately 12 miles south of Rifle, Colorado in the SW ¥% NE % Section 36, Township 7 South, Range 94 West. TPR is privately owned and operated by CPX, predominantly for the exploration and development of natural gas wells. The location is further described in Table 1. Existing and proposed wells are listed in Table 2. Table 1. Existing Well Pad 36A Location Legal Description Location Coordinates Location ID SW % NE Ya, Section 36 conn, voy ae "08 334460 Township 7 South, Range 94 West gruce. , Table 2. Existing and Proposed Natural Gas Wells Existing Wells Proposed Wells One Spud/Not Completed Well (DG): TPR 132-36 (API # 05-045-16949) 32 Natural Gas Wells Two Expired Permits (EP): TPR 143-36 (API # 05-045-16950) TPR 112-6 (API # 05-045-16951) 1 Plugged and Abandoned Well (TPR 132-36) 2.0 Waste Identification and Classification This section addresses identification and classification of waste that may occur at the location. The U.S. Environmental Protection Agency (EPA) regulates solid and hazardous wastes under the Resource Conservation and Recovery Act (RCRA). The EPA classifies waste into two main categories: Hazardous Waste and Nonhazardous/Solid Waste. The EPA defines subcategories for each type of waste. Common classification of waste, according to the source of generation, are listed below: 1) Industrial Solid Waste 2) Domestic Solid Waste 3) Oil and Gas Exploration & Production (E&P) Waste 2.1 Industrial Solid Waste Industrial solid wastes are generated by industrial processes. Examples include cleaning solutions, solvents and degreasers, absorbent media, filters, filter media, and certain empty chemical containers. WASTE MANAGEMENT PLAN Well Pad 36A November 2022 CPX Piceance Holdings, LLC (CPX) owns and operates Tepee Park Ranch (TPR) in Garfield County, Colorado. CPX has prepared this Waste Management Plan for continued development of the existing Well Pad 36A on TPR. The sections below correspond to Colorado Oil & Gas Conservation Commission (COGCC) Rule 304.c.(11) to prepare a Waste Management Plan consistent with Rule 905.a.(4) and COGCC Waste Management Plan Guidance (September 15, 2021). 1.0 Site Description The purpose of the Waste Management Plan (WMP) is to provide a systemic approach to manage waste streams generated by CPX during well drilling, completions, and production. Proper waste management avoids environmental impacts while reducing company liability. Well Pad 36A is an existing well pad on an established disturbed surface. The location is approximately 12 miles south of Rifle, Colorado in the SW ¼ NE ¼ Section 36, Township 7 South, Range 94 West. TPR is privately owned and operated by CPX, predominantly for the exploration and development of natural gas wells. The location is further described in Table 1. Existing and proposed wells are listed in Table 2. Table 1. Existing Well Pad 36A Location Legal Description Location Coordinates Location ID SW ¼ NE ¼, Section 36 Township 7 South, Range 94 West Latitude: 39.395017 Longitude: -107.831908 334460 Table 2. Existing and Proposed Natural Gas Wells Existing Wells Proposed Wells One Spud/Not Completed Well (DG): TPR 132-36 (API # 05-045-16949) Two Expired Permits (EP): TPR 143-36 (API # 05-045-16950) TPR 112-6 (API # 05-045-16951) 32 Natural Gas Wells 1 Plugged and Abandoned Well (TPR 132-36) 2.0 Waste Identification and Classification This section addresses identification and classification of waste that may occur at the location. The U.S. Environmental Protection Agency (EPA) regulates solid and hazardous wastes under the Resource Conservation and Recovery Act (RCRA). The EPA classifies waste into two main categories: Hazardous Waste and Nonhazardous/Solid Waste. The EPA defines subcategories for each type of waste. Common classification of waste, according to the source of generation, are listed below: 1) Industrial Solid Waste 2) Domestic Solid Waste 3) Oil and Gas Exploration & Production (E&P) Waste 2.1 Industrial Solid Waste Industrial solid wastes are generated by industrial processes. Examples include cleaning solutions, solvents and degreasers, absorbent media, filters, filter media, and certain empty chemical containers. CPX Piceance Holdings, LLC Waste Management Plan Well Pad 36A 2 November 2022 Waste associated with down hole oil and gas exploration and production activities is not considered to be waste from an industrial process. CPX does not anticipate industrial solid waste to be generated from the activities at the Oil and Gas Location. Therefore, the WMP does not address industrial waste handling and disposal. 2.1 Domestic Waste Examples of domestic waste include domestic trash, paper, food waste, and packaging. Sewage is also classified as domestic waste unless contaminated with hazardous materials. Sewage includes both gray water and septic waste generated at drilling rigs and living quarters. CPX anticipates generating waste classified as domestic waste. Domestic waste is commonly disposed of at a municipal solid waste landfill and, in the case of sewage, at a publicly owned treatment works through a third-party hauler. Waste disposal facilities are listed in Attachment A. 2.2 Oil and Gas Exploration and Production (E&P) Waste Colorado Revised Statute (C.R.S.) § 34-60-103 defines Exploration and Production (E&P) Waste as: Those wastes that are generated during the drilling of and production from oil and gas wells or during primary field operations and that are exempt from regulation as hazardous wastes under Subtitle C of the federal Resource Conservation and Recovery Act of 1976, 42 U.S.C. Sec. 6901 to 6934, as amended. E&P waste includes, but is not limited to drilling fluids, flowback fluids, produced water, oily waste, drill cuttings, and tank bottoms. Spilled or released product at primary field exploration operations is also considered E&P waste. Exempt and non-exempt waste that may be generated at Well Pad 36A is listed in Attachment B. 3.0 Waste Reduction and Minimization CPX will reduce and minimize waste generation by: • Reuse of waste as part of makeup constituents o Use of recycled water from a third-party operation for CPX well completions to minimize use of freshwater o Closed loop well drilling to reuse drilling fluids • Good housekeeping o Erosion and stormwater controls to avoid runoff and sedimentation o Bear-proof waste containers to avoid an attractant o Ensuring that contractors remove their own waste streams o Proper container labeling to avoid mixed waste o Avoiding commingling waste streams o Proper equipment maintenance and replacement • Reduction of waste o Use of closed loop drilling to reduce the volume of drilling waste o Use of bulk containers rather than drums o Transport off site unused chemicals for use at another site or for shipping back to the chemical provider CPX Piceance Holdings, LLC Waste Management Plan o Use of an Underground Injection Control (UIC) well for disposal of produced water under a permit issued by COGCC o Communication with subcontractors on waste minimization practices 4.0 Waste Disposal The following methods are anticipated to properly dispose of waste generated at the Well Pad 36A: e Proposed UIC well for disposal of produced water e Approved off-site third-party disposal facilities e Drill cuttings trench 4.1 Proposed UIC Well After completions and flowback, produced water not used during well development will be disposed of at CPX’s proposed UIC well on Well Pad 25A under a permit issued by COGCC. CPX is proposing to convert the existing TPR 176-25 to a UIC well. TPR 176-25 was drilled but uncompleted. Upon approval, CPX will use the proposed UIC well only for water generated on TPR. The proposed well is described in Table 3. Table 3. Proposed UIC Well Well Name Current Status Facility ID AP|# Lat/Long TPR 176-25 DUC/TA 433942 05-045-22153 39.404404 / -107.832644 4.2 Approved Off-site Third-party Disposal Facilities A list of approved third-party disposal facilities is provided in Attachment A. Wastes will be characterized according to disposal facility requirements for acceptance at the disposal facility. Waste characterization will include the necessary sampling required by the disposal facility and preparation of a waste profile. Materials will be transported for disposal under waste manifests for safety and recordkeeping. 4.3 Drill Cuttings Under Rule 905.g.(1).C, the water-based bentonite drilling cuttings generated on Well Pad 36A will be managed as oily waste until the drill cuttings have been approved for burial in the drill cuttings trench on the well pad. A Form 15 will be submitted within 30 days of constructing the drill cuttings trench, pursuant to Rule 908.c.(2). CPX estimates that each well will generate approximately 300 cubic yards of drill cuttings, or approximately 9,600 cubic yards of drill cuttings for the proposed 32 new wells. Representative baseline samples will be collected for the first two wells (600 cubic yards of drill cuttings). CPX will collect a 5-point composite sample for every 500 cubic yards of material. Each point will represent a 100-cubic yard aliquot of material, as recommended by the COGCC Rule 915.e.(2) Soil Sampling and Analysis Guidance (January 11, 2021). Each of the five aliquots will be collected at random depths at least 1 foot below the surface of the drill cuttings stockpile. The drill cuttings will be stored temporarily in a bermed cuttings management area on the well pad, as shown on the Drill Rig Layout submitted with the Form 2A application. Drill cuttings will be transferred to the cuttings trench and amended with clean soil that was derived from excavation of the cuttings trench. The drill cuttings will be sampled for the constituents in Table 915-1 before final burial with a minimum 3 feet of soil cover. The samples are anticipated to be representative for the 32 wells because they will be drilled in the same geologic formation. The composite samples will be analyzed by an accredited commercial lab to Well Pad 36A 3 November 2022 CPX Piceance Holdings, LLC Waste Management Plan Well Pad 36A 3 November 2022 o Use of an Underground Injection Control (UIC) well for disposal of produced water under a permit issued by COGCC o Communication with subcontractors on waste minimization practices 4.0 Waste Disposal The following methods are anticipated to properly dispose of waste generated at the Well Pad 36A: • Proposed UIC well for disposal of produced water • Approved off-site third-party disposal facilities • Drill cuttings trench 4.1 Proposed UIC Well After completions and flowback, produced water not used during well development will be disposed of at CPX’s proposed UIC well on Well Pad 25A under a permit issued by COGCC. CPX is proposing to convert the existing TPR 176-25 to a UIC well. TPR 176-25 was drilled but uncompleted. Upon approval, CPX will use the proposed UIC well only for water generated on TPR. The proposed well is described in Table 3. Table 3. Proposed UIC Well Well Name Current Status Facility ID API # Lat/Long TPR 176-25 DUC/TA 433942 05-045-22153 39.404404 / -107.832644 4.2 Approved Off-site Third-party Disposal Facilities A list of approved third-party disposal facilities is provided in Attachment A. Wastes will be characterized according to disposal facility requirements for acceptance at the disposal facility. Waste characterization will include the necessary sampling required by the disposal facility and preparation of a waste profile . Materials will be transported for disposal under waste manifests for safety and recordkeeping. 4.3 Drill Cuttings Under Rule 905.g.(1).C, the water-based bentonite drilling cuttings generated on Well Pad 36A will be managed as oily waste until the drill cuttings have been approved for burial in the drill cuttings trench on the well pad. A Form 15 will be submitted within 30 days of constructing the drill cuttings trench, pursuan t to Rule 908.c.(2). CPX estimates that each well will generate approximately 300 cubic yards of drill cuttings, or approximately 9,600 cubic yards of drill cuttings for the proposed 32 new wells. Representative baseline samples will be collected for the first two wells (600 cubic yards of drill cuttings). CPX will collect a 5-point composite sample for every 500 cubic yards of material. Each point will represent a 100-cubic yard aliquot of material, as recommended by the COGCC Rule 915.e.(2) Soil Sampling and Analysis Guidance (January 11, 2021). Each of the five aliquots will be collected at random depths at least 1 foot below the surface of the drill cuttings stockpile. The drill cuttings will be stored temporarily in a bermed cuttings management area on the well pad, as shown on the Drill Rig Layout submitted with the Form 2A application. Drill cuttings will be transferred to the cuttings trench and amended with clean soil that was derived from excavation of the cuttings trench. The drill cuttings will be sampled for the constituents in Table 915-1 before final burial with a minimum 3 feet of soil cover. The samples are anticipated to be representative for the 32 wells because they will be drilled in the same geologic formation. The composite samples will be analyzed by an accredited commercial lab to CPX Piceance Holdings, LLC Waste Management Plan demonstrate that concentrations do not exceed applicable Table 915-1 levels including consideration of background levels, as noted in Table 915-1, footnote 1. If the drill cuttings do not meet Table 915-1 analytical requirements, they will receive additional soil amendment and aeration. They will be re-sampled monthly until the drill cuttings meet the Table 915-1 requirements or until they are within background limits in the footnotes listed in Table 915-1. Drill cuttings meeting Table 915-1 requirements will be managed and disposed of pursuant to Rule 905.g.(2) Drill Cuttings and an approved Form 27. The drill cuttings trench will be filled and covered with 3 feet of soil cover from the original well pad construction. During interim reclamation, this area will be reclaimed so that it blends with the surrounding topography and is seeded, as described in the Interim Reclamation Plan submitted with the Form 2A application. 5.0 Waste Tracking and Records Management In compliance with COGCC Rule 907.b.(8).F. Recordkeeping, waste transported off site on public roads will be documented. Records of the source and destination will be maintained. In accordance with Rule 907.b.(2), the following information will be kept on file: A. The date of the transport B. The identity of the waste generator C. The identity of the waste transporter D. The location of the waste pickup site E. The type and volume of waste F. The name and location of the treatment or disposal site CPXs will maintain records of waste treatment, analytical results, and transport and manifests for a minimum of 5 years at its office in Rifle, Colorado. Records will be made available upon request. 6.0 Waste Transportation CPX will use third-party waste haulers for disposal of wastes. The following preferred haul route will be used for waste transportation: e North on private Tepee Park Ranch Road for approximately 1.50 miles e North on Forest Service Road 824 (FS 824) for approximately 2.75 miles to County Road (CR) 317 e =North on CR 317 for approximately 5.5 miles e East on CR 320 (Rifle-Rulison Road) for approximately 3 miles e North on Garden Lane and East on 7‘ St. to Rifle Waste haulers will access I-70 in Rifle to continue to the waste disposal facilities listed in Attachment A. According to the Garfield County Road and Bridge Department, CR 317 and CR 320 are preferred haul routes. Both are used to access ranches and agricultural operations, rural residences, oil and gas operations, and public lands. CR 320 is hard surfaced. CR 317 is hard surfaced for the first mile on the north end and then becomes an unpaved road maintained by Garfield County. FS 824 is an unpaved road. CPX has a use permit with the Forest Service and uses the road under an annual operating agreement approved by the Forest Service. In 2018, CPX financed and self-performed significant road realignment and stormwater control improvements to FS 824 following a National Environmental Policy Act review conducted by the Forest Service. The road realignment moved portions of the road away from Beaver Well Pad 36A 4 November 2022 CPX Piceance Holdings, LLC Waste Management Plan Well Pad 36A 4 November 2022 demonstrate that concentrations do not exceed applicable Table 915-1 levels including consideration of background levels, as noted in Table 915-1, footnote 1. If the drill cuttings do not meet Table 915-1 analytical requirements, they will receive additional soil amendment and aeration. They will be re-sampled monthly until the drill cuttings meet the Table 915-1 requirements or until they are within background limits in the footnotes listed in Table 915-1. Drill cuttings meeting Table 915-1 requirements will be managed and disposed of pursuant to Rule 905.g.(2) Drill Cuttings and an approved Form 27. The drill cuttings trench will be filled and covered with 3 feet of soil cover from the original well pad construction. During interim reclamation, this area will be reclaimed so that it blends with the surrounding topography and is seeded, as described in the Interim Reclamation Plan submitted with the Form 2A application. 5.0 Waste Tracking and Records Management In compliance with COGCC Rule 907.b.(8).F. Recordkeeping, waste transported off site on public roads will be documented. Records of the source and destination will be maintained. In accordance with Rule 907.b.(2), the following information will be kept on file: A. The date of the transport B. The identity of the waste generator C. The identity of the waste transporter D. The location of the waste pickup site E. The type and volume of waste F. The name and location of the treatment or disposal site CPXs will maintain records of waste treatment, analytical results, and transport and manifests for a minimum of 5 years at its office in Rifle, Colorado. Records will be made available upon request. 6.0 Waste Transportation CPX will use third-party waste haulers for disposal of wastes. The following preferred haul route will be used for waste transportation: • North on private Tepee Park Ranch Road for approximately 1.50 miles • North on Forest Service Road 824 (FS 824) for approximately 2.75 miles to County Road (CR) 317 • North on CR 317 for approximately 5.5 miles • East on CR 320 (Rifle-Rulison Road) for approximately 3 miles • North on Garden Lane and East on 7th St. to Rifle Waste haulers will access I-70 in Rifle to continue to the waste disposal facilities listed in Attachment A. According to the Garfield County Road and Bridge Department, CR 317 and CR 320 are preferred haul routes. Both are used to access ranches and agricultural operations, rural residences, oil and gas operations, and public lands. CR 320 is hard surfaced. CR 317 is hard surfaced for the first mile on the north end and then becomes an unpaved road maintained by Garfield County. FS 824 is an unpaved road. CPX has a use permit with the Forest Service and uses the road under an annual operating agreement approved by the Forest Service. In 2018, CPX financed and self-performed significant road realignment and stormwater control improvements to FS 824 following a National Environmental Policy Act review conducted by the Forest Service. The road realignment moved portions of the road away f rom Beaver CPX Piceance Holdings, LLC Waste Management Plan Creek. The stormwater improvements consisted of culvert installations with armored upstream and downstream inlets and outlets. 7.0 Approved Waste Disposal Facilities A list of approved third-party waste disposal and recycling facilities is provided in Attachment A. 8.0 Waste Stream Table A list of waste streams by operation is provided in Attachment B. 9.0 Waste List and Waste Management Guides A list of potential wastes and a waste management guide is provided in Attachment C. 10.0 Layout Drawings Layout drawings showing the cuttings trench, cuttings management area, and frac sand containment are provided with the layout drawings submitted with the Form 2A application. 11.0 Best Management Practices Table 4. Best Management Practices Best Management Practices e Trash will be removed for disposal as domestic solid waste at a permitted waste disposal facility. e Tanks and containers will be labeled according to requirements of Rule 605.h. e The location will use bear-proof containers for food-related waste. e _ Recycled produced water will be used to support CPX completions operations. e _Acclosed loop drilling system will be used to reduce the volume of waste. e Bulk containers will be used instead of drums to reduce waste. e Unused chemicals will be sent back to the chemical provider or will be used at another drilling site and will not be stored on the location. e Waste streams will not be commingled such that they no longer qualify as solid waste or E&P exempt waste. e _ A designated area will be identified and controlled for waste storage. e Waste will be segregated and stored according to its waste classification. e _ Equipment and materials will be properly maintained to avoid unnecessary waste. e —CPXwill communicate waste minimization practices and procedures to subcontractors. e Wastes will be stored in containers or on lined containment that are chosen for compatibility and checked for leaks or integrity problems. Examples of containment include but are not limited to steel tanks, lined berms, lined containment, plastic totes, drums, etc. Attachments Attachment A Approved Third-party Waste Disposal and Recycling Facilities Attachment B_ Waste Streams by Operation Attachment C Waste List and Waste Management Guide Well Pad 36A 5 November 2022 CPX Piceance Holdings, LLC Waste Management Plan Well Pad 36A 5 November 2022 Creek. The stormwater improvements consisted of culvert installations with armored upstream and downstream inlets and outlets. 7.0 Approved Waste Disposal Facilities A list of approved third-party waste disposal and recycling facilities is provided in Attachment A. 8.0 Waste Stream Table A list of waste streams by operation is provided in Attachment B. 9.0 Waste List and Waste Management Guides A list of potential wastes and a waste management guide is provided in Attachment C. 10.0 Layout Drawings Layout drawings showing the cuttings trench, cuttings management area, and frac sand containment are provided with the layout drawings submitted with the Form 2A application. 11.0 Best Management Practices Table 4. Best Management Practices Best Management Practices • Trash will be removed for disposal as domestic solid waste at a permitted waste disposal facility. • Tanks and containers will be labeled according to requirements of Rule 605.h. • The location will use bear-proof containers for food-related waste. • Recycled produced water will be used to support CPX completions operations. • A closed loop drilling system will be used to reduce the volume of waste. • Bulk containers will be used instead of drums to reduce waste. • Unused chemicals will be sent back to the chemical provider or will be used at another drilling site and will not be stored on the location. • Waste streams will not be commingled such that they no longer qualify as solid waste or E&P exempt waste. • A designated area will be identified and controlled for waste storage. • Waste will be segregated and stored according to its waste classification. • Equipment and materials will be properly maintained to avoid unnecessary waste. • CPX will communicate waste minimization practices and procedures to subcontractors. • Wastes will be stored in containers or on lined containment that are chosen for compatibility and checked for leaks or integrity problems. Examples of containment include but are not limited to steel tanks, lined berms, lined containment, plastic totes, drums, etc. Attachments Attachment A Approved Third-party Waste Disposal and Recycling Facilities Attachment B Waste Streams by Operation Attachment C Waste List and Waste Management Guide CPX Piceance Holdings, LLC Waste Management Plan Well Pad 36A 6 November 2022 ATTACHMENT A APPROVED THIRD-PARTY WASTE DISPOSAL FACILITIES Garfield County Landfill 0075 County Road 246 Rifle, CO 81650 (970) 625-2516 https://www.garfield-county.com/landfill/ Greenleaf Environmental Services 15655 45 1/2 Road De Beque, CO, 81630 (970) 283-8992 https://www.greenlfservices.com/ Safety Kleen 368 Bonny Street Grand Junction, CO 81501 (970) 241-1343 https://www.safety-kleen.com/locations ECDC Environmental Landfill 1111 West Highway 123 East Carbon, UT 84520 (435) 888-4113 APPROVED THIRD-PARTY RECYCLING FACILITIES Pacific Steel and Recycling 2365 River Road Grand Junction, CO 81505 (970) 241-2551 https://www.pacific-steel.com/ Green Zone 32595 Highway 6 & 24 Silt, CO 81652 970-876-5941 https://www.green-zone-recycling.com/ Batteries Plus 578 25 Road Grand Junction, CO 81505 (970) 245-7000 https://www.batteriesplus.com/ Western Metal Recycling 645 4th Ave Grand Junction, CO 81501 (970) 242-9500 https://www.wmrecycling.com/grand-junction-co/ CPX Piceance Holdings, LLC Waste Management Plan Well Pad 36A 7 November 2022 ATTACHMENT B WASTE STREAMS BY OPERATION Operational Phase Waste Stream Disposal Type Construction Phase (Site Preparation, removing off existing equipment) Scrap Metal Recycling Produced Solids and Tank Bottoms Disposal – Refer to Attachment C for waste characterization and disposal details Domestic Refuse Disposal – Garfield County Landfill Drilling Drill Cuttings Disposal – Cuttings Trench Drilling Fluid/Mud Disposal and Recycling - Refer to Attachment C for waste characterization and disposal details Domestic Refuse Disposal – Garfield County Landfill Completions Frac Sand Disposal – Greenleaf Environmental Services Domestic Refuse Disposal – Garfield County Landfill Flowback Produced Water Disposal – UIC disposal Filters - produced water Disposal - Refer to Attachment C for waste characterization and disposal details Domestic Refuse Disposal – Garfield County Landfill Production Produced Solids and Tank Bottoms Disposal – Refer to Attachment C for waste characterization and disposal details Chemicals - Spent and Unused Non- Hazardous Blowdown and Swabbing Waste Well Workover and Completion Fluids Batteries – Lead Acid Recycling Spill Response and Remediation Soil Contaminated with Chemical or Lube Oil Disposal – Refer to Attachment C for waste characterization and disposal details Soil Contaminated with Oil, Condensate or Produced Water Oil/Condensate Collected from Spills CPX Piceance Holdings, LLC Waste Management Plan ATTACHMENT C POTENTIAL WASTE AND WASTE MANAGEMENT GUIDE Acids and Caustics - Unused Aerosol Cans - Spent (degreasers, WD-40, spray paint, lubricants, etc.) Batteries — Lead Acid Blowdown and Swabbing Waste Chemicals - Spent and Unused Non-Hazardous Oil/Condensate Collected from Spills Domestic Refuse (trash, construction debris, food waste) Drilling Fluid/Mud Drilling Mud Solids and Cuttings Filters - Produced water and flowback water Frac Sand Oil Contaminated Debris (oily rags, oil pads, booms, etc.) Produced Solids and Tank Bottoms Produced Water Scrap Metal (pipe, vessels) Septic Waste Soil Contaminated with Chemical or Lube Oil Soil Contaminated with Oil, Condensate or Produced Water Solvents - Spent Well Workover and Completion Fluids Well Pad 36A 8 November 2022 CPX Piceance Holdings, LLC Waste Management Plan Well Pad 36A 8 November 2022 ATTACHMENT C POTENTIAL WASTE AND WASTE MANAGEMENT GUIDE Waste Acids and Caustics - Unused Aerosol Cans - Spent (degreasers, WD-40, spray paint, lubricants, etc.) Batteries – Lead Acid Blowdown and Swabbing Waste Chemicals - Spent and Unused Non-Hazardous Oil/Condensate Collected from Spills Domestic Refuse (trash, construction debris, food waste) Drilling Fluid/Mud Drilling Mud Solids and Cuttings Filters - Produced water and flowback water Frac Sand Oil Contaminated Debris (oily rags, oil pads, booms, etc.) Produced Solids and Tank Bottoms Produced Water Scrap Metal (pipe, vessels) Septic Waste Soil Contaminated with Chemical or Lube Oil Soil Contaminated with Oil, Condensate or Produced Water Solvents - Spent Well Workover and Completion Fluids CPX Piceance Holdings, LLC Waste Management Plan Well Pad 36A 9 November 2022 Acids and Caustics - Unused Waste Description Acid or caustic that has been used for well workover and stimulation. May contain surfactants, emulsifiers, solvents, and/or dispersant. Classification E&P Exempt Classification Basis Exempt for oil and gas production under EPA Regulatory Determination Federal Register Vol. 58, No 53 but may be classified as hazardous if mismanaged. Handling/ Storage Containerize spent acids in rain-proof and leak-proof containers that are compatible with corrosive materials. Keep containers closed when not in use. Store containers in designated non-hazardous waste storage areas that reduce the potential for release. If commingling with produced water, store in produced water tanks. Labeling Label with contents. Required Logs, Manifests, Notifications If shipping to 3rd party disposal, use the state specified method of shipment for E&P Waste (required manifest or standard bill of lading). Transportation Waste must be transported by an authorized and certified transporter. Recycling Recycle at an approved recycling facility. Recordkeeping Maintain logs, manifests, and waste documentation at the facility or nearest office for a minimum of 5 years. CPX Piceance Holdings, LLC Waste Management Plan Well Pad 36A 10 November 2022 Aerosol Cans - Spent Waste Description Aerosol cans containing lubricants, degreasers, spray paint, etc. Classification Non-Hazardous if can is “RCRA empty” of product. Hazardous if can is not “RCRA empty” and product can no longer be used. Classification Basis Can/container is RCRA empty if all product has been removed using practices commonly employed (spraying) and residue left in can is <1 inch or <3% of original product weight. COGCC Rule Reference COGCC Rule 906 Handling/ Storage Containerize spent aerosol cans that are classified as hazardous waste in rain-proof and leak-proof containers that are compatible with the chemicals stored therein. Keep containers closed when not in use. If managed as hazardous waste, store cans for no more than 180 days. Aerosol cans that are RCRA empty can be treated as municipal waste and placed in trash receptacles. Labeling The accumulation start date must also be recorded, either on the container or in written or electronic records. Required Logs, Manifests, Notifications Waste aerosol cans that are disposed of as non-hazardous typically need no manifests. If disposed of a hazardous waste, a Uniform Hazardous Waste Manifest is not required Transportation Waste must be transported by an authorized and certified transporter. Disposal If hazardous, dispose of at an approved hazardous waste landfill. Confirm that landfill will accept waste aerosol cans. If RCRA empty, dispose of cans at approved non- hazardous waste landfill. Approved Waste Disposal and Recycling Facilities ECDC Environmental Landfill Refer to Attachment A for approved waste disposal facility location details. Pacific Steel and Recycling Recordkeeping Maintain logs, manifests, and waste documentation at the facility or nearest office for a minimum of 5 years. CPX Piceance Holdings, LLC Waste Management Plan Well Pad 36A 11 November 2022 Batteries – Lead Acid Waste Description Lead acid batteries used in electrical and mechanical applications. Classification Hazardous if disposed of in landfill. May be managed as non-hazardous if recycled or reclaimed. Classification Basis Meets the criteria for hazardous waste as defined by 40 CFR 261. Can be classified as non-hazardous if recycled or reclaimed. Also classified as universal hazardous waste under 40 CFR 273. COGCC Rule Reference COGCC Rule 906 Handling/ Storage Store spent batteries in designated storage area in rainproof, leak-proof containers that are compatible with the types of batteries stored therein. If managed as hazardous waste, store batteries for no more than 180 days. If managed as universal hazardous, store for no more than one year. Labeling If managed as hazardous waste, label container as “Waste Batteries - Hazardous” or “Used Batteries - Hazardous”. If managed as universal hazardous waste, label as above or as “Universal Waste Batteries”. The accumulation start date must also be recorded, either on the container or in written or electronic records. Required Sampling/Analysis for Classification Status None Required Logs, Manifests, Notifications If non-hazardous (recycled), use Bill of Lading or Non-Hazardous Waste Manifest. If hazardous (disposal), a Uniform Hazardous Waste Manifest is not required, but is highly recommended for Very Small Quantity Generators. Hazardous waste from Small Quantity or Large Quantity Hazardous Waste Generators always requires a Uniform Hazardous Waste Manifest. Transportation Waste must be transported by an authorized and certified transporter. Disposal If not recycled, dispose of at an approved hazardous waste landfill or an approved non-hazardous waste landfill that accepts hazardous waste from Very Small Quantity Generators. Approved Disposal and Recycling Vendors Green Zone Refer to Attachment A for approved waste disposal and recycling facility location details. Western Metals Recycling Recycling Return to vendor or recycle at an approved recycling facility. Recordkeeping Maintain logs, manifests, and waste documentation at the facility or nearest office for a minimum of 5 years. CPX Piceance Holdings, LLC Waste Management Plan Well Pad 36A 12 November 2022 Blowdown and Swabbing Waste Waste Description Fluids cleaned out of a well bore including oil, produced water, paraffin and water mix, emulsion breakers, corrosion inhibitors and scale inhibitors. Classification E&P Exempt Classification Basis Exempt for oil and gas production under EPA Regulatory Determination Federal Register Vol. 58, No 53, but may be classified as Hazardous if mismanaged. COGCC Rule Reference COGCC Rule 905 Handling/ Storage Send through production system for ultimate disposal with produced water. Labeling N/A Required Sampling/Analysis for Classification Status None Required Logs, Manifests, Notifications If shipping to 3rd party disposal, use the state specified method of shipment for E&P Waste (required manifest or standard bill of lading). Transportation Waste must be transported by an authorized and certified transporter. Disposal Dispose of along with produced water at CPX UIC well. Recordkeeping Maintain logs, manifests, and waste documentation at the facility or nearest office for a minimum of 5 years. CPX Piceance Holdings, LLC Waste Management Plan Well Pad 36A 13 November 2022 Chemicals – Spent and Unused Non-Hazardous Waste Description Spent non-hazardous chemicals used by a facility or unused chemicals still in a condition to be used as originally intended but has no further function at a facility. Classification Non-Hazardous, if chemicals are to be disposed. Unused chemicals returned to the vendor are not classified as waste. Classification Basis Does not meet the requirements for hazardous waste as defined by 40 CFR 261 or UAC R315-5. COGCC Rule Reference COGCC Rule 906 Handling/Storage Containerize spent chemicals in rain-proof and leak-proof containers that are compatible with chemicals stored therein (original containers if available). Keep containers closed when not in use. Store containers in designated non-hazardous waste storage areas that reduce the potential for release. Labeling Label as non-hazardous with chemical name. Required Sampling/Analysis for Classification Status None unless classification is unknown. Required Logs, Manifests, Notifications If chemicals are to be disposed, use a Bill of Lading or Non-Hazardous Waste Manifest. Transportation Waste must be transported by an authorized and certified transporter. Disposal Dispose of at an approved non-hazardous waste landfill. Approved Disposal Vendors Refer to Attachment A for approved waste disposal facility location details. Recycling Unused chemicals should always be returned to vendor. Recordkeeping Maintain all logs, manifests and waste documentation at the facility or nearest office for a minimum of 5 years. Waste Minimization Best Practices If possible, return unused chemicals to vendor. Use chemical completely before removing from the system to reduce the amount of waste produced. CPX Piceance Holdings, LLC Waste Management Plan Well Pad 36A 14 November 2022 Oil / Condensate Collected from Spills Waste Description Oil and condensate collected from spills, leaks, and operation upsets. Classification E&P Exempt Classification Basis Exempt for oil and gas production under EPA Regulatory Determination Federal Register Vol. 58, No 53. COGCC Rule Reference COGCC Rule 905 Handling/Storage If not placed back into production system, containerize in rain-proof and leak-proof containers that are compatible with the material stored therein. Keep containers closed when not in use. Store containers in designated non-hazardous waste storage areas that reduce the potential for release. Labeling Label with contents. Required Logs, Manifests, Notifications Use the state specified method of shipment for E&P Waste (required manifest or standard bill of lading). Transportation Waste must be transported by an authorized and certified transporter. Disposal If not placed back in production system, disposed of at an approved E&P exempt waste landfill. Approved Waste Disposal Facilities Greenleaf Environmental Services Refer to Attachment A for approved recycling facility location details ECDC Environmental Landfill Recycling Return to production stream for recovery. Recordkeeping Maintain all logs, manifests, and waste documentation at the facility or nearest office for a minimum of 5 years. CPX Piceance Holdings, LLC Waste Management Plan Well Pad 36A 15 November 2022 Domestic Refuse Waste Description General personnel trash, paper, food waste, etc. Classification Municipal/Domestic Solid Waste Classification Basis Does not meet the criteria for hazardous waste as defined by 40 CFR 261 or UAC R315-5 but may be classified as hazardous if mismanaged. COGCC Rule Reference COGCC Rule 906 Handling/Storage Do not mix with material that is contaminated or may be hazardous. Place domestic refuse in trash receptacle if not recycled. CPX will utilize bear-proof containers onsite for food waste. Transportation Waste to be transported by an authorized transporter. Disposal Disposed of at an approved municipal waste landfill. Approved Waste Disposal Facilities Garfield County Landfill Refer to Attachment A for approved recycling facility location details Recycling Recycle at an approved recycling facility. Recordkeeping Maintain logs, manifests, and waste documentation at the facility or nearest office for a minimum of 5 years. CPX Piceance Holdings, LLC Waste Management Plan Well Pad 36A 16 November 2022 Drilling Fluid/Mud Waste Description Water-based circulating fluid/mud used in the rotary drilling of wells to clean and condition the hole and to counterbalance formation pressure. Classification E&P Exempt Classification Basis Exempt for oil and gas production under EPA Regulatory Determination Federal Register Vol. 58, No 53, but may be classified as Hazardous if mismanaged. COGCC Rule Reference COGCC Rule 905 Handling/Storage Closed loop system will be used to separate solids from liquid. The majority of drilling fluids are anticipated to be clean and clean drilling fluids will be recycled and used in drilling operations at the next pad location. Any drilling fluids that are deemed to be unusable, will be transported to an approved off-site disposal facility. Required Logs, Manifests, Notifications Use the state specified method of shipment for E&P Waste (required manifest or standard bill of lading). Transportation Waste must be transported by an authorized and certified transporter. Disposal Disposed of at an approved E&P exempt waste landfill or approved subsurface injection facility. Approved Waste Disposal Facilities Greenleaf Environmental Services Refer to Attachment A for approved recycling facility location details Recycling Reuse drilling fluid whenever possible. Recordkeeping Maintain logs, manifests, and waste documentation at the facility or nearest office for a minimum of 5 years. CPX Piceance Holdings, LLC Waste Management Plan Well Pad 36A 17 November 2022 Drilling Cuttings/Oily Waste Waste Description Particles and cuttings generated by drilling into the subsurface geological formations including cured cement carried to the surface with the drilling fluid (water based). Classification E&P Exempt Classification Basis Exempt for oil and gas production under EPA Regulatory Determination Federal Register Vol. 58, No 53. COGCC Rule Reference COGCC Rule 905 Handling/Storage Dried, amended, and buried/disposed of onsite in cuttings trench. Required Sampling/Analysis for Classification Status COGCC Table 915-1 Required Logs, Manifests, Notifications Use the state specified method for E&P Waste (required characterization). Transportation Drill cuttings will remain onsite and will be buried in a drill cuttings trench. Oily waste will be transported off site. Disposal Drill cuttings will be analyzed to meet analytical standards of Table 915-1. Upon meeting Table 915-1 criteria and Form 27 approval, the subject cuttings will be buried/disposed. Oily waste will be disposed of off site. Approved Waste Disposal Facilities Drill Cuttings will be disposed of/buried onsite Refer to WMP. Greenleaf Environmental Services Refer to Attachment A for approved recycling facility location details Recordkeeping Maintain logs, manifests, and waste documentation at the facility or nearest office for a minimum 5 years. Volume Per Well Estimated For Well Pad 36A 300 Cubic Yards 9,600 Cubic Yards CPX Piceance Holdings, LLC Waste Management Plan Well Pad 36A 18 November 2022 Filters – Produced Water and Flowback Water Waste Description Wound string cartridge filters for filtering produced water and flowback water. Classification E&P Exempt Classification Basis Exempt for oil and gas production under EPA Regulatory Determination Federal Register Vol. 58, No 53, but may be classified as Hazardous if mismanaged. COGCC Rule Reference COGCC Rule 905 Handling/Storage Filters intended for recycling or landfill must be drained of all liquids prior to disposal. Return recovered liquids back into produced water tanks. Containerize filters in separate rain-proof, and leak proof containers that are compatible with material stored therein. Keep containers closed when not in use. Store containers in designated non-hazardous waste storage areas that reduce the potential for release. Labeling Label with contents. Required Sampling/Analysis for Classification Status None Required Logs, Manifests, Notifications Use the state specified method of shipment for E&P Waste (required manifest or standard bill of lading). Transportation Waste must be transported by an authorized and certified transporter. Disposal Disposed of at an approved E&P exempt waste landfill. Approved Disposal Vendors Greenleaf Environmental Services Refer to Attachment A for approved recycling facility location details ECDC Environmental Landfill Recordkeeping Maintain logs, manifests, and waste documentation at the facility or nearest office for a minimum of 5 years. CPX Piceance Holdings, LLC Waste Management Plan Well Pad 36A 19 November 2022 Frac Sand Waste Description Sand that is used in hydraulic fracturing treatment to prop open the artificially created or enhanced fractures once the treatment is completed. Classification E&P Exempt Classification Basis Exempt for oil and gas production under EPA Regulatory Determination Federal Register Vol. 58, No 53, but may be classified as Hazardous if mismanaged. COGCC Rule Reference COGCC Rule 905 Handling/Storage Used frac sand will be stored in bermed containment onsite. It will be hauled off site for disposal by Greenleaf Environmental Services. Labeling Label with contents. Required Sampling/Analysis for Classification Status None Required Logs, Manifests, Notifications Use the state specified method of shipment for E&P Waste (required manifest or standard bill of lading). Transportation Waste must be transported by an authorized and certified transporter. Disposal Can be disposed of at an approved E&P exempt waste landfill. Approved Disposal Vendors Frac sand will be disposed of offsite. Greenleaf Environmental Services Refer to Attachment A for approved recycling facility location details Recordkeeping Maintain logs, manifests, and waste documentation at the facility or nearest office for a minimum of 5 years. Volume Per Well Estimated For Well Pad 36A 0.25 cubic yard 8.0 cubic yards CPX Piceance Holdings, LLC Waste Management Plan Well Pad 36A 20 November 2022 Oil Contaminated Debris Waste Description Oily rags, oil pads and booms generated from equipment maintenance and spill response procedures Classification E&P Exempt Classification Basis Exempt for oil and gas production under EPA Regulatory Determination Federal Register Vol. 58, No 53, but may be classified as Hazardous if mismanaged or contaminated with non-exempt waste. COGCC Rule Reference COGCC Rule 905 Handling/Storage Waste must be drained of all liquids. Containerize liquids in drums. Deposit oil contaminated debris in rain-proof, leak-proof containers. Keep containers closed when not in use. Store containers in designated non-hazardous waste storage areas that reduce the potential for release. Labeling Label with contents. Required Logs, Manifests, Notifications Use the state specified method of shipment for E&P Waste (required manifest or standard bill of lading). Transportation Waste must be transported by an authorized and certified transporter. Disposal Disposed of at an approved E&P exempt waste landfill. Approved Waste Disposal Facilities Greenleaf Environmental Services Refer to Attachment A for approved recycling facility location details ECDC Environmental Landfill Recordkeeping Maintain logs, manifests, and waste documentation at the facility or nearest office for a minimum of 5 years. CPX Piceance Holdings, LLC Waste Management Plan Well Pad 36A 21 November 2022 Produced Solids and Tank Bottoms Waste Description All sediments/sand/sludge/salt removed from the bottoms of tanks or vessels when periodically cleaned out. Classification E&P Exempt Classification Basis Exempt for oil and gas production under EPA Regulatory Determination Federal Register Vol. 58, No 53, but may be classified as Hazardous if mismanaged. If waste material contains TENORM, it must be treated as TENORM waste. COGCC Rule Reference COGCC Rule 905 Handling/Storage Containerize in rain-proof and leak-proof containers that are compatible with waste stored therein. Keep containers closed when not in use. Store containers in designated non-hazardous waste storage areas that reduce the potential for release. Labeling Label with contents. Required Sampling/Analysis for Classification Status Check for TENORM before sending to disposal facility. Required Logs, Manifests, Notifications Use the state specified method of shipment for E&P Waste (required manifest or standard bill of lading). Transportation Waste must be transported by an authorized and certified transporter. Disposal Greenleaf Services Refer to Attachment A for approved recycling facility location details ECDC Environmental Landfill Approved Waste Disposal Facilities Refer to Attachment A for a list of approved waste disposal facilities. Recordkeeping Maintain logs, manifests, and waste documentation at the facility or nearest office for a minimum of 5 years. CPX Piceance Holdings, LLC Waste Management Plan Well Pad 36A 22 November 2022 Produced Water Waste Description Water collected during the process of extracting and dewatering oil and gas. Classification E&P Exempt Classification Basis Exempt for oil and gas production under EPA Regulatory Determination Federal Register Vol. 58, No 53. COGCC Rule Reference COGCC Rule 905 Handling/Storage Containerize in rain-proof and leak proof containers, tanks or permitted evaporation ponds that are compatible with waste stored therein. Keep containers closed when not in use. Tanks and containers should be constructed to reduce the potential for release. Labeling Label with contents. Required Sampling/Analysis for Classification Status Table 915-1: Benzene, Ethylbenzene, Xylene, and 1,3,5-trimethylbenzene Required Logs, Manifests, Notifications Use the state specified method of shipment for E&P Waste (required manifest or standard bill of lading). Transportation Waste must be transported by an authorized and certified transporter. Disposal CPX submitted for approval an application to convert an existing well on Well Pad 25A to a UIC injection well for disposal of flowback and produced water from operations on TPR. As a contingency, CPX will utilized Greenleaf Environmental Services if the proposed well is not approved. Approved Waste Disposal Facilities CPX operated UIC Injection well (TPR #176-25) – Upon Approval Refer to Attachment A for approved waste disposal facility location details Greenleaf Environmental Services Recordkeeping Maintain logs, manifests, and waste documentation at the facility or nearest office for a minimum of 5 years. CPX Piceance Holdings, LLC Waste Management Plan Well Pad 36A 23 November 2022 Scrap Metal Waste Description Used metallic equipment, tanks, piping and other materials. Classification Non-Hazardous Classification Basis Non-Exempt for oil and gas production under EPA Regulatory Determination Federal Register Vol. 58, No 53. Does not meet the criteria for hazardous waste as defined by 40 CFR 261 COGCC Rules Reference COGCC Rule 906 Handling/Storage None Labeling None Required Sampling/Analysis for Classification Status None Required Logs, Manifests, Notifications Bill of Lading or Non-Hazardous Waste Manifest. Transportation Waste must be transported by an authorized and certified transporter. Recycling Recycle at an approved recycling facility (scrap metal dealer). Most scrap metal dealers will not accept metal contaminated with NORM. Approved Recycle Vendors Pacific Steel and Recycling Refer to Attachment A for approved recycling facility location details Recordkeeping Maintain logs, manifests, and waste documentation at the facility or nearest office for a minimum of 5 years. CPX Piceance Holdings, LLC Waste Management Plan Well Pad 36A 24 November 2022 Septic Waste Waste Description Water and human waste from toilets. Classification Municipal/Domestic Solid Waste Classification Basis Non-Exempt for oil and gas production under EPA Regulatory Determination Federal Register Vol. 58, No 53. Does not meet the criteria for hazardous waste as defined by 40 CFR 261 but may be hazardous if mixed with hazardous waste streams such as chemicals or solvents. COGCC Rules Reference COGCC Rule 906 Handling/Storage Flush only domestic wastes down the drains, never hazardous wastes or process waste waters. In remote locations without a sewer system, wastes should be directed to either a portable septic system or leak-proof container. Wastes are then shipped off site for disposal. Labeling None Required Sampling/Analysis for Classification Status None Required Logs, Manifests, Notifications None Transportation Waste must be transported by an authorized and certified transporter. Disposal As long as the waste consists of only domestic sewage, typical sink drain, and wash down water, the waste should drain to the septic system, if available. Containerized septic waste should be disposed of at an approved sewage treatment facility or municipal waste landfill. Approved Recycle Vendors Redi Services, LLC 2143 Airport Road Rifle, CO 81650 970-625-0233 https://rediusa.com Recordkeeping Maintain logs, manifests, and waste documentation at the facility or nearest office for a minimum of 5 years. CPX Piceance Holdings, LLC Waste Management Plan Well Pad 36A 25 November 2022 Soil Contaminated with Chemical or Lube Oil Waste Description Chemical or lube oil contaminated soils resulting from spills, leaks and other operational upsets. Classification Non-Hazardous (but potentially hazardous depending on contaminants) Classification Basis Non-exempt for oil and gas production under EPA Regulatory Determination Federal Register Vol. 58, No 53. May contain components that meet the criteria for hazardous waste as defined by 40 CFR 261 COGCC Rule Reference COGCC Rule 906 Handling/Storage Drain any excess chemical or lube oil from the soil. Containerize both the liquid and soil within separate rainproof, leak-proof containers. Keep containers closed when not in use and store in designated non-hazardous waste storage areas that reduce the potential for release. If classified as hazardous, dispose of as soon as possible. If you exceed 2204.6 pounds (1000 Kg) per month of hazardous waste, the storage time limit may change. Contact EHS Department for assistance. Labeling If non-hazardous, label contents. For example, “Non-Hazardous Lube Oil Contaminated Soil”. If hazardous, label as “Hazardous Waste”. Include contents, generator information and accumulation start date on label. Required Sampling/Analysis for Classification Status Soil contaminated with chemicals or lube oil may be hazardous. Analysis is required to confirm waste classification. Required Logs, Manifests, Notifications If non-hazardous, use Bill of Lading or Non-Hazardous Waste Manifest. If hazardous, a Uniform Hazardous Waste Manifest is not required, but is highly recommended for Very Small Quantity Generators. Hazardous waste from Small Quantity or Large Quantity Hazardous Waste Generators always requires a Uniform Hazardous Waste Manifest. Transportation Waste must be transported by an authorized and certified transporter. Disposal Non-Hazardous – Disposed of at an approved non-hazardous waste landfill. Hazardous - Disposed of at an approved hazardous waste landfill or at a non- hazardous waste landfill that accepts hazardous waste from a Very Small Quantity Generator. Approved Waste Disposal Facilities Greenleaf Environmental Services Refer to Attachment A for approved waste disposal facility location details Garfield County Landfill Recordkeeping Maintain logs, manifests, and waste documentation at the facility or nearest office for a minimum of 5 years. Meet reporting requirements prescribed by COGCC 900 Series rules. CPX Piceance Holdings, LLC Waste Management Plan Well Pad 36A 26 November 2022 Soil Contaminated with Oil, Condensate or Produced Water Waste Description Non-Refined Oil, condensate, or produced water contaminated soils resulting from spills, leaks or operational upsets. Classification E&P Exempt Classification Basis Exempt for oil and gas production under EPA Regulatory Determination Federal Register Vol. 58, No 53, but may be classified as Hazardous if mismanaged. COGCC Rule Reference COGCC Rule 905 Handling/Storage Drain any excess oil or produced water from the soil. Containerize both the liquid and soil within separate rainproof, leak-proof containers. Keep containers closed when not in use and store in designated non-hazardous waste storage areas that reduce the potential for release. Labeling Label with contents. Required Logs, Manifests, Notifications Use the state specified method of shipment for E&P Waste (required manifest or standard bill of lading). Transportation Waste must be transported by an authorized and certified transporter. Disposal Dispose of at an approved E&P exempt waste landfill. Approved Disposal Vendors Greenleaf Environmental Services Refer to Attachment A for approved waste disposal facility location details Garfield County Landfill Recordkeeping Maintain logs, manifests, and waste documentation at the facility or nearest office for a minimum of 5 years. Meet reporting requirements prescribed by COGCC 900 Series rules. CPX Piceance Holdings, LLC Waste Management Plan Well Pad 36A 27 November 2022 Spent Solvents Waste Description Solvents used for cleaning/maintenance including paint thinners, degreasers, methyl ethyl ketone (MEK), toluene, xylene, etc. Classification Hazardous Classification Basis Meets the criteria for hazardous waste as defined by 40 CFR 261 COGCC Rule Reference COGCC Rule 906 Handling/Storage Containerize in rainproof, leak-proof containers that are compatible with the solvents contained therein. Keep containers closed when not in use and store in designated hazardous waste storage areas that reduce the potential for release. Hazardous waste should be disposed of as soon as possible. If you exceed 2204.6 pounds (1000 Kg) per month of hazardous waste, the storage time limit may change. Contact EHS Department for assistance. Labeling Label as “Hazardous Waste”. Include contents (type of solvent), generator information and accumulation start date on label. Required Sampling/Analysis for Classification Status Some solvents may be non-hazardous. Refer to the material safety data sheet (MSDS) to confirm waste classification. Required Logs, Manifests, Notifications If non-hazardous, use Bill of Lading or Non-Hazardous Waste Manifest. If hazardous, a Uniform Hazardous Waste Manifest is not required, but is highly recommended for Very Small Quantity Generators. Hazardous waste from Small Quantity or Large Quantity Hazardous Waste Generators always requires a Uniform Hazardous Waste Manifest. Transportation Waste must be transported by an authorized and certified transporter. Disposal Disposed of at an approved hazardous waste landfill or at a non-hazardous waste landfill that accepts hazardous waste from a Very Small Quantity Generator. Approved Waste Disposal Facilities Safety-Kleen Refer to Attachment A for approved waste disposal facility location details Recordkeeping Maintain logs, manifests, and waste documentation at the facility or nearest office for a minimum of 5 years. CPX Piceance Holdings, LLC Waste Management Plan Well Pad 36A 28 November 2022 Well Workover and Completion Fluids Waste Description Well work fluids including completion, workover fluids Classification E&P Exempt Classification Basis Exempt for oil and gas production under EPA Regulatory Determination Federal Register Vol. 58, No 53, but may be classified as Hazardous if unused and contains hazardous components. COGCC Rule Reference COGCC Rule 905 Handling/Storage Store used fluids in evaporation ponds or tanks. Labeling Label with contents. Required Sampling/Analysis for Classification Status None Required Logs, Manifests, Notifications Use the state specified method of shipment for E&P Waste (required manifest or standard bill of lading). Transportation Waste must be transported by an authorized and certified transporter or via pipeline. Disposal CPX is concurrently seeking approval to convert an existing well to a UIC injection well for use in disposal. As a contingency, CPX will utilized Greenleaf Environmental Services if the proposed well is not approved. Approved Disposal Vendors CPX operated UIC Injection well (TPR #176-25) – Upon Approval Refer to Attachment A for approved waste disposal facility location details Greenleaf Environmental Services Recycling Flowback from completions can be treated at a COGCC approved facility to be recycled or re-used for additional stimulations at other pads. MSDS sheets will be maintained for any additives used in stimulation. Tanks will be labeled in accordance with COGCC regulations. Recordkeeping Maintain logs, manifests, and waste documentation at the facility or nearest office for a minimum of 5 years. CPX Piceance Holdings, LLC 34 S. Wynden Drive, Suite 240 Limited Impact Review Garfield County, Colorado Houston, TX 77056 TPR Well Pad 36A Article 9 Oil and Gas Permit Application Topsoil Protection Plan COGCC Rule 304.c.(14) TOPSOIL PROTECTION PLAN TPR Well Pad 36A November 2022 CPX Piceance Holdings, LLC (CPX) owns and operates Tepee Park Ranch (TPR) in Garfield County, Colorado. CPX has prepared this Topsoil Protection Plan for continued development of the existing Well Pad 36A on TPR. The sections below correspond to Colorado Oil & Gas Conservation Commission (COGCC) Rule 304.c.(14) to prepare a Topsoil Protection Plan consistent with Rule 1002 and COGCC guidance (March 25, 2022). 1.0 Disturbance Acreage Well Pad 36A is an existing natural gas well pad on an existing and established disturbed surface. The extent of the disturbed area is shown on the Form 2A, Construction Layout Drawing and Form 2A, Related Location and Flowline Map. The drawings show the Oil and Gas Location, access road, and proposed new off-location flowlines. The disturbance acreages are listed in Table 1 and are described below. Disturbance associated with the flowlines was described under the 2A permit approved for CPX’s Well Pad 25A. Table 1. Estimated Disturbance Acreages Oil and Gas Location – CPX does not propose to expand the existing Oil and Gas Location. The location was constructed in approximately 2008. The surrounding area is predominantly spruce/fir forest with an understory of native forbs and grasses. They include Kentucky bluegrass, blue wildrye, gooseberry currant, California valerian, common yarrow, tall ragwort, fishlake thistle, stinging nettle, fireweed, silvery lupine, slender wheatgrass, and smooth brome. The location has a stable cut slope on the east side and 2-foot-high earthen berms. The outside slopes of the berms are vegetated with approximately 80 percent cover. Working Pad Surface – CPX does not propose to expand the Working Pad Surface. It has a hardened surface with a top layer of aggregate. Soil is stockpiled surrounding the well pad. Approximately 15,380 cubic yards of soil salvaged from construction will be available for interim reclamation. It is protected for reuse from wind and water erosion by a stable 3.5:1 slope and vegetation. Topsoil was segregated for stockpiling and reuse for reclamation based on its color and texture because the soil is darker and contains less clay than the underlying soils. The topsoil was divided into protected areas on the outermost edges of the well pad to keep the topsoil intact, untracked, and uncontaminated. In each area, the topsoil was tracked and seeded by hand with broadcast seed using a Forest Service special blend seed mix that was in circulation at the time the well pad was developed. When the well pad i s reclaimed, the topsoil will be brought up from the fill slopes onto the pad for interim reclamation and reseeding. During final reclamation, topsoil will be brought up from the fill slopes and from areas of interim reclamation as the final layer to recon tour, reclaim, and seed the area. Access Roads – CPX does not propose to expand the access road. Tepee Park Ranch Road is a well-established private unpaved road that predates well development on TPR. It was originally constructed to support logging operations on TPR. The road is approximately 20 feet wide, crowned in the center for drainage, and has culverts draining to borrow ditches at approximately 600-foot intervals. Area Acres Description Oil and Gas Location 5.45 Existing Disturbance Working Pad Surface 2.06 Existing Disturbance Tepee Park Ranch Road 3.63 Existing Disturbance TOTAL NEW DISTURBANCE 0.00 CPX Piceance Holdings, LLC Topsoil Protection Plan TPR Well Pad 36A 2 November 2022 2.0 Soil Types The Natural Resource Conservation Service (NRCS) soil types are listed below. Existing Oil and Gas Location 104A: Haplocryolls-Cryaquolls complex, 0 to 15 percent slopes 331C: Woodrock-Angostura familes complex, 40 to 65 percent slopes Existing Tepee Park Ranch Road 104A: Haplocryolls-Cryaquolls complex, 0 to 15 percent slopes 220B: Angostura Family, 5 to 40 percent slopes 338B: Wetopa-Doughspon-Echemoor families complex, 5 to 40 percent slopes 449C: Tampico-Echemoor-Eyre families complex, 30 to 65 percent slopes A Soil Unit Map and NRCS soil unit descriptions are provided with the Form 2A application. 3.0 Soil Evaluation The Oil and Gas Location occurs in NRCS soil types 104A: Haplocryolls-Cryaquolls complex, 0 to 15 percent slopes, and 331C: Woodrock-Angostura familes complex, 40 to 65 percent slopes. An onsite soil pit evaluation was conducted on September 27, 2021. The evaluation was a visual and tactile field review using hand-dug soil pits in representative undisturbed soils adjacent to the location. The soil pits were dug to depths of up to 18 inches to assess topsoil, the A-horizon and B-horizon, and Munsell soil color characteristics. The results of the soil pit evaluation are shown in Table 2. The evaluation is illustrated in the attachments to this plan. Soil type 331C: Woodrock-Angostura families complex occurs only along a narrow area at the top of a steep cut slope. The top of the steep cut slope is not representative of salvaged topsoil or soil to be used for interim reclamation. Soil pits, therefore, were not dug at the top of the cut slope. In general, topsoil depth in the soil pit locations was identified based on root structure, organic content, and soil color and texture. Topsoil depths ranged from 13 to 14 inches. Organic matter was high. Soil texture in the A- horizon was silt loam and in the B-horizon rocky loam and channery loam. Table 2. Soil Pits 4.0 Soil Stockpile Location The soil stockpile locations are shown on the Form 2A, Construction Layout Drawing. Soil Pit 1 Soil Pit 2 Location 39.394349, -107.832728 39.394084, -107.831906 Soil Unit 104A: Haplocryolls-Cryaquolls 104A: Haplocryolls-Cryaquolls Topsoil Depth Approximately 14 inches Approximately 13 inches A-Horizon 14 inches silt loam 13 inches silt loam B-Horizon Rocky loam Channery loam Munsell Soil Color 10YR 2/1 7.5YR 3/2 CPX Piceance Holdings, LLC Topsoil Protection Plan TPR Well Pad 36A 3 November 2022 5.0 Soil Salvage The Oil and Gas Location previously disturbed an approximately 5.45-acre area with an approximately 2.06-acre Working Pad Surface. Soil salvaged during construction of the location will be used for interim reclamation. The soil was segregated at the edges of the Working Pad Surface. It is protected from wind and water erosion by a stable and partially vegetated 3.5:1 slope. CPX has further protected the soil stockpiles in the following ways: Contamination CPX has kept the area surrounding the stockpiles clear of equipment, stored materials, and vehicle parking. Compaction The stockpiles are placed at the edge of the Working Pad Surface to avoid the risk that equipment will be operated over the stockpile. Wind and Water Erosion The stockpiles are consolidated and mounded to minimize loose soils. They are located on portions of the Oil and Gas Location that promote natural drainage and avoid ponding and stormwater runnels. The stockpiles are stable and free from blowing soil. Vegetation An approximately 80 percent vegetative cover has established on the outside slopes of the stockpiles, which helps to promote soil microbial activity. The microbes provide a bank of viable seeds for native forbs and grasses for later germination. 6.0 Best Management Practices Best management practices (BMPs) for topsoil protection are described in Table 3. Table 3. Best Management Practices Short-Term • There will be no additional vegetation removal to prepare the Well Pad 36A Working Pad Surface for well development. • Salvaged topsoil will continue to be protected during well development by keeping the stockpile areas clear of equipment, stored materials, and vehicle parking. Long-Term • The soil stockpiles will be protected from compaction by continuing to isolate it from equipment operating on the Working Pad Surface. The stockpiles will be designated with staking and flagging. • The stockpiles will continue to be protected from wind degradation and erosion using stable 3.5:1 slopes to prevent loose soils while preventing stormwater from ponding or forming runnels on the stockpile. • Existing vegetation established on each stockpile will stabilize it, outcompete weeds, and promote soil microbial activity. • The stockpiles will be monitored and managed for weeds during weed management monitoring conducted at the Oil and Gas Location by the field operator. • CPX will implement a Weed Control Plan. CPX Piceance Holdings, LLC Topsoil Protection Plan TPR Well Pad 36A 4 November 2022 Attachments Construction Layout Drawing Soil Pit Location Map Soil Pit Cross Sections and Evaluation Weed Control Plan Bmp-nsuog g¢ Ped\ge AvaleL0Z Xd OH ZZOZISL/LL Section 36 T. 78S. R. 94W. Garfield County Proposed Sediment \ y % Trap with 6" Outlet Pipe to Lower Drainage Ditch Proposed Lined Exist. Oil \ % Diversion Ditch ost and \ Maintain Existing DH as Location Diversion Ditchs —a | Exist. Oil & a. NN \ Gas Location oo ~ \ a eee: 3 ; ae ° . io ee —— ° re : r Lae ee — Da . | GRAPHIC SCALE IN FEET or: i . \. ——— ae 1 INCH = 60 FEET — : EZ a la Exist. Topsoil Area 3 = A g : ¢ t, & Contour Interval = 2 ft. fl: = 425'x56', 10.5' max depth 9350 Easing x 3 \Y D \ i / 2 ___ (£2,330 cy) Sediment Trap Exist. Topsoil Area 2 | 1 (4 fe Za ; . . . : v—--- v te ey Le £142'x83', 6.3' max depth ~, Exist. Lined J | eos —— BE eee oo —pos | al; f (+950 cy) \ Proposed Diversion Ditch a —-_ | oS a “\ — | Sediment Trap / em — ak) \ TC J Edge of Working 2' Earthen Berm — ia y) Pad. Surface L / ( Existing A : > 2 Drain Pipe re) oo > 5 ! | . > AQ : / > : ~ Q “\ INN 3 goal BES gent / a | \ = N > = b cyst © aA 3 me & | i S 8 & ae) 320 a / / os ° 2 % oe ’ / Proposed Lined 3.5: ae . : . 3 357 | J / Diversion Ditch x, => | "| JSF > Exist. Pad Elev.: +9355 3 oa Pa : / | | o & a / > ‘ ° wo i N Az. 27.10 FSFESPFSPPT PSHE SPS. 8 _— Df \ 113’ 105' £ 15'© 15" 117’ 4 a \Y EXISTING WELL DATA: : > \ 5 a AZ WELL NORTHING EASTING | \ 3 8 —s yo a i TPR 132-36 1577222.4 2341062.9 9379 > ‘ ral = NS ee CNDCTR #2 1577208.4 2341055.8 : \ a g Exist, ficcess Rdad CNDCTR#3 1577195.4 2341049.1 > S — ol 8 ; Drive Over | Berm | 4 o= 380 | — ——— a we ee Edge of Working 9 <=" A r i _.. : _ ih a— Pad Surface \ : DISTURBANCE AREAS _ Z aN Oil and Gas Location 5.45 ac =a i 2 £2. __..—« Propased,Cutings Pit... aovess Road 30.020 19' Depth (8,320 bbl) Y Maintain Existing Sediment Trap 9390 a 9309 *Notes 9370 1) Excavation of Cuttings Trench is the Only Nz Construction Anticipated at this Location. 7 roy 9380 2) Pit Interior Slope: 1:1 RS N 9390 3) 20% Swell Factor Applied to Earthwork Cut Volume. Qg 9400 4 oa'0 ESTIMATED EARTHWORK QUANTITIES (cy) _ ITEM CUT FILL | TOPSOIL | EXCESS 9420 ——— 9430 PAD 0 0 0 0 a — SSeS SS TRENCH] 9,990 | 210 9,780 Exist. Oil and Gas Location 9430 TOTALS] 9,990 210 0 9,780 9440 REVISED, 11/15/22 Construction Plan Prepared for: SCALE: 136 East Third Street Rifle, Colorado 81650 = DATE: Ph. (970) 625-1330 = Fax (970) 625-2773 : ——— PROJECT: Survey Services, Inc. iii PN =60 co CPX Piceance Holdings, LLC 2/28/21 = Cx TPR Well Pad 36A CONSTRUCTION LAYOUT DRA WING PLAN VIEW cs 11/15/2022 K:\CPX 2018\PAD 36\Pad 36 Constr.dwg Oil and Gas Location 5.45 ac19' Depth (8,320 bbl) Existing Well Pad 36A 104A 104A 104A 331C 36A Soil Pit 1 Topsoil Depth: 14" 36A Soil Pit 2 Topsoil Depth: 13" Section 36 Legend Working Pad Surface Oil and Gas Location Forest Service Road Private Road Forest Service Jurisdiction Parcels NRCS Soil Survey Soil Map Unit Soil Map Unit Description 104A: Haplocryolls-Cryaquolls complex, 0 to 15 percent slopes 331C: Woodrock-Angostura families complex, 40 to 65 percent slopes CPX Piceance Holdings, LLC Tepee Park Ranch Well Pad 36A Soil Pit Location Map Garfield County SW1/4NE1/4 Sec. 36, T7S R94W, 6th P.M. Date 10/18/22 Aota Technical, LLC 0 25 50 75 100 Feet Data Source: COGCC GIS Online Natural Resources Conservation Service. Web Soil Survey Top Edge of Cut Slope Figure 1. CPX Piceance Holdings, LLC Well Pad 36A Soil Pit 1: Pit excavated adjacent to the Oil and Gas Location; sample collected from 0-18”. Location Coordinates Munsell Color A Horizon B Horizon 39.394349, -107.832728 10YR 2/1 14” Silt Loam Rocky Loam A B Figure 2. CPX Piceance Holdings, LLC Well Pad 36A Soil Pit 2: Pit excavated adjacent to the Oil and Gas Location; sample collected from 0-18”. Location Coordinates Munsell Color A Horizon B Horizon 39.394084, -107.831906 7.5YR 3/2 13” Silt Loam Channery Loam A B B WEED CONTROL PLAN November 2022 CPX Piceance Holdings, LLC (CPX) owns and operates Tepee Park Ranch (TPR) in Garfield County, Colorado. CPX has prepared this Weed Control Plan as part of continued development TPR. The Weed Control Plan supplements the Topsoil Protection Plans required under Colorado Oil & Gas Conservation Commission (COGCC) Rule 304.c.14. Topsoil Protection Plan guidance issued by COGCC (March 25, 2022) instructs that Topsoil Protection Plans include weed prevention best management practices (BMPs). In addition to BMPs, this Weed Management Plan also includes Identification, Prevention, Control, and Monitoring for weeds, as described below. 1.0 Weed Identification and Existing Conditions TPR performs identification of noxious weeds and weed infestations through site survey and during routine operations and maintenance. A site survey was conducted on TPR on September 27, 2021. There were no noxious weeds or weed infestations observed at existing Oil and Gas Locations or along the access road during the survey. There were scattered Canada thistle observed along the proposed flowline corridor between existing Well Pads 25A and 36A. Canada thistle is a List B species, according to the Colorado Department of Agriculture. The state, in consultation with local governments, develops weed management plans designed to stop the continued spread of List B species. CPX’s Operations Manager and Field Operator are experienced with weed identification during routine operation and maintenance of the Oil and Gas Location, access road, and flowline corridors. The noxious weed list provided by the Garfield County Vegetation Management Department is shown in Table 1. To assist individuals in the field, Garfield County provides electronic access to species -specific Identification and Management sheets prepared by the Colorado Department of Agriculture, Conservation Services Division. Each sheet provides photographs, descriptions, and physical characteristics of the weed species, including key identifiers. The sheets enable CPX staff to clearly identify a weed species and to distinguish between similar species. Table 1. Garfield County Noxious Weed List and Classifications Common Name Common Name Common Name Absinth wormwood (B) Black henbane (B) Bouncingbet (B) Bull thistle (B) Canada thistle (B) Chicory (C) Chinese clematis (B) Common burdock (C) Common tansy (B) Common teasel (B) Corn chamomile (B) Curly dock (Not designated) Cutleaf teasel (B) Cypress spurge (A) Dalmatian toadflax (B) Dame’s rocket (B) Diffuse knapweed (B) Hoary cress (B) Houndstongue (B) Jointed goatgrass (B) Leafy spurge (B) Mayweed chamomile (B) Meadow knapweed (A) Mediterranean sage (A) Musk thistle (B) Myrtle spurge (A) Oxeye daisy (B) Perennial pepperweed (B) Plumeless thistle (B) Poison hemlock (C) Purple loosestrife (A) Russian knapweed (B) Russian olive (B) Salt cedar (B) Scentless chamomile (B) Scotch thistle (B) CPX Piceance Holdings, LLC Weed Control Plan 2 November 2022 Source: Garfield County Vegetation Management Department 2.0 Prevention The Colorado Department Agriculture established at C.R.S. 35-5.5-102 an organized and coordinated effort to stop the spread of noxious weeds. The rules classify noxious weeds into four categories: A – Rare noxious weeds subject to eradication as a matter of law whenever they are detected . B – Specified populations are subject to eradication, containment, or suppression in identified areas of the state to deplete the seed source. C – Widespread and well-established species for which the state recommends but does not require control, although Garfield County may. Watch List – A non-regulatory and advisory list to increase awareness of new invasive species in the state. Canada thistle is a List B species. Its control is described in Section 3.0. CPX performs noxious weed management in accordance with the Noxious Weed Management Plan (February 16, 2016) issued by Garfield County. CPX’s general prevention methods for noxious weeds are to avoid or minimize ground disturbance where noxious weeds may outcompete native vegetation in disturbed soil. CPX also avoids cross country travel on TPR, which can introduce seeds to previously undisturbed locations. Frequent monitoring and treatment of identified infestations is used to limit the spread of noxious weeds. When seeding disturbed areas, CPX uses certified weed-free seed mixes recommended by the adjacent U.S. Forest Service. The seed mixes represent native species that are most likely to proliferate and be sustainable. 3.0 Control For control of Canada thistle, the Colorado Department of Agriculture recommends combining control methods to continually stress the plant and exhaust root nutrient stores. This includes mechanical suppression by mowing every 10 to 21 days during the growing season and application of a fall herbicide. In general, integrated weed management and control can be accomplished through a combination of mechanical and chemical controls, potential biological controls, and education. Mechanical control is labor intensive. CPX finds mechanical control through mowing or hand pulling best suited to smaller or linear areas. Chemical control with herbicides is generally the most effective and targeted method to eradicate noxious weeds and disrupt their proliferation. CPX uses spot treatment and broadcast treatment of targeted areas using a recommended herbicide by weed species. Biological controls through the deliberate introduction of living agents, such as insects and grazing animals to reduce noxious weed populations, can be difficult to effectively target a specific area or corridor. CPX finds that biological control is most conducive to pasture or rangeland. Education is an effective tool for minimizing the introduction or spread of weed species. CPX educates personnel and contractors particularly on avoidance of unnecessary disturbances and unnecessary cross country travel that may introduce spores from vehicle tires. Common Name Common Name Common Name Spotted knapweed (B) Sulfur cinquefoil (B) Yellow starthistle (A) Yellow toadflax (B) CPX Piceance Holdings, LLC Weed Control Plan 3 November 2022 4.0 Monitoring For Canada thistle, the Colorado Department of Agriculture weed control sheets adopted by Garfield County recommend monitoring for new infestations to prevent, rather than treat, the species. In general, CPX regularly monitors and maintains its oil and gas facilities, including well pads, well pad disturbances, flowline corridors, and access roads. The presence of weed infestations and noxious weeds is noted for appropriate treatment using the controls described above. The treated locations are reinspected to identify where infestations may not have been adequately suppressed and require additional mechanical or chemical treatment. 5.0 Best Management Practices Best management practices (BMPs) for weed control are listed in Table 2. Table 2. Best Management Practices Best Management Practice Maintain existing vegetation to outcompete weeds and promote healthy native vegetation. Monitor and manage Oil and Gas Locations, flowline corridors, and access roads for weeds as part of routine facility inspection and maintenance. Use certified weed-free seed mixes and mulches. Broadcast or hydroseed seed mixes recommended by the U.S. Forest Service Native Plant Materials Program to optimize successful establishment of vegetation. Limit cross-country travel to minimize introduction of noxious weed spores. Avoid unnecessary disturbances that require revegetation and weed control. CPX Piceance Holdings, LLC 34 S. Wynden Drive, Suite 240 Limited Impact Review Garfield County, Colorado Houston, TX 77056 TPR Well Pad 36A Article 9 Oil and Gas Permit Application Stormwater Management Plan COGCC Rule 304.c.(15) STORMWATER MANAGEMENT PLAN Well Pad 36A November 2022 CPX Piceance Holdings, LLC (CPX) owns and operates Tepee Park Ranch (TPR) in Garfield County, Colorado. CPX has prepared this Stormwater Management Plan for the continued development of the existing Well Pad 36A on TPR. The sections below correspond to the Colorado Oil & Gas Conservation Commission (COGCC) requirement in Rule 304.c.(15) to prepare a Stormwater Management Plan consistent with Rule 1002.f. 1.0 Proposed Operations and Site Description 1.1 Proposed Operations CPX proposes the continued development of the existing Well Pad 36A on TPR. The Well Pad is located approximately 12 miles south of Rifle, Colorado in the SW ¼ NE ¼ Section 36, Township 7 South, Range 94 West. It is at an elevation of 9,355 feet. TPR is privately owned and operated by CPX, predominantly for the exploration and development of natural gas. Well Pad 36A contains three previously permitted wells. Well 132-36 was spud but not completed (DG). Wells 143- 36 and 112-6 have expired permits (EP). 1.2 Site Description Well Pad 36A is shown on the Location Drawing submitted with the Form 2A application. It is located on private property owned by CPX. The area is zoned Rural by Garfield County. This portion of TPR is bounded by U.S. Forest Service land to the north, south, and east. The surrounding area is predominantly spruce/fir forest with an understory of native forbs and grasses. They include Kentucky bluegrass, blue wildrye, gooseberry currant, Californ ia valerian, common yarrow, tall ragwort, fishlake thistle, stinging nettle, fireweed, silvery lupine, slender wheatgrass, and smooth brome. Beaver Creek, a perennial waterbody, flows from south to north across TPR . The creek is between approximately 130 to 223 feet downgradient to the west of Well Pad 36A. The well pad is separated from the creek by a compacted 2-foot earthen berm, lined stormwater collection trench, and vegetated buffer area. TPR is accessed using approximately 1.5 miles of the existing 20-foot-wide unpaved private Tepee Park Ranch Road. Three existing off-location flowlines are buried in a shared trench from CPX’s existing Well Pad 25A to CPX’s Pad 2 Tanks in Section 13, Township 7 South, Range 94 West. The off-location flowlines transport natural gas, condensate, and water. New off-location buried flowlines for natural gas, condensate, and water are proposed between Well Pad 25A and Well Pad 36A. The flowline trench was described in the approved 2A permit issued for Well Pad 25A. 2.0 Nature and Sequence of Activities 2.1 Construction CPX does not propose to expand Well Pad 36A. An additional 4 to 6 inches of aggregate will be added to the well pad surface to support drilling equipment. CPX is proposing to use permitted Well Pad 25A as a remote frac support pad for SIMOPs during drilling on Well Pad 36A. Alternatively, equipment will be located on Well Pad 36A. The permitted Temporary Water Support Pad 25B will provide storage for recycled produced water and water from well completions to use during well development on Well Pad 36A. Its location is shown on the attached Related Location and Flowline Map. CPX Piceance Holdings, LLC Stormwater Management Plan Well Pad 36A 2 November 2022 A drill cuttings trench will be constructed on Well Pad 36A. Water-based bentonite drill cuttings that are generated at Well Pad 36A will be stored temporarily in a bermed area on the well pad. Drill cuttings will be transferred to the cuttings trench, mixed with clean soil derived from excavation of the cutting trench, and sampled for the constituents in Table 915-1 before final burial with 3 feet of cover. Additional stormwater control from a drive-over berm will be installed at the entrance of the well pad. The proposed operations, disturbance areas, and schedule are listed in Tables 1 through 3. Table 1. Proposed Operations Location Description Well Pad 36A TPR 132-36 (DG) proposed for plugging and abandonment TPR 143-36 and 112-6 (EP) Proposed 32 natural gas wells Permitted Well Pad 25A Proposed SIMOPs Permitted Water Support Pad 25B Temporary water support pad Table 2. Disturbance Areas Area Acres Description Oil and Gas Location 5.45 Existing Disturbance Working Pad Surface 2..06 Existing Disturbance Well Pad After Interim Reclamation 1.34 Existing Disturbance Well Pad Reclaimed Area 4.11 Existing Disturbance Tepee Park Ranch Road 3.63 Existing Disturbance TOTAL NEW DISTURBANCE 0.00 Table 3. Anticipated Schedule Location Schedule Construction 1 month Drilling 8 months Completions 8 months Interim Reclamation 1 month Production 30 years 2.2 Drilling CPX proposes to use the existing Oil and Gas Location and access roads for well drilling. A closed-loop drilling system will be used for well drilling with a water-based drilling mud. Drill cuttings will be placed in the drill cuttings trench described above and in a temporary bermed staging area on the well pad before composite sampling and receipt of lab analysis results. The drill cuttings will be buried on site in the drill cuttings trench. Equipment for well drilling is shown on the Drill Rig Layout attached to this Plan. 2.3 Completions Anticipated major equipment for completions is listed on the Well Completion and Stimulation Layout attached to this Plan. The equipment will be removed when well completions are finished. Recycled produced water for completions is anticipated to be delivered to TPR using CPX’s bidirectional water flowline. CPX will dispose of water using its proposed UIC disposal well on Well Pad 25A and trucking to a third-party commercial disposal facility. CPX will store water on the permitted Temporary Water Support Pad 25B. The pad will contain recycled produced water and water from well completions to use for subsequent completions. CPX is proposing to use Well Pad 25A to store a portion of the equipment as a remote frac support pad for SIMOPs. Well Pad 25A and Pad 25B are shown on the attached Layout Drawings and the Form 2A Process Flow Diagram. CPX Piceance Holdings, LLC Stormwater Management Plan Well Pad 36A 3 November 2022 2.4 Interim Reclamation After well drilling and completions, the Well Pad 36A Working Pad Surface will be reduced through interim reclamation to approximately 1.34 acres. The area to be reclaimed will be ripped and seeded, as described in the Interim Reclamation Plan submitted with the Form 2A application. 2.5 Production During production, the well pad is anticipated to include the following major equipment: • 32 Natural Gas Wells • 1 Enclosed Combustion Device • 2 Condensate Tanks (300-bbl; 500-bbl) • 1 VOC Combustor • 2 750-bbl Produced Water Tanks • 1 Meter/Sales Building • 8 Quad 3-Phase Separators • 1 Instrument Air Skid • 2 Heater Treaters • 1 Low,1 High Pressure Knockout Vessel • 1 Gas Motor • Fuel Gas Scrubber • 3 Electric Motors • Condensate Transfer Pump • 1 Electric Generator • Produced Water Transfer Pump • 1 LACT Unit Tanks to support production will be located inside of steel secondary containment sized to contain 150 percent of the volume of the largest tank, consistent with Rule 603.o. The new and existing water, condensate, and natural gas flowlines will be used to transport liquids and natural gas to CPX’s Pad 2 Tanks in Section 13. CPX will use wellhead telemetry to support production. CPX’s Spill Prevention Control and Countermeasure (SPCC) Plan will be updated and maintained for the location. The wells are expected to be in production for approximately 30 years, based on the average life of a well in this area. 3.0 Supplemental Site Information 3.1 Disturbance Area The existing Oil and Gas Location is approximately 5.45 acres. The existing Working Pad Surface is approximately 2.06 acres. Cut and fill work to prepare the well pad is complete. The well pad fill slopes have 2-foot-high earthen berms, which are compacted to 95 percent soil/moisture density. The outside slopes of the berms have 80 percent vegetative cover. The well pad has been in use since approximately 2008. 3.2 Soil Description and Erosion Potential The Natural Resources Conservation Service Map Units indicate that the soil types for the Oil and Gas Location are 104A: Haplocryolls-Cryaquolls complex, 0 to 15 percent slopes, and 331C: Woodrock-Angostura families complex, 40 to 65 percent slopes. For 104A, the A horizon is 0 to 20 inches of silt loam overlaying 20 to 60 inches of silt loam and clay loam to gravelly sandy clay loam. The soil is well drained. The depth to the restrictive feature is more than 80 inches. For 331C, which is present only at the top of the cut slope at the location, the A horizon is 1 to 3 inches of silt loam and loam overlaying 2 to 17 inches of loam and gravelly silt loam. The soil is well drained. The depth to the restrictive feature is 40 to 72 inches. The existing access road is proposed to be used under this OGDP. Its soil types are described in detail in the Dust Mitigation Plan submitted with the Form 2A application. 3.3 Vegetation Description There is no vegetation on the existing Working Pad Surface. The Well Pad berms have approximately 80 percent vegetative cover on the outside slopes to stabilize the berms. The seed mix was a broadcast seed using a U.S. Forest Service special blend in circulation at the time that the well pad was developed. CPX Piceance Holdings, LLC Stormwater Management Plan Well Pad 36A 4 November 2022 Vegetation in the reference area consists of spruce/fir forest with an understory of native forbs and grasses. They include Kentucky bluegrass, blue wildrye, gooseberry currant, California valerian, common yarrow, tall ragwort, fishlake thistle, stinging nettle, fireweed, silvery lupine, slender wheatgrass, and smooth brome. 3.4 Pre-disturbance Coverage Estimate The pre-disturbance coverage on the established Working Pad Surface is 0 percent. The pre-disturbance coverage in the reference area is 90 percent. 3.5 Known Weed Infestations There are no observed weed infestations or noxious weeds on the Oil and Gas Location. The surrounding area does have select areas of Canada thistle under active management by CPX. Canada thistle is a List B species, according to the Colorado Department of Agriculture. The state, in consultation with local governments, develops weed management plans designed to stop the continued spread of List B species. 3.6 Non-stormwater Discharges There will be no non-stormwater discharges from the Oil and Gas Location. 3.7 Receiving Waters The nearest surface water is Beaver Creek, which is approximately 130 to 223 feet west of Well Pad 36A. 4.0 Potential Pollution Sources and Control Measures Potential pollution sources, including those in Rule 1002.f, are listed below, together with how they are addressed through control measures. 4.1 Well Pad Well Pad 36A has no uncontrolled stormwater on the well pad. The well pad has a 6-inch-diameter drain on the well pad. The drain is piped outside of the berm to a lined trench. The lined trench drains to a lined catchment basin. Solids settle in the catchment basin for removal. The stormwater evaporates. The well pad fill slopes have 2-foot-high earthen berms, which are compacted to 95 percent soil/moisture density. The outside slopes of the berms have 80 percent vegetative cover. The berms are stable with high structural integrity. A drive-over berm will be installed at the entrance of the pad for additional stormwater control. An additional 4 to 6 inches of aggregate will be added to the pad surface to support drilling equipment. 4.2 Soil Stockpile There are existing soil stockpiles at the edges of the well pad, as shown on the attached Construction Layout. Topsoil was salvaged during construction of Well Pad 36A to use during interim reclamation. The soil stockpiles are protected from wind and water erosion by a stable 3.5:1 slopes and vegetation. 4.3 Access Road The existing unpaved access road is surface hardened. The Tepee Park Ranch Road is crowned and has a borrow ditch on the upslope side for stormwater drainage. Stormwater is diverted to 18-inch and 24-inch culverts placed at 600-foot intervals along the roadway. Frequent culverts prevent erosion by avoiding long runs of stormwater and slowing velocity. 4.4 Well Drilling and Completion Equipment A closed-loop drilling system will be used with a water-based drilling mud. Proppant used during completions will be hauled to the location in a closed container truck. Offloading will occur within secondary containers around the proppant storage silos. Containment will be a rubber or plastic liner with 8 -inch supported sides. During well drilling, CPX Piceance Holdings, LLC Stormwater Management Plan Well Pad 36A 5 November 2022 the drill rig will have a liner under the rig to monitor for and contain drips or leaks. The drill rig will have an integrated fuel tank. Vehicles will not be fueled on site. 4.5 Tank Battery The steel secondary containment will be sized to contain 150 percent of the largest tank. The secondary containment liner is anticipated to be sprayed in to optimize its seal. Tank battery loading and unloading operations otherwise have been relocated to CPX’s Pad 2 Tanks, approximately 4.25 miles from Pad 36A. 4.6 Compressor An air package compressor will be used during well drilling. It will be skid-mounted and powered with diesel fuel using self-contained integrated fuel storage and containment. 4.7 Flowlines Freshwater for well drilling will be trucked directly to Well Pad 36A using bobtail trucks offloading to freshwater tanks at the drill rig. Water for completions will be recycled water from third-party operations. It will be delivered to Pad 25B using the existing water pipeline from CPX’s Pad 2 to Well Pad 25A and a temporary surface frac line from Well Pad 25A to Pad 25B. The temporary surface frac line to Pad 25B and other frac lines to Well Pads 25A and 36A are proposed to be 4-inch-diameter steel frac lines. Frac support equipment on Well Pad 25A would require adequate water pressure using a high horsepower system on Well Pad 25A. Water pumped between locations otherwise would use a trailer-mounted pump on Pad 25B. During production, the buried natural gas, condensate, and water flowlines between Well Pads 25A and 36A are expected to consist of a 12-inch-diameter steel natural gas flowline; 2-inch-diameter steel condensate flowline, and 5-inch-diameter bidirectional flexpipe water flowline. The flowlines were described in the approved 2A permit issued for Well Pad 25A. 4.8 Chemicals and Materials The location will have fuel, oils, lubricants, and coolants for powered equipment and maintenance. Concrete, sealants, and solvents will be used. Materials will be properly contained, stored, labeled, and disposed of. Spill kits will be available for use. An inadvertent spill will be properly cleaned up and reported as require d under COGCC rules. Concrete washout areas will be identified and protect ed using BMPs to prevent the discharge of concrete. Concrete will not be washed onto topsoil. Garbage and construction debris will be generated and properly contained and hauled off site to a location authorized to accept the waste. The wells will be drilled using a water-based drilling mud. Proppant used during completions will be hauled to the location in a closed container truck. The truck will be a semi hauling an aluminum trailer. Three cones on the trailer will be full of proppant, and an air compressor will be used to push the proppant out of the truck. Dust control will consist of filtering the proppant when loading the truck and filtering again when dispensing the proppant into silos on the location. Chemicals and support materials will be skid-mounted with containment. 4.9 Fueling A temporary fuel tank for well drilling equipment will have integrated secondary containment. Vehicles will not be fueled on site. 4.10 Storage Materials will consist of piping offloaded as it is needed onto a centralized drill rack and pipe area. CPX Piceance Holdings, LLC Stormwater Management Plan Well Pad 36A 6 November 2022 4.11 Processing Activities During production, the equipment listed in Section 2.5 will be located on Well Pad 36A. Processing and loadout otherwise will occur at CPX’s Pad 2 Tanks, approximately 4.25 miles away. 4.12 Significant Dust or Particulate Generating Processes Exposed soils will be avoided or minimized because Well Pad 36A and the access road have well-established and hardened surfaces. Particulates generated during well drilling will be controlled using fresh water. 5.0 Pollution Prevention 5.1 Erosion Protection Cut and fill work for Well Pad 36A is complete. The well pad was constructed in approximately 2008. The well pad surface and cut slopes are stable and compacted. The berms on fill slopes are compacted and vegetated. The well pad has no uncontrolled stormwater, as described in Section 4.1. 5.2 Secondary Containment Secondary containment will be in place for equipment and material used during well drilling, including liners under the drill rig and motors, secondary containment under all powered equipment, skid-mounted totes with containment, and containment around proppant silos. During operation, lined steel secondary containment will be used for storage tanks and will be sized to contain 150 percent of the largest tank. 5.3 Reclamation The 5.45-acre Oil and Gas Location will be reduced to approximately 1.34 acres after interim reclamation. Soil and topsoil will be replaced on areas not used for production. Those areas will be cross ripped, seeded or hydroseeded, and mulched, as described in the Interim Reclamation Plan submitted with the Form 2A application. 6.0 Structural and Non-Structural Practices 6.1 Structural Practices Structural best management practices (BMPs) are listed in Section 9.0. The well pad has a 6-inch-diameter drain that is piped outside of the berm to a lined trench. The trench drains to a lined catchment basin. The well pad has 2-foot high compacted and stable berms on fill slopes to further prevent stormwater runoff. The access road has a borrow ditch on the upslope side to capture stormwater drainage. Stormwater is diverted to 18-inch and 24-inch culverts placed at 600-foot intervals along the roadway. Storage tanks will have lined steel secondary containment sized to contain 150 percent of the largest tank. Temporary equipment and materials used during well drilling will have liners and secondary containment to prevent impacts from leaks or spills. The chemical tote containing a corrosion inhibitor during production has an integrated plastic tub with a lid for off-site disposal of any leaked fluid. 6.2 Non-structural Practices Loose material and packaging used during well development will be containerized to prevent blowing. Ingress, egress, and parking will occur in designated areas. Vehicles and equipment will be monitored for leaks during well development. Absorbents and spill response material will be made available to address inadvertent spills. The location will be monitored daily during well development and production. 6.2.1 Erosion Controls The well pad surface has been in place since approximately 2008. It is well compacted and has a surface layer of 1-inch aggregate base coarse screened to 3-inch minus. CPX will add an additional 4 to 6 inches of aggregate to support well drilling. CPX Piceance Holdings, LLC Stormwater Management Plan Well Pad 36A 7 November 2022 The well pad cut slope had been stabilized since approximately 2008. The well pad fill slopes have 2 -foot-high earthen berms, compacted to 95 percent soil/moisture density. The outside slopes of the berms have 80 percent vegetative cover. Stormwater controls on the well pad consist of the 6-inch-diameter drain on the well pad. The drain is piped outside of the berm to a lined trench. The trench drains to a lined catchment basin where solids settle for removal and the stormwater evaporates. The access road has a borrow ditch on the upslope side where stormwater is diverted to 18 -inch and 24-inch culverts placed at 600-foot intervals along the roadway. The flowline trench between Well Pads 25A and 36A was described in the approved 2A permit issued for Well Pad 25A. Interim reclamation will occur during the next favorable growing season after well drilling and completion. Revegetation will be monitored for growth and a vegetative cover that reflects 80 percent of the reference area condition. 6.2.2 Vehicle Tracking Control There will be no tie-in to paved surfaces to result in vehicle tracking. Well Pad 36A ties into the unpaved access road. The unpaved access road ties into the unpaved Forest Service Road 824. The access road is bladed and maintained to prevent rutting that would result in stormwater runoff from fines and sediments. 6.2.3 Materials Handling and Spill Prevention The nearest downgradient surface water is approximately 130 to 223 feet west of Well Pad 36A. Three levels of control prevent spills from impacting surface water. The primary control is the compacted and vegetated 2-foot-high earthen berm on the fill slope. The secondary control is the lined steel secondary containment system around the storage tank area, which is designed to contain 150 percent of the largest tank. The third control is the stormwater control system on the well pad with a stormwater drain piped to a lined trench and lined catchment system. Temporary equipment and materials used during well drilling and completion have additional controls. During well drilling, the drill rig and powered equipment will have liners. Other materials will have skid-mounted containment or totes. Spill response absorbents and booms will be stored on Well Pad 36A. CPX maintains a Spill Prevention, Control, and Countermeasure Plan for tanks located on TPR. Vehicles and equipment used on site will be properly maintained to prevent leaks and will be monitored for leakage. 6.2.4 Management of Waste Material A site-specific Waste Management Plan has been submitted with the Form 2A application to describe waste streams, containers and management, and final disposal. 7.0 Site-Specific Construction and Stormwater/Erosion Control Measures In accordance with COGCC guidance, this section refers to the Construction Layout Drawing and Facilit y Layout Drawing attached to this plan. 8.0 Inspection and Maintenance Procedures 8.1 Trained and Qualified Site Inspections Stormwater inspections will be conducted by personnel trained and qualified on the content of this Stormwater Management Plan and preventative measures, practices, controls, and maintenance in the field. The drilling CPX Piceance Holdings, LLC Stormwater Management Plan Well Pad 36A 8 November 2022 supervisor, operations manager, and field operator are experienced with stormwater management and maintenance practices from current operations. 8.2 Scope of the Inspection Stormwater inspections will review the Oil and Gas Location p erimeter; disturbed areas and reclaimed areas; equipment, material, and storage areas; and vehicle access. Inspections will look for evidence of soils or sediment leaving the location or access road. Inspections also will review the location for signs of erosion. Stormwater maintenance needs will be identified and addressed with needed follow up. 8.3 State and Local Inspection Requirements The operator will comply with construction stormwater management requirements administered by the Colorado Department of Public Health and Environment (CDPHE). 8.4 Inspection Procedures and Frequency The Oil and Gas Location will be monitored at an estimated frequency of daily during drilling, completion, and production. A documented stormwater inspection will be conducted at least every 14 days during operation and more frequently after significant storm or snowmelt events. The inspection frequency may be reduced to 30 days after interim reclamation. Inspections will ensure that erosion and sediment controls identified in this plan are maintained and functioning properly and that there is no evidence of movement of s oils, ponding, runnels, and erosion. During inspection, the site operator will monitor for evidence of erosion from the cut slope, berms, and road; material storage areas for evidence of leaks or spills; runoff from the well pad that is not adequately controlled by the trench and catchment; runoff from the road that is not adequately diverted to culverts; evidence of slumping along the flowline; and vegetative success from interim reclamation. Deficiencies identified during an inspection will be corrected using additional or replacement controls or housekeeping practices. 8.5 Reporting and Recordkeeping Requirements Recordkeeping will include conformance with recordkeeping requirements administered by CDPHE. During well drilling, stormwater records will be included with the drill operations records. During production, the site operator will record stormwater inspections and maintenance needs as part of the maintenance records for the location. 9.0 Site-specific Construction and Stormwater/Erosion Control BMPs Table 4 lists site-specific BMPs to control and minimize stormwater and sediment run-on and run-off. Table 4. Best Management Practices Structural • The well pad fill slopes will be controlled using the 2-foot-high earthen berms, compacted to 95 percent soil/moisture density. • Tank area secondary containment will use a lined steel containment system sized to contain 150 percent of the largest tank. • The well pad stormwater control system will be maintained. It consists of a 6-inch-diameter drain on the well pad, which is piped to a lined trench and lined stormwater catchment basin. • Temporary equipment and materials used during well drilling and completion will have liners and secondary containment. • The access road will be maintained with blading, a borrow ditch on the upslope side of the road to divert stormwater, and culverts placed along the roadway to channel stormwater. CPX Piceance Holdings, LLC Stormwater Management Plan Well Pad 36A 9 November 2022 Non-Structural • Ingress, egress, and parking will occur in designated areas on the well pad. • Waste materials will be bagged or containerized to avoid blowing and contact with precipitation. • Vehicles and equipment will be monitored for leaks during well development. • The well pad will be inaccessible to the public to prevent unauthorized access and excessive wear on access roads. • Spill response booms and absorbents will be containerized and available on site. • During well development and production, stormwater monitoring will occur daily. Areas that require correction for stormwater control will be addressed or repaired promptly. • During production, stormwater inspections will be performed at least every 14 days and every 30 days after interim reclamation. Inspections will occur more frequently after significant storm or snowmelt events, in accordance with CDPHE requirements. • Interim reclamation and revegetation will be performed during the first growing season after well drilling and completion. Attachments Layout Drawings Related Location and Flowline Map Bmp-nsuog g¢ Ped\ge AvaleL0Z Xd OH ZZOZISL/LL Section 36 T. 78S. R. 94W. Garfield County Proposed Sediment \ y % Trap with 6" Outlet Pipe to Lower Drainage Ditch Proposed Lined Exist. Oil \ % Diversion Ditch ost and \ Maintain Existing DH as Location Diversion Ditchs —a | Exist. Oil & a. NN \ Gas Location oo ~ \ a eee: 3 ; ae ° . io ee —— ° re : r Lae ee — Da . | GRAPHIC SCALE IN FEET or: i . \. ——— ae 1 INCH = 60 FEET — : EZ a la Exist. Topsoil Area 3 = A g : ¢ t, & Contour Interval = 2 ft. fl: = 425'x56', 10.5' max depth 9350 Easing x 3 \Y D \ i / 2 ___ (£2,330 cy) Sediment Trap Exist. Topsoil Area 2 | 1 (4 fe Za ; . . . : v—--- v te ey Le £142'x83', 6.3' max depth ~, Exist. Lined J | eos —— BE eee oo —pos | al; f (+950 cy) \ Proposed Diversion Ditch a —-_ | oS a “\ — | Sediment Trap / em — ak) \ TC J Edge of Working 2' Earthen Berm — ia y) Pad. Surface L / ( Existing A : > 2 Drain Pipe re) oo > 5 ! | . > AQ : / > : ~ Q “\ INN 3 goal BES gent / a | \ = N > = b cyst © aA 3 me & | i S 8 & ae) 320 a / / os ° 2 % oe ’ / Proposed Lined 3.5: ae . : . 3 357 | J / Diversion Ditch x, => | "| JSF > Exist. Pad Elev.: +9355 3 oa Pa : / | | o & a / > ‘ ° wo i N Az. 27.10 FSFESPFSPPT PSHE SPS. 8 _— Df \ 113’ 105' £ 15'© 15" 117’ 4 a \Y EXISTING WELL DATA: : > \ 5 a AZ WELL NORTHING EASTING | \ 3 8 —s yo a i TPR 132-36 1577222.4 2341062.9 9379 > ‘ ral = NS ee CNDCTR #2 1577208.4 2341055.8 : \ a g Exist, ficcess Rdad CNDCTR#3 1577195.4 2341049.1 > S — ol 8 ; Drive Over | Berm | 4 o= 380 | — ——— a we ee Edge of Working 9 <=" A r i _.. : _ ih a— Pad Surface \ : DISTURBANCE AREAS _ Z aN Oil and Gas Location 5.45 ac =a i 2 £2. __..—« Propased,Cutings Pit... aovess Road 30.020 19' Depth (8,320 bbl) Y Maintain Existing Sediment Trap 9390 a 9309 *Notes 9370 1) Excavation of Cuttings Trench is the Only Nz Construction Anticipated at this Location. 7 roy 9380 2) Pit Interior Slope: 1:1 RS N 9390 3) 20% Swell Factor Applied to Earthwork Cut Volume. Qg 9400 4 oa'0 ESTIMATED EARTHWORK QUANTITIES (cy) _ ITEM CUT FILL | TOPSOIL | EXCESS 9420 ——— 9430 PAD 0 0 0 0 a — SSeS SS TRENCH] 9,990 | 210 9,780 Exist. Oil and Gas Location 9430 TOTALS] 9,990 210 0 9,780 9440 REVISED, 11/15/22 Construction Plan Prepared for: SCALE: 136 East Third Street Rifle, Colorado 81650 = DATE: Ph. (970) 625-1330 = Fax (970) 625-2773 : ——— PROJECT: Survey Services, Inc. iii PN =60 co CPX Piceance Holdings, LLC 2/28/21 = Cx TPR Well Pad 36A CONSTRUCTION LAYOUT DRA WING PLAN VIEW cs 11/15/2022 K:\CPX 2018\PAD 36\Pad 36 Constr.dwg Oil and Gas Location 5.45 ac19' Depth (8,320 bbl) 212215 1820 19Suction Tank &MOC SkidBoilerProcess SkidMixing SkidMud P um pSk id s Proposed LinedDiversion DitchProposedSediment TrapDrive OverBermExist. Oil and Gas LocationProposed Cuttings Pit19' depth (±8,320 cy) 21433213241311125126897Skidding RailSkidding RailPDS3D Catwalk DRILLINGFLOORUtilitty ShedVFD HOUSEDiesel Tank Proposed LinedDiversion DitchExist. Oil andGas LocationSee Drilling Cellar Detailfor Well DesignationsProposed SedimentTrap with 6" Outlet Pipeto Lower Drainage DitchCuttings ManagementAreaExcess Soil Stockpile(±9,780 cy)Shale ShakerDragon FireGen. House 14 1716 12345678910111213141516ABDATE:DRAWN BY:DESIGNED BY:PROJECT:FEET1 INCH =0GRAPHIC SCALE IN FEET8080Contour Interval = 2'11/29/22CPXJASTPP- LEGEND -1. WASTE WATER ABOVEGROUND TANK (1500 gal)2. POTABLE WATER ABOVEGROUND TANK (3360 gal)3. PORTABLE TOILETS4. WILDLIFE - PROOF DUMPSTER5. COMPANY MAN HOUSING6. DIRECTIONAL HOUSE7. MUD ENGINEERING - SOLIDS8. TOOL PUSHER SHED9. CHANGE HOUSE10. UTILITY SHED (NOT USED ON THIS SITE)11. AIR HANDLER12. OFFICE13. FLARE STACK14. MUD STORAGE TANKS (6)15. DeWATER TANK16. CEMENT WATER TANKS (2)17. CEMENT TANKS (2)18. BAR TANK19. GELL TANK20. PREMIX TANK21. DRYING SHAKERS22. CUTTINGS TANK23. SEPARATORS (2 - 10'x8')24. AIR FUELSW1/4SE1/4 Section 36T. 7 S., R. 94 W.Garfield CountyExisting Oil & Gas LocationEdge of WorkingPad SurfaceTemporary Pad BermPROPOSED WORKING PAD SURFACETEMPORARY PAD BERMEXISTING OIL & GAS LOCATIONDRIVE OVER BERM Exist. Access Road123456789 10 11 12 13 14 15 16 17 18 ^^^^^^^^^^^^^^^^^^^^F 9.9'F 6.5'F 14.7'F 10.1'F 13.2'F 14.8' Exist. A cc e ss R o a d 7+008+009+0090'70'C 21.7' C 18.2' C 17.3' C 18.4'915091609170914091809 1 3 0 91409150916091709180 9090909091009110910091109120910091009110912091309140 90909090DATE:DRAWN BY:DESIGNED BY:PROJECT:FEET1 INCH =0GRAPHIC SCALE IN FEET6060Contour Interval = 2'11/03/22CPXJASTPP- LEGEND -EXIST.SED TRAPEXIST.SED TRAPSW1/4SE1/4 Section 36T.7S, R 94 W.Garfield CountyPROPOSEDSED TRAPProposed Cuttings Trench19' Depth (±7,390 bbl)PROPOSEDDIVERSION DITCHPROPOSEDSED TRAPEXIST. DIVERSIONDITCHPROPOSED DIVERSIONDITCHExist. TPR 132-36 Exist. Conductor #1 Exist. Conductor #2 PRODUCTION GAS WELLEXISTING CONDUCTORDRIVE OVER BERMEXISTING WORKING PAD SURFACEPERIMETER BERMPROPOSED TANK MANIFOLDPROPOSED TRANSFER HOSEFRAC WATER SUPPLY (2-4.5 STEEL)PROPOSED FRAC LINES (2-4.5" STEEL)EXISTING OIL & GAS LOCATIONEXISTING ACCESS ROADEXISTING TOE TRENCHFRAC EQUIPMENTBLENDERFRAC PUMPFRAC PUMP MANIFOLDFRAC TANK (500bbl)SAND SILOSEE NOTE 6TANK BATTERY CONDENSATETRANSFERPUMPPIGLAUNCHERTANK VAPORSCOMBUSTORLIQUIDSKNOCK-OUTSALT WATERDISPOSAL EQUIPMENT:CHARGE PUMPSFILTERSINJECTION PUMPSSEPARATION EQUIPMENT:9 QUAD SEPARATORSFUEL GASSKIDINSTRUMENTAIRCOMPRESSORUTILITIES / CONTROLS:POWER GENERATIONPLC SITE CONTROLLERREMOTE TELEMETRYUNIT / RADIOBLOWDOWNCOMBUSTORHEATER TREATERSECONDARYCONTAINMENT:METALLIC WALLIMPERMEABLE LINERNotes:1. Exhibit depicts the preliminary frac equipment layout on Pad 25A (COGCC Loc ID: 334457) supporting remote well completion operations for the proposed wells on Pad 36A.2. Six (6) total tanks. Total Capacity 3,000bbls. Working Capacity 2,500bbls.3. Two-and one-half foot (2.5') high perimeter berm with a total site capacity of 55,400bbls. Perimeter berm capacity does not account for equipment displacement.4. Equipment used during well completion operations may vary depending on availability at the time of operations.5. Equipment location may vary depending on site conditions and availability of space on the site during well completions operations.6. Pad Located on Private surface, gate locked at main ranch entrance.FRAC WATERSUPPLY (2-4.5" STEEL)PROPOSED FRACLINES (2-4.5" STEEL) Edge of WorkingPad Surface12345678910111213141516Edge of WorkingPad SurfaceExist. Pad Elev.: ±9355111'100'62'Proposed Cuttings Pit19' depth (±8,3200 cy)15'15'Excess Soil Stockpile(±9,780 cy)105'141'113'Exist. Oil andGas LocationExist. Oil and Gas LocationExistingSediment TrapProposed P&A Exist. Conductor #3 Exist. Conductor #2 ABProposed Separators Area(70'x20' and 66'x20')Exist. Oil &Gas LocationExist. LinedDiversion DitchMaintain ExistingDiversion DitchsTrap with 6" Outlet Pipeto Lower Drainage DitchProposedSediment TrapMaintain ExistingSediment TrapDrive OverBerm 25'Temp. Pad BermProposed LinedDiversion DitchCuttings ManagementAreaExis t . Access RoadExist. Topsoil Area 3(±2,330 cy)Exist. Topsoil Area 2(±950 cy)Exist. Topsoil Area 1(±2,320 cy)Proposed LinedDiversion DitchDATE:DRAWN BY:DESIGNED BY:PROJECT:FEET1 INCH =0GRAPHIC SCALE IN FEET8080Contour Interval = 2'11/03/22CPXJASTPPSW1/4NE1/4 Section 36T. 7 S., R. 94 W.Garfield CountySee Note 3FLOWBACKLINE TO PAD 25BPLUG AND ABANDONED WELLPROPOSED GAS WELLPROPOSED FLARE LINEPROPOSED FLOWLINEPROPOSED TRANSFER HOSEPROPOSED WELLHEAD MANIFOLDENCLOSED COMBUSTION DEVICEHP 4-PHASE SEPARATORLOW PRESSURE VESSELPRODUCED WATER TANKWATER PUMPCONDENSATE TANKPRODUCED WATER TANKPROPOSED SURFACE FRAC LINES (2-4.5")PROPOSED FLOWBACK LINEPROPOSED GAS/WATER PIPELINESPROPOSED PRODUCTION EQUIPMENTPROPOSED LAND FARM "EARTH BERM"EXISTING OIL & GAS LOCATIONPROPOSED WORKING PAD SURFACEEXISTING PRODUCTION EQUIPMENTEXISTING ROADDRIVE OVER BERMSURFACE FRACLINE FROMREMOTE FRAC PADPROPOSEDGAS/WATERPIPELINES- LEGEND - 12345678910111213141516ABExis t . Access RoadSection 36T. 7 S., R. 94 W.Garfield CountySee Note 3PLUG AND ABANDONED WELLPROPOSED GAS WELLPRODUCED WATER TANKCONDENSATE TANKWELLHEAD FLOWLINEPRODUCTION PAD SURFACEGAS/WATER/CONDENSATE FLOWLINESEXISTING 2' EARTHEN BERMEXISTING OIL & GAS LOCATIONWORKING PAD SURFACEEXISTING ROADDRIVE OVER BERMDIVERSION DITCHINTERIM RECLAMATION AREA, MULCHEDAND SEEDEDGas/Water/CondensateFlowlines- LEGEND -Exist. Oil andGas LocationExist. TPR 132-36 Drive OverBerm 25'Exist. Oil and Gas LocationExist. Oil &Gas LocationExist. LinedDiversion DitchMaintain ExistingDiversion DitchsSediment Trap with 6"Outlet Pipe to LowerDrainage DitchLinedDiversion DitchSeparation Equipment:8 Quad SeparatorsFuel GasSkidUtilities/Controls:Power GenerationPLC Site ControllerRemote TelemetryUnit/RadioExist. Conductor #3 Exist. Conductor #2 Existing CreekInterim Reclamationarea, Mulched andSeededDATE:DRAWN BY:DESIGNED BY:PROJECT:FEET1 INCH =0GRAPHIC SCALE IN FEET8080Contour Interval = 2'11/16/22CPXTPPTPPProduction PadSurfaceDISTURBANCE AREASOIL AND GAS LOCATION: ± 5.45 ACWORKING PAD SURFACE: ± 2.06 ACACCESS ROAD: ± 0.0 AC PRODUCTION PAD: ± 1.34 AC RE-CLAIMED AREA: ± 4.11 AC ExistingSediment TrapInstrument AirSkidProduced WaterTransfer PumpSediment TrapLinedDiversion DitchCondensateLACT UnitV.O.C.CombustorBlowdown EnclosedCombustion DeviceHeater TreatersWorking PadSurfaceKnockoutVesselsWorkingPad Surface CPX Existing Well Pad 25A Location ID 334457 TepeeParkRanchForestServiceRoad824Area Affected by OGDP (2,000' Radius) CPX PICEANCE HOLDINGS LLC CPX PICEANCE HOLDINGS LLC White River National Forest CPX Existing Well Pad 36A Location ID 334460 Road(Private)White River National Forest CPX Temporary Water Support Pad 25B Location ID 482984 132-36 TPR 112-6 TPR 143-36 TPR 176-25 TPR 112-16 TPR 1 TPR Section 24 Section 25 Section 36 Section 19 Section 30 Section 31 Section 6 Section 7 Section 1 Section 12 T7S R94W T8S R94W T7S R94WT8S R93WT7S R94WT7S R93WT8S R94WT8S R93WT8S R93W T7S R93W Legend Drilled and Producing Drilled Drilled/Uncompleted "DUC" Well Permitted Working Pad Surface Oil and Gas Location Area Affected by OGDP (2,000' Temporary Water Support Pad Proposed Off-location Flowlines Forest Service Road Private Road White River National Forest Lands Parcels Figure 7a CPX Piceance Holdings, LLC Tepee Park Ranch Well Pad 36A Aota Technical, LLC Figure No. Related Location and Flowline Map 10/10/22 Date Garfield County SW1/4NE1/4 Sec. 36, T7S R94W, 6th P.M. 0 250 500 750 1,000 Feet Data Source: COGCC GIS Online CPX Piceance Holdings, LLC 34 S. Wynden Drive, Suite 240 Limited Impact Review Garfield County, Colorado Houston, TX 77056 TPR Well Pad 36A Article 9 Oil and Gas Permit Application Interim Reclamation Plan COGCC Rule 304.c.(16) INTERIM RECLAMATION PLAN TPR Well Pad 36A November 2022 CPX Piceance Holdings, LLC (CPX) owns and operates Tepee Park Ranch (TPR) in Garfield County, Colorado. CPX has prepared this Interim Reclamation Plan for continued development of the existing Well Pad 36A on TPR. The Plan addresses the Colorado Oil & Gas Conservation Commission (COGCC) requirement at Rule 304.c.(16) to prepare an Interim Reclamation Plan consistent with Rule 1003. 1.0 Site Description Well Pad 36A is an existing natural gas well pad on an established disturbed surface. The location is approximately 12 miles south of Rifle, Colorado in the SW ¼ NE ¼ Section 36, Township 7 South, Range 94 West. It is at an elevation of approximately 9,355 feet. TPR is privately owned and operated by CPX, predominantly f or the exploration and development of natural gas. Well Pad 36A contains three previously permitted wells. Well 132-36 was spud but not completed. Wells 143-36 and 112-6 have expired permits. The portion of TPR where the Oil and Gas Location is located is bounded by U.S. Forest Service lands to the north, south, and east. The Oil and Gas Location is zoned rural by Garfield County. The current land use is for natural gas extraction and production. The predominant vegetation community in the surrounding area is listed in Section 3.0. It includes spruce/fir forest with an understory of native forbs and grasses. The existing Oil and Gas Location is approximately 5.45 acres. The existing Working Pad Surface is approximately 2.06 acres, which will be reduced to 1.34 acres during production. The 4.11 acres of reclaimed area is shown on the attached Facility Layout Drawing. TPR is accessed using the existing 20-foot-wide unpaved private Tepee Park Ranch Road. The existing road pre-dates the Form 2A application and will remain after interim reclamation to provide access to TPR and Well Pad 36A during production. North of Well Pad 36A, CPX operates the existing Well Pad 25A on TPR in the SW ¼ SE ¼ Section 25, Township 7 South, Range 94 West. This well pad is an established disturbed surface with two operating wells and COGCC approval on September 21, 2022 to drill and produce additional natural gas wells. CPX proposes to use the existing Well Pad 25A as a remote frac support pad for SIMOPs during well drilling on Well Pad 36A. New off-location flowlines are proposed to be buried in a single trench on CPX land to transport natural gas, condensate, and fresh or produced water between Well Pad 25A and Well Pad 36A. The flowlines were included in the approved 2A permit for Well Pad 25A. 2.0 Soil Description Soil map units and their boundaries are shown on the Form 2A, Soil Unit Map. Soil units are listed in Table 1 . Additional soil unit descriptions are provided in the Dust Mitigation Plan and Topsoil Protection Plan submitted with the Form 2A application. Table 1. Soil Units Soil Unit Affected Area Drainage Class Available Water Capacity Depth to Restrictive Feature 104A: Haplocryolls- Cryaquolls complex 0 to 15 percent slopes Existing Oil and Gas Location; Existing Tepee Park Ranch Road Well drained 8.7 to 10.9 inches More than 80 inches CPX Piceance Holdings, LLC Interim Reclamation Plan TPR Well Pad 36A 2 November 2022 Source: Natural Resources Conservation Service, National Cooperative Soil Survey 3.0 Oil and Gas Location Pre-Disturbance Vegetation Composition According to an on-site environmental review conducted on August 15, 2022, the vegetation cover at the undisturbed reference area adjacent to the existing Oil and Gas location consists of the species below. The percent cover is an estimated 90 percent. Slender Wheatgrass Common Yarrow Kentucky Bluegrass Fishlake Thistle Blue Wildrye Stinging Nettle Gooseberry Currant Fireweed California Valerian Silvery Lupine Tall Ragwort Smooth Brome 4.0 Identification of Reference Area The Reference Area was identified on August 15, 2022. The latitude/longitude for the reference area is 39.3936216, -107.8325564. The Reference Area was determined based on a location adjacent to and representative of the existing Oil and Gas Location with similar soil properties, vegetation, and cover. Photographs of the area are provided in the Form 2A, Reference Area Pictures. 5.0 Known Weed Infestations There are no observed noxious weed infestations at the Oil and Gas Location. 6.0 Flowlines During production, buried natural gas, condensate, and water flowlines between Well Pads 25A and 36A are expected to consist of a 12-inch-diameter steel natural gas flowline; 2-inch-diameter steel condensate flowline, Soil Unit Affected Area Drainage Class Available Water Capacity Depth to Restrictive Feature 220B: Angostura family 5 to 40 percent slopes Existing Tepee Park Ranch Road Well drained 5.2 inches More than 60 inches 331C: Woodrock- Angostura families complex, 40 to 65 percent slopes Existing Oil and Gas Location Well drained 8.9 inches 40 to 72 inches 338B: Wetopa- Doughspon- Echemoor families complex 5 to 40 percent slopes Existing Tepee Park Ranch Road Well drained 6.5 to 11.1 inches More than 80 inches 449C: Tampico- Echemoor-Eyre families complex 30 to 65 percent slopes Existing Tepee Park Ranch Road Well drained 2.2 to 6.6 inches More than 60 inches CPX Piceance Holdings, LLC Interim Reclamation Plan TPR Well Pad 36A 3 November 2022 and 5-inch-diameter bidirectional flexpipe water flowline. The flowlines are shown on the Form 2A, Related Location and Flowline Map. A description of the flowlines, trench, and reclamation was included in the approved 2A permit for Well Pad 25A. 7.0 Access Road The existing Tepee Park Ranch road will be used for access to the well pad. The road will remain approximately 20 feet wide. The road has a well-established and hardened surface and will remain in use during production. 8.0 Removal of Drilling, Re-Entry, Completion Equipment and All Associated Debris and Waste Materials (1003.a) After well drilling and completion, the well pad will be downsized to approximately 1.34 acres to support natural gas well operation and future workovers. Equipment that is not needed to support production and stored materials will be removed from the location in preparation for interim reclamation. Any open holes, cellars, rat holes, or other boreholes will be backfilled per industry standards. During final reclamation, surface equipment, tanks, abandoned gathering line risers and flowline risers, and any debris will be removed from the location. 9.0 Management of Waste Material Waste materials will not be left onsite after well drilling and completion. Waste materials, volumes, and final disposal are described in the Waste Management Plan submitted with the Form 2A application. 10.0 Identification of Interim Reclamation Areas no Longer in Use (1003.b) An approximately 1.34-acre production pad will not be reclaimed. During production, this area will support natural gas well operation, process equipment, process flowlines, tank storage inside of secondary containment, and maintenance activities. The estimated timeframes for well development are listed in Table 2. Interim reclamation will be performed during the first favorable growing season after well development is complete and within the anticipated 6 months described in Rule 1003.b. Table 2. Operational Phases 11.0 Compaction Alleviation (1003.c) To decompact soil layers, areas to be reclaimed will have any gravel or surface material removed. The material will be redistributed during interim reclamation and trucked off site during final reclamation. Areas to be reclaimed will be cross ripped to an estimated depth of 18 inches unless restrictive features are encountered at a shallower depth. Decompaction will be used to improve the soil structure and to promote soil aeration, water infiltration, and microbial activity, which will promote plant growth. 12.0 Recontouring The Oil and Gas Location is relatively flat, as shown on the Form 2A, Construction Layout. There will be no cut, fill, or additional disturbance to the existing size of the location. Soil stockpiled on the location will be restored on the reclaimed area. Approximately 15,380 cubic yards of soil salvaged from construction will be available for interim Phase Anticipated Duration (Months) Construction 1 Well Drilling 8 Well Completions 8 Interim Reclamation 1 CPX Piceance Holdings, LLC Interim Reclamation Plan TPR Well Pad 36A 4 November 2022 reclamation. Topsoil is protected from wind and water erosion by stable 3.5:1 slopes and vegetation. The vegetation also protects microbial activity. Topsoil was segregated for stockpiling and reuse for reclamation based on its color and texture because the soil is darker and contains less clay than the underlying soils. The topsoil was divided into protected areas on the outermost edges of the well pad to keep the topsoil intact, untracked, and uncontaminated. In each area, the topsoil was seeded by hand with broadcast seed using a Forest Service special blend seed mix that was in circulation at the time the well pad was developed. When the well pad is reclaimed, the topsoil will be brought up from the fill slopes onto the pad as the final layer to recontour, reclaim, and seed the area. 13.0 Re-establish and Stabilize Drainage Features The reclaimed area will be blended with the surrounding surface to restore natural grade s and hydrology patterns. The existing stormwater controls will remain in place. They consist of a 6-inch-diameter drain on the well pad. The drain is piped outside of the berm to a lined trench. The trench drains to a lined catchment basin. Solids settle in the catchment basin for removal. The stormwater evaporates. 14.0 Establish Desired Plant Community (1003.e) Consistent with past revegetation work on TPR, CPX will use a U.S. Forest Service-recommended seed mix appropriate to the site plant community, adjacent Forest Service lands, and elevation. White River National Forest manages a Native Plant Materials Program for collection and propagation of local native seeds and makes the species available as a recommended seed mix to the commercial seed industry and land management agencies for large-scale restoration work. CPX plans to continue to rely on the Native Plant Materials Program as the most appropriate and effective source for a land manager-approved native plant mix for the location and its elevation. This method has been consistent with Garfield County expectations for site restoration. 15.0 Seedbed Preparation and Seeding (1003.e) The segregated soil horizons will be replaced in their original relative positions. The area will be tilled or disked to prepare a seedbed following natural contours. Soil amendments may be introduced at this stage to promote moisture retention and soil stabilization. Seedbed preparation will be conducted immediately before seeding to ensure that the seedbed maximizes revegetation success. Seeding will be conducted using broadcast seed distributed by hand or hydroseeding to obtain complete coverage. Spring and fall typically are preferred seeding periods to coincide with increased precipitation and conditions favorable to seed germination. 16.0 Fencing Twelve-foot cattle panels will be used to f ence the wellhead bay. Unauthorized access to TPR will continue to be restricted by a locked entrance gate at the northern end of the Tepee Park Ranch road. 17.0 Management of Invasive Plants (1003.f) The site operator will continue to monitor and control for noxious and invasive weeds at the location. Weed treatment will be conducted to prevent establishment and spread of noxious weeds. The weed treatment will be conducted according to Colorado Department of Agriculture recommendations by weed species. 18.0 Proposed Interim Reclamation Drawing The interim reclamation area is shown on the attached Facility Layout Drawings. It shows stormwater controls for control of erosion and stormwater runoff. 19.0 Reclamation Monitoring, Inspection, Maintenance, and Reporting A site operator will be on location daily to monitor the natural gas wells, equipment, tanks, location, and flowlines. The vegetative success will be monitored as part of these routine site visits. Invasive weeds, evidence of erosion, and areas requiring reseeding will be identified and addressed through weed treatment, adapting stormwater CPX Piceance Holdings, LLC Interim Reclamation Plan TPR Well Pad 36A 5 November 2022 controls, and application of additional seed and soil amendment or fertilizer. Vegetative success will be considered at least 80 percent of pre-disturbance reference area cover, consistent with Rule 1003.e.(2). A plant count for plant density will be conducted to assess percent cover and to g auge plant height. Documentation will include the operator’s maintenance and stormwater inspection records for the location and Change Management Checklist. 20.0 Interim Reclamation Completion Notice, Form 4 [1003.e(3)] CPX will submit a Form 4 Sundry Notice describing the reclamation pr ocedures, any mitigation measures, any changes to the final land use, and the total vegetative cover. A minimum of four photos will be taken during the growing season showing each cardinal direction to document the success of interim reclamation. One photo will document the total cover of live perennial vegetation of adjacent or nearby undisturbed land or the reference area . 21.0 Best Management Practices Best management practices (BMPs) for interim reclamation are described in Table 3. Table 3. Best Management Practices Best Management Practices • Timing – Interim reclamation will begin within 6 months after the last well is completed and the site is transitioned from well completions to production operations. • Waste Disposal – CPX will properly characterize and dispose of waste in accordance with its Waste Management Plan. • Recontouring - Disturbed areas will be recontoured to blend with the pre-disturbance surface and restore natural drainage patterns. • Topsoil - Topsoil stored on the location will be restored on the reclaimed area. Salvaged topsoil will be replaced and contoured to maximize erosion control and soil stability. • Erosion control – Erosion controls will be maintained to prevent stormwater run on, runoff, and erosion. Stormwater controls during production are shown on the attached Facility Layout Drawing. • Seedbed Preparation - Gravel or surface material will be removed or redistributed during interim reclamation. Areas to be reclaimed will be cross ripped to an estimated depth of 18 inches unless restrictive features are encountered at a shallower depth. • Seed mix – CPX will broadcast or hydroseed the U.S. Forest Service Native Plant Materials Program certified weed-free recommended seed mix. • Weed control – The location will be monitored for the presence of invasive weeds. Invasive weeds will be treated to prevent them from establishing or spreading. • Access – Unauthorized access will continue to be restricted by the locked gate to TPR at the northern end of the Tepee Park Ranch road. • Monitoring – The location will be monitored for vegetative success. It will be reseeded where needed to establish 80 percent of pre-disturbance cover. Attachment Facility Layout Drawing with Interim Reclamation Area 12345678910111213141516ABExis t . Access RoadSection 36T. 7 S., R. 94 W.Garfield CountySee Note 3PLUG AND ABANDONED WELLPROPOSED GAS WELLPRODUCED WATER TANKCONDENSATE TANKWELLHEAD FLOWLINEPRODUCTION PAD SURFACEGAS/WATER/CONDENSATE FLOWLINESEXISTING 2' EARTHEN BERMEXISTING OIL & GAS LOCATIONWORKING PAD SURFACEEXISTING ROADDRIVE OVER BERMDIVERSION DITCHINTERIM RECLAMATION AREA, MULCHEDAND SEEDEDGas/Water/CondensateFlowlines- LEGEND -Exist. Oil andGas LocationExist. TPR 132-36 Drive OverBerm 25'Exist. Oil and Gas LocationExist. Oil &Gas LocationExist. LinedDiversion DitchMaintain ExistingDiversion DitchsSediment Trap with 6"Outlet Pipe to LowerDrainage DitchLinedDiversion DitchSeparation Equipment:8 Quad SeparatorsFuel GasSkidUtilities/Controls:Power GenerationPLC Site ControllerRemote TelemetryUnit/RadioExist. Conductor #3 Exist. Conductor #2 Existing CreekInterim Reclamationarea, Mulched andSeededDATE:DRAWN BY:DESIGNED BY:PROJECT:FEET1 INCH =0GRAPHIC SCALE IN FEET8080Contour Interval = 2'11/16/22CPXTPPTPPProduction PadSurfaceDISTURBANCE AREASOIL AND GAS LOCATION: ± 5.45 ACWORKING PAD SURFACE: ± 2.06 ACACCESS ROAD: ± 0.0 AC PRODUCTION PAD: ± 1.34 AC RE-CLAIMED AREA: ± 4.11 AC ExistingSediment TrapInstrument AirSkidProduced WaterTransfer PumpSediment TrapLinedDiversion DitchCondensateLACT UnitV.O.C.CombustorBlowdown EnclosedCombustion DeviceHeater TreatersWorking PadSurfaceKnockoutVesselsWorkingPad Surface CPX Piceance Holdings, LLC 34 S. Wynden Drive, Suite 240 Limited Impact Review Garfield County, Colorado Houston, TX 77056 TPR Well Pad 36A Article 9 Oil and Gas Permit Application Wildlife Plan COGCC Rule 304.c.(17) WILDLIFE PLAN Well Pad 36A November 2022 CPX Piceance Holdings, LLC (CPX) owns and operates Tepee Park Ranch (TPR) in Garfield County, Colorado. CPX has prepared this Wildlife Plan for continued development of the existing Well Pad 36A on TPR. The sections below correspond to Colorado Oil & Gas Conservation Commission (COGCC) Rule 304.c.(17) to prepare a Wildlife Plan consistent with Rule 1201.b and with COGCC Wildlife Protection Guidance (June 25, 2021). 1.0 Site Description and Environmental Setting CPX owns and operates TPR, predominantly for the exploration and production of natural gas. The area is zoned Rural by Garfield County. The existing Well Pad 36A is located in the SW ¼ NE ¼ Section 36, Township 7 South, Range 94 West. This portion of TPR is bounded by U.S. Forest Service land to the north, south, and east. Well Pad 36A contains three previously permitted wells. Well 132-36 was spud but not completed (DG). Wells 143- 36 and 112-6 have expired permits (EP). CPX plans to plug and abandon Well 132-36. At full build out, CPX proposes 32 new natural gas wells on Well Pad 36A. CPX is proposing to use the existing 2.06-acre Working Pad Surface for well development. During production, CPX will use new buried flowlines to transport natural gas, condensate, and produced water to a tie in point at CPX’s permitted Well Pad 25A. The flowline corridor will be adjacent to and in the existing access road. The flowline trench was described in the approved 2A permit issued for Well Pad 25A. At Well Pad 25A, existing buried flowlines will transport natural gas and condensate to CPX’s permitted Pad 2 Tanks in Section 13, Township 7 South, Range 94 West. CPX proposes to dispose of produced water in a Class 2 Underground Injection Control well on Well Pad 25A. CPX is proposing to use the existing Well Pad 25A as a remote frac support pad for SIMOPs during well drilling on Well Pad 36A. Using Well Pad 25A as a temporary frac support pad to conduct SIMOPs on Well Pad 36A would expedite the completions schedule. Alternatively, equipment for completions would be located on Well Pad 36A. CPX will use the permitted Temporary Water Support Pad 25B for recycled produced water and flowback water storage during well development on Well Pad 36A. The locations are shown on the Related Location and Flowline Map submitted with the Form 2A application. The environmental setting for Well Pad 36A is predominantly spruce/fir forest with an understory of native forbs and grasses. They include Engelmann spruce, Kentucky bluegrass, blue wildrye, gooseberry currant, California valerian, tall ragwort, slender wheatgrass, common yarrow, fishlake thistle, stinging nettle, fi reweed, silvery lupine, and smooth brome. An environmental field review was conducted for Well Pad 36A on September 6, 2021. The review method was field identification of plant species and vegetation sampling. Findings from the environmental review were included in the Topsoil Protection Plan and Interim Reclamation Plan . In addition to the environmental field review, CPX conducted a desktop review and mapping using the sources listed in Section 7.0, References. 2.0 High Priority Habitat and Colorado Parks & Wildlife Consultation Existing Well Pad 36A is in an area designated High Priority Habitat (HPH) under Rule 1202.c.(1).R, cutthroat trout designated crucial habitat and native fish and other native aquatic species conservation waters (within 500 feet of ordinary high water mark). The well pad is within 500 feet of designated waters. The western portion of the well pad is also within 300 feet of designated waters. This portion of the well pad is between 130 feet and 223 feet from designated waters. The area is shown on the Wildlife Habitat Drawing submitted with the Form 2A application. For continued development of Well Pad 36A within the HPH buffer area, CPX conducted a pre-application consultation with officials from Colorado Parks & Wildlife (CPW) and COGCC on May 27, 2021. CPX provided CPX Piceance Holdings, LLC Wildlife Plan Well Pad 36A 2 November 2022 wildlife habitat mapping, a presentation, and discussion of COGCC rule requirements regarding HPH. CPX also conducted an on-site field review of mapped HPH areas and TPR operations. During the field review, agency staff viewed the environmental setting, designated waters, and the extensive controls on Well Pad 36A to prevent spills, runoff, and potential impacts to HPH. The field review demonstrated that the well pad has been stable and well established since its construction in approximately 2008. It represents a continued use of an existing location and, access without creating new soil disturbance and habitat fragmentation from relocating the well pad. CPX received a waiver and variance recommendation from CPW on June 18, 2021 for development within the Rule 1202.c.(1).R buffer. Specifically, Rule 309.e.(5).D.i allows CPW to waive the application of Rule 1202.c.(1).R between 300 and 500 feet from designated waters. In its waiver documentation, CPW stated that it incentivizes the use of already disturbed locations when no adverse impacts are anticipated. CPW further stated that construction of a new location, instead of continued use of the existing location, would cause more u ndesired disturbance and habitat fragmentation, and would pose more risk to high priority habitat and the watershed. Rule 309.e.(5).E allows CPW to make a variance recommendation to allow Oil and Gas Operations within 300 feet from designated waters. CPW renewed the waiver and variance recommendation on July 13, 2022. The waiver and variance recommendations provided by CPW are attached to this Plan. CPW provided an additional and related written waiver on November 18, 2022. Under Rule 1202.a.(3), CPW waived the restriction from staging, refueling, and Chemical storage areas within 500 feet of the Ordinary High Water Mark (OHWM) of any river, perennial or intermittent stream, lake, pond, or wetland. Through its waiver, CPW found that the already developed location, avoidance measures, and BMPs are sufficiently protective. Among other protections, CPW found that the stormwater and erosion control measures for the location are sufficient to minimize erosion, transport of sediment, and site degradation, consistent with Rule 1002.f provisions for Stormwater Management to limit surface water impacts. Waivers provided by CPW are attached to this Plan. 3.0 Rule 309.e.(5) Best Management Practices The best management practices (BMPs) required by Rule 309.e.(5).D.i as part of CPW consultation are listed in Table 1. Additional BMPs coordinated with CPW are listed in Table 2. Table 1. Rule 309.e.(5).D.i Best Management Practices Provision Best Management Practices 309.e.(5).D.i.aa The operator will contain flowback and stimulation fluids in tanks that are placed on a Working Pad Surface in an area with downgradient perimeter berming. 309.e.(5).D.i.bb The operator will construct lined containment devices pursuant to Rule 603.o arou nd any new condensate and produced water storage tanks. There will be no crude oil storage on Well Pad 36A. 309.e.(5).D.i.cc The operator will inspect the location on a daily basis. 309.e.(5).D.i.dd The operator will maintain adequate spill response equipment on the location during drilling and completion operations. 309.e.(5).D.i.ee There will be no construction or utilization of fluid pits. Table 2. Additional Best Management Practices Provision Best Management Practices Spill Protection 1 To protect against spills from the well pad, existing well pad fill slopes have 2-foot-high high earthen berms compacted to 95 percent soil/moisture density. The outside slopes of the berms have 80 percent vegetative cover. The berms are stable with high structural integrity. 2 To protect against spills from tanks, steel secondary containment will be sized to 150 percent of the largest tank. CPX Piceance Holdings, LLC Wildlife Plan Well Pad 36A 3 November 2022 Provision Best Management Practices 3 During production, facility design minimized the number of produced water and condensate tanks to a projected two of each set back from surface water by greater than 300 feet. They will be surrounded by steel secondary containment. Stormwater Protection 4 To protect against runoff, there is no uncontrolled stormwater on the well pad. The well pad has a 6-inch drain to capture stormwater. The drain is piped outside of the berm to a lined perimeter stormwater trench. The trench drains to a lined stormwater catchment basin. Solids settle in the catchment basin for removal. The stormwater evaporates. The perimeter trench and catchment basin will remain in place during production. 5 To protect against erosion, the access road has a borrow ditch on the upslope side. Stormwater is diverted to 18 to 24-inch culverts spaced at 600-foot intervals. The frequent culverts prevent erosion by avoiding long runs of stormwater and slowing velocity. 6 During production, the well pad will be reduced to approximately 1.34 acres. The remaining area will be reclaimed, seeded, and revegetated. Stream Protection 7 To protect Beaver Creek, its road crossing was designed in consultation with the U.S. Army Corps of Engineers. The crossing is an open bottom arch with concrete footers to maintain the streambed integrity. 8 To protect Beaver Creek, tank loading and unloading will not occur on the well pad. Tank loading and unloading were moved off of TPR to CPX’s Pad 2 Tanks along County Roa d 317. 9 The existing access road will be used to support Well Pad 36A. It has a well-established and surface hardened roadbed that receives dust mitigation using fresh water. Inspections 10 Well drilling and completions will be manned and monitored 24/7 by CPX personnel and contract operators. Drips, leaks, or spills will be detected visually or by a pressure loss to avoid or contain fluid or material within the multiple layers of secondary containment. 11 To minimize potential for undetected spills, runoff, and pipeline leaks, personnel are on site minimally 5 days/week. Field staff live within 15 minutes of the well pads, which facilitates consistent on-site presence. 12 Pipelines are monitored for pressure loss and are tested annually. 4.0 Other Mapped Species There is one terrestrial species with habitat mapped by COGCC within 1 mile of the Well Pad 36A Working Pad Surface: lynx. The Wildlife Habitat Drawing shows the habitat and distances listed in Table 3. Table 3. Mapped Terrestrial Species Mapped Habitat1 Nearest Distance and Direction from Working Pad Surface (feet) Lynx Denning 1,770 S Lynx Winter 1,740 S 1U.S. Forest Service Habitat Data: https://www.fs.usda.gov/main/whiteriver/landmanagement/gis Development on Well Pad 36A will avoid potential impacts to mapped lynx habitat. The well pad represents a continued land use in the area. It is separated from mapped habitat by approximately one-third mile of spruce/fir CPX Piceance Holdings, LLC Wildlife Plan Well Pad 36A 4 November 2022 forest, ridgelines, and a drainage. The combination of distance, forest cover, and topography attenuates noise and light and avoids potential impacts to mapped habitat. Lighting will occur only during well drilling and completions and will be cast downward. The location will be unlit during production. In 2017, CPX prepared an Environmental Assessment under the National Environmental Policy Act to support U.S. Forest Service review of CPX’s proposed pipeline and road construction and road use on Forest Service Land north of TPR. The affected area was adjacent to the northernmost mapped lynx habitat shown on the Wildlife Habitat Drawing. The Forest Service approved CPX’s pipeline and road construction and road use with a Finding of No Significant Impact and issued a pipeline right-of-way and road use permit. In its Decision Notice (November 3, 2017) the Forest Service stated its finding that there would be no significant adverse effects on wildlife and their habitat , including from construction and road use on National Forest System Road 824 adjacent to lynx denning habitat. In addition to the Forest Service review described above, the White River National Forest Land and Resource Management Plan (Forest Plan) (2002) establishes objectives for lynx. The Plan lists protecting water quality and habitat connectivity in linkage areas; managing vegetation, grazing, and recreation; and discouraging snow compaction in lynx habitat. There are no references in the Forest Plan to noise or light in relation to lynx. The Forest Service prepared a Southern Rockies Lynx Amendment (2008) with updated management direction for eight forest plans, including White River National Forest. In its discussion of energy development, the Amendment discusses additional guidelines for winter access and for reclamation plans in lynx habitat. There are, again, no references to noise or light in relation to lynx. The Amendment concludes that any site-specific effects will be determined at an Application for Permit to Drill (APD) stage or a Geographic Planning stage. A 2011 CPW study of habitat use by radio-collared lynx reintroduced to Colorado found that the average elevation for lynx habitat was 10,780 feet with the majority of habitat located between 9,900 feet and 11,620 feet. Well Pad 36A is located at approximately 9,355 feet in elevation, which is between 500 and 2,300 feet lower in elevation than the majority of lynx habitat. Activity on Well Pad 36A avoids impacts to lynx habitat from the distance between the well pad and habitat and also from the difference in elevation. 5.0 Rule 1202.a Requirements Table 4 describes how the operator will implement Rules 1202.a.(1-10) and 1202.b for the Oil and Gas Location. Table 4. Rule 1202.a Requirements Provision Implementation 1202.a.(1) The operator will install and use bear-proof dumpsters and trash receptacles for unsecured food-related trash at facilities that generate trash. 1202.a.(2) The operator will not withdraw from or discharge into surface waters. 1202.a.(3) The operator will not situate new staging, refueling, or chemical storage areas within 500 feet upgradient of the ordinary high water mark of any river, perennial or intermittent stream, lake, pond, or wetland. CPX has obtained a CPW waiver for this provision. 1202.a.(4) The Oil and Gas Location will have no drilling, production, or other fluid pits. 1202.a.(5) Trenches left open for more than 5 consecutive days during construction of flowlines regulated under the 1100 Series Rules will have wildlife escape ramps at a minimum of one ramp per ¼ mile of trench. 1202.a.(6) When conducting interim and final reclamation pursuant to Rules 1003 and 1004, the operator will use CPW-recommended seed mixes for reclamation when consistent with any local soil conservation district requirements. 1202.a.(7) The operator will use CPW-recommended fence designs when consistent with any relevant local government requirements. 1202.a.(8) The operator will conduct all vegetation removal necessary for oil and gas operations outside of the nesting season for migratory birds (April 1 to August 31). For any vegetation removal that must be scheduled between April 1 to August 31, the operator will implement appropriate CPX Piceance Holdings, LLC Wildlife Plan Well Pad 36A 5 November 2022 Provision Implementation hazing or other exclusion measures prior to April 1 to avoid take of migratory birds. If hazing or other exclusion measures are not implemented, the operator will conduct pre-construction nesting migratory bird surveys within the approved disturbance areas prior to any vegetation removal during the nesting season. If active nests are located, the operator will provide work zone buffers around active nests. 1202.a.(9) The Oil and Gas Location will have no drilling, production, or other fluid pits. 1202.a.(10) The operator will operate in accordance with the provisions listed in Table 1 of this plan for a Working Pad Surface between 500 feet and 1,000 feet hydraulically upgradient from HPH in Rule 1202.c.(1).R. 1202.b The operator will bore, rather than trench, any flowline crossings of perennial streams identified as aquatic HPH. The operator will excavate under existing culverts for any crossings of dry drainages or intermittent streams. 6.0 General Operating Requirements Table 5 lists general statewide standard operating requirements to protect wildlife habitat and resources. Table 5. General Operating Requirements BMP The Operator Will 1 Inform and educate employees and contractors on wildlife conservation practices, including no harassment or feeding of wildlife. 2 Consolidate and centralize fluid collection and distribution facilities to minimize impact to wildlife. 3 Adequately size infrastructure and facilities to accommodate both current and future gas production. 4 Design road crossings of streams at right angles to all riparian corridors and streams to minimize the area of disturbance. 5 Implement fugitive dust control measures. 6 Install screening or other devices on the stacks and on other openings of heater treaters or fired vessels to prevent entry by migratory birds. 7 Minimize rig mobilization and demobilization by completing or re-completing all wells from a given well pad before moving rigs to a new location. 8 To the extent practicable, share and consolidate new corridors for pipeline rights-of-way to minimize surface disturbance. 9 Engineer new pipelines to reduce field fitting and reduce excessive right -of-way widths and reclamation. 10 Mow or brush hog vegetation where appropriate, leaving root structure intact, instead of scraping the surface, where allowed by the surface owner. 11 Limit access to oil and gas access roads where approved by surface owners, surface managing agencies, or local government. 12 Post speed limits and caution signs to the extent allowed by surface owners, federal and state regulations, local government, and land use policies. 13 Use wildlife-appropriate fencing where acceptable to the surface owner. 14 Use topographic features and vegetative screening to create seclusion areas, where acceptable to the surface owner. 15 Use remote monitoring of well production to the extent practicable. 16 Reduce traffic associated with transporting drilling water and produced liquids through the use of pipelines, large tanks, or other measures. CPX Piceance Holdings, LLC Wildlife Plan Well Pad 36A 6 November 2022 BMP The Operator Will 17 Store and stage emergency spill response equipment at strategic locations along perennial water courses so that it is available to expedite effective spill response. 18 Install automated emergency response systems (e.g., high tank alarms, emergency shutdown systems). 19 Avoid dust suppression activities within 300 feet of the ordinary high water mark of any reservoir, lake, wetland, or natural perennial or seasonally flowing stream or river. 7.0 References 1. COGIS High Priority Habitat Layers. 2. Critical Habitat IPaC Report: https://ecos.fws.gov/ipac/. 3. Migratory Birds: https://www.fws.gov/birds/index.php. 4. State Protected Species: https://cpw.state.co.us/learn/Pages/SpeciesProfiles.aspx . 5. Buffer Zones and Seasonal Restrictions for Colorado Raptors: https://cpw.state.co.us/Documents/WildlifeSpecies/LivingWithWildlife/Raptor -Buffer-Guidelines.pdf. 6. U.S. Forest Service Habitat Data: https://www.fs.usda.gov/main/whiteriver/landmanagement/gis. 7. U.S. Geological Survey, National Hydrography Dataset. 8. Areas of high habitat use from 1999-2010 for radio-collared Canada lynx reintroduced to Colorado: Lynx habitat use (state.co.us). Attachments Colorado Parks and Wildlife Waiver and Variance Recommendation for Rule 1202.c.(1).R (June 18, 2021) Colorado Parks and Wildlife Waiver and Variance Recommendation for Rule 1202.c.(1).R Renewal (July 13, 2022) Colorado Parks and Wildlife Waiver for Rule 1202.a.(3) (November 18, 2022) Grand Junction Service Center Northwest Regional Office 711 Independent Ave. Grand Junction, CO, 81505 P 970-255-6100 | F 970-255-6111 Dan Prenzlow, Director, Colorado Parks and Wildlife • Parks and Wildlife Commission: Marvin McDaniel, Chair  Carrie Besnette Hauser, Vice-Chair Marie Haskett, Secretary  Taishya Adams  Betsy Blecha  Charles Garcia  Dallas May  Duke Phillips, IV  Luke B. Schafer  James Jay Tutchton  Eden Vardy CPX Piceance Holdings 6/18/2021 34 S. Wynden Dr. Suite 300 Houston, Texas 77056 Dear CPX Piceance Holdings, Colorado Parks and Wildlife (CPW) has a statutory responsibility to manage all wildlife species in Colorado and consultation obligations for certain oil and gas operations regulated by the Colorado Oil and Gas Conservation Commission (COGCC). As a result of CPW consultation, detailed in COGCC Rule 309.e.(5).E, “CPW may also make written recommendations on whether a variance pursuant to Rule 502 should be granted, under what conditions, and the reasons for any such recommendations, including requests for variances from Rules 1202.c.(1)Q-S. The Commission will consider the written recommendations of CPW…” This serves as CPW’s written recommendation in support of CPX’s request for a variance from Rule 1202.c.(1).R on Pad 36A. Pad 36A is partially situated within 300 feet of Beaver Creek, which is cutthroat trout designated crucial habitat and native fish and other native aquatic species conservation waters. However, Pad 36A is well-established. This location was constructed in 2008 and received an exception to interim reclamation requirements. CPW incentivizes the use of already disturbed locations when no adverse impacts are anticipated. CPW staff toured Pad 36A on May 27, 2021, to verify that this location was appropriate for a variance. A variance would allow CPX to continue the use of an existing location, access roads, and off-location flowlines. The following items provided CPW staff with confidence in their support of the variance request: A lined steel secondary containment will avoid the potential for spills & leaks to impact surface water An engineered drain from the pad to a lined perimeter trench A catchment system to avoid storm water runoff is in place No erosion is anticipated due to the maturity of the pad surface & established vegetation Dust suppression measure will be taken to avoid impacts on Beaver Creek Additionally, CPX indicated that the existing tertiary containment perimeter berm could be reinstalled after interim reclamation. CPX has agreed to all operating requirements listed in Rule 309.e.(5)D.i.aa-ee to obtain a waiver in 1202.c.(1).R habitats. Considering this, CPW issues a waiver for portions of Pad 36A that are outside of the variance zone. An alternative location for Pad 36A was considered; however, construction at an alternative location would cause undesired habitat fragmentation and pose more risk to High Priority Habitats and the watershed. Colorado Parks & Wildlife values the opportunity to provide comments on this proposal. If you have any questions or concerns, please reach out to Taylor Elm, Energy Liaison, at (970) 986-9767. Sincerely, Kirk Oldham Area Wildlife Manager Cc. Travis ByBee, District Wildlife Manager Taylor Elm, Northwest Region Energy Liaison Danielle Neumann, Northwest Region Land Use Specialist File. Grand Junction Service Center Northwest Regional Office 711 Independent Avenue Grand Junction, CO 81505 P 970.255.6100 Heather Dugan, Acting Director, Colorado Parks and Wildlife • Dan Prenzlow, Director, Colorado Parks and Wildlife Parks and Wildlife Commission: Carrie Besnette Hauser, Chair  Dallas May, Vice-Chair  Marie Haskett, Secretary  Taishya Adams Karen Bailey  Betsy Blecha  Gabriel Otero  Duke Phillips, IV  Richard Reading  James Jay Tutchton  Eden Vardy CPX Piceance Holdings 7/13/2022 34 S. Wynden Dr. Suite 300 Houston, Texas 77056 Dear CPX Piceance Holdings, Colorado Parks and Wildlife (CPW) has a statutory responsibility to manage all wildlife species in Colorado and consultation obligations for certain oil and gas operations regulated by the Colorado Oil and Gas Conservation Commission (COGCC). As a result of CPW consultation, detailed in COGCC Rule 309.e.(5).E, “CPW may also make written recommendations on whether a variance pursuant to Rule 502 should be granted, under what conditions, and the reasons for any such recommendations, including requests for variances from Rules 1202.c.(1)Q-S. The Commission will consider the written recommendations of CPW…” This serves as CPW’s written recommendation in support of CPX’s request for a variance from Rule 1202.c.(1).R on Pad 36A. Pad 36A is partially situated within 300 feet of Beaver Creek, which is cutthroat trout designated crucial habitat and native fish and other native aquatic species conservation waters. However, Pad 36A is well-established. This location was constructed in 2008 and received an exception to interim reclamation requirements. CPW incentivizes the use of already disturbed locations when no adverse impacts are anticipated. CPW staff toured Pad 36A on May 27, 2021, to verify that this location was appropriate for a variance. A variance would allow CPX to continue the use of an existing location, access roads, and off-location flow lines. The following items provided CPW staff with confidence in their support of the variance request:  A lined steel secondary containment will avoid the potential for spills & leaks to impact surface water  An engineered drain from the pad to a lined perimeter trench  A catchment system to avoid storm water runoff is in place  No erosion is anticipated due to the maturity of the pad surface & established vegetation  Dust suppression measure will be taken to avoid impacts on Beaver Creek Additionally, CPX indicated that the existing tertiary containment perimeter berm could be reinstalled after interim reclamation. CPX has agreed to all operating requirements listed in Rule 309.e.(5)D.i.aa- ee to obtain a waiver in 1202.c.(1).R habitats. Considering this, CPW issues a waiver for portions of Pad 36A that are outside of the variance zone. An alternative location for Pad 36A was considered; however, construction at an alternative location would cause undesired habitat fragmentation and pose more risk to High Priority Habitats and the watershed. Colorado Parks & Wildlife values the opportunity to provide comments on this proposal. If you have any questions or concerns, please reach out to Taylor Elm, Energy Liaison, at (970) 986-9767. Sincerely, Kirk Oldham Area Wildlife Manager Cc. Travis ByBee, District Wildlife Manager Taylor Elm, Northwest Region Energy Liaison File. 1 gwen.brodsky@aota.tech From:Neumann - DNR, Danielle <danielle.neumann@state.co.us> Sent:Friday, November 18, 2022 1:38 PM To:gwen.brodsky@aota.tech Cc:Nick Kurtenbach; Bryan Clark; Taylor Elm - DNR Subject:Re: CPX Piceance Holdings consultation on Well Pad 36A under Rule 1202.a.(3) Ms. Brodsky, Colorado Parks & Wildlife (CPW) staff toured CPX Piceance Holding's Well Pad 36A on May 27, 2021. This communication serves as CPW's waiver for CPX Piceance Holding's Well Pad 36A from Colorado Oil and Gas Conservation Commission (COGCC) Rule 1202.a.(3) for Well Pad 36A. Rule 1202.a.(3) states, "at new and existing Oil and Gas Locations, Operators will not situate new staging, refueling, or Chemical storage areas within 500 feet of the Ordinary High Water Mark ("OHWM") of any river, perennial or intermittent stream, lake, pond, or wetland." This Operating Requirement may be removed per a signed waiver from CPW and additional approvals from COGCC. CPW is confident in issuing this waiver after carefully considering the location, which is already developed, and the provided Avoidance Measures and Best Management Practices summarized in CPX Piceance Holding's November 16, 2022 email communication to CPW staff. Well Pad 36A was constructed in 2008 and received an exception from COGCC to interim reclamation requirements. CPW incentivizes using already disturbed locations when no adverse impacts are anticipated. An alternative location for Well Pad 36A was considered; however, construction at an alternative location would cause undesired habitat fragmentation and pose more risk to High Priority Habitats and the watershed. If there are any questions regarding this response or a need for additional details, please feel free to reach out to me directly. Sincerely, On Wed, Nov 16, 2022 at 1:44 PM <gwen.brodsky@aota.tech> wrote: Ms. Neumann, Thank you again for CPW’s past documentation for CPX Piceance Holdings, LLC’s existing Well Pad 36A. CPX received a waiver and variance recommendation from CPW on June 18, 2021, which was renewed on July 13, 2022. That documentation is for the Well Pad’s proximity to Colorado Oil & Gas Conservation Commission (COGCC) Rule 1202.c.(1).R high priority habitat for cutthroat trout designated crucial habitat and native fish and other native aquatic species conservation waters. This email requests the additional explicit waiver required by COGCC for Rule 1202.a.(3) for staging, refueling, and chemical storage areas within 500 feet of the Ordinary High Water Mark (OHWM) of any river, perennial or intermittent stream, lake, pond, or wetland. Information to support this waiver request is provided below. 2 History of Previous Consultation on HPH for Well Pad 36A  Rule 1202.c.(1).R HPH waiver and variance recommendation from CPW (June 18, 2021)  Rule 1202.c.(1).R HPH waiver and variance recommendation renewal from CPW (July 13, 2022)  Rule 1202.c.(2).C agreement with Best Management Practices or other avoidance measures for flowline corridor clearing and installation (August 1, 2022) Avoidance Measures and Best Management Practices for Well Pad 36A  The attached Facility Layout Drawing demonstrates that there will be no expansion of the existing Well Pad 36A Oil and Gas Location.  The Oil and Gas Location will remain its current size of approximately 5.45 acres.  The Working Pad Surface will remain its current size of approximately 2.06 acres.  The Well Pad during Production will be reduced to approximately 1.34 acres. The remaining area will be reclaimed, seeded, and revegetated.  The well pad has been stable and well established since its construction in approximately 2008.  The well pad is surrounded by 2-foot earthen berms, compacted to 95 percent soil/moisture density.  The earthen berms are stable and vegetated with approximately 80 percent vegetative cover on the outside fill slopes.  The well pad has a 6-inch drain to capture stormwater. The drain is piped outside of the berm to a lined perimeter stormwater trench. The trench drains to a lined catchment basin. In the catchment basin, solids settle for removal. The stormwater evaporates.  Steel secondary containment during production will be sized to contain 150 percent of the largest tank.  Tank loading and unloading will not occur on the well pad. Tank loading and unloading were moved off of Tepee Park Ranch to CPX’s Pad 2 Tanks along County Road 317.  The existing access road will be used to support Well Pad 36A. It has a well-established and surface hardened roadbed that receives dust mitigation using fresh water.  Flowlines to support Well Pad 36A were previously reviewed by CPW for agreement with BMPs and other avoidance measures on August 1, 2022 under Rule 1202.c.(2).C.  Well drilling and completions will be manned and monitored 24/7 by CPX personnel and contract operators. Drips, leaks, or spills will be detected visually or by a pressure loss to avoid or contain fluid or material within the multiple layers of secondary containment.  During production, the Facility Layout Drawing shows that CPX well pad design has minimized the number of produced water and condensate tanks to two of each. They will be set back from surface water by greater than 300 feet. They will be surrounded by steel secondary containment.  The perimeter trench and catchment basin will remain in place during production to provide an added layer of control. Thank you very much for your assistance with this, and please let me know if I can help with any questions. 3 Gwen Gwen Brodsky | Principal Cell (303) 818-4462 gwen.brodsky@aota.tech Aota Technical, LLC | Denver, CO aota.tech -- Danielle Neumann Land Use Specialist Northwest Region To help protect your privacy, Microsoft Office prevented automatic download of this picture from the Internet. C: 970-366-1223 0088 Wildlife Way Glenwood Springs CO 81601 danielle.neumann@state.co.us | www.cpw.state.co.us CPX Piceance Holdings, LLC 34 S. Wynden Drive, Suite 240 Limited Impact Review Garfield County, Colorado Houston, TX 77056 TPR Well Pad 36A Article 9 Oil and Gas Permit Application Water Plan COGCC Rule 304.c.(18) Well Pad 36A November 2022 WATER PLAN CPX Piceance Holdings, LLC (CPX) owns and operates Tepee Park Ranch (TPR) in Garfield County, Colorado. CPX has prepared this Water Plan for continued development of the existing Well Pad 36A on TPR. The sections below correspond to Colorado Oil & Gas Conservation Commission (COGCC) Rule 304.c.(18) to prepare a Water Plan consistent with Rule 437, Rule 905.a.(3), and Hydraulic Fracturing Chemical Additives guidance (May 11, 2021). 1.0 Site Description CPX proposes the continued development of the existing Well Pad 36A on TPR. TPR is privately owned and operated by CPX, predominantly for the exploration and development of natural gas wells. Well Pad 36A is an existing natural gas well pad on an established disturbed surface. The location is approximately 12 miles south of Rifle, Colorado in the SW ¼ NE ¼ Section 36, Township 7 South, Range 94 West. The location is further described in Table 1. Existing and proposed wells are listed in Table 2. Table 1. Existing Well Pad Location Legal Description Location Coordinates Location ID County SW ¼ NE ¼, Section 36, Township 7 South, Range 94 West Latitude: 39.395017 Longitude: -107.831908 334460 Garfield Table 2. Existing and Proposed Wells Existing Wells Proposed Wells One Spud/Not Completed Well (DG): TPR 132-36 (API # 05-045-16949) Two Expired Permits (EP) TPR 143-36 (API # 05-045-16950) TPR 112-6 (API # 05-045-16951) One Drilled but Uncompleted Well (DUC/TA): TPR 176-25 (API # 05-045-22153) 32 Natural Gas Wells 1 Plugged and Abandoned Well (TPR 132-36) 2.0 Water Volumes 2.1 Overview CPX is proposing to drill 32 new natural gas wells on Well Pad 36A with water-based bentonite drilling fluids. Drilling will use fresh water. Completions will use recycled produced water and water from well completions. CPX has a sufficient volume of fresh water available by purchasing from a third-party source for drilling and dust abatement. CPX plans to purchase recycled produced water from TEP Rocky Mountain LLC (TEP). Water from well completions will come from wells drilled on Well Pad 36A. 2.2 Drilling CPX anticipates that drilling will require approximately 8 months to complete. Fresh water will be purchased for drilling from Loesch and Crann Ditch Company in Rifle, Colorado at the address in Section 3.0. Loesch and Crann will source water from the Last Chance Ditch. Water will be trucked to Well Pad 36A. Fresh water will be used for well drilling to provide the proper chemistry for drilling mud and for better formation compatibility. Estimated volumes of fresh water are based on calculations from water use records from wells in the TPR area. Cementing the wells will use approximately 650 bbls of water per well. During mudding, the initial well will use approximately 4,500 bbls of fresh water and return approximately 4,050 bbls of recycled mud. This CPX Piceance Holdings, LLC Water Plan Well Pad 36A 2 November 2022 represents an estimated 10 percent water loss to the formation per well. A fter the initial well, therefore, CPX expects the addition of approximately 450 bbls of fresh water for each subsequent well. An estimated 500 bbls of fresh water will be used for dust abatement per well. The anticipated water volumes are listed in Table 3. Table 3. Drilling Fresh Water Use (bbls) Activity Per Well Total Cementing 650 20,800 Mud (Initial Well) 4,500 4,500 Mud (Subsequent Wells) 450 13,950 Dust Abatement 500 16,000 TOTAL 55,250 2.3 Completions CPX anticipates that completions will require approximately 8 months. CPX plans to use recycled produced water sourced from TEP Rocky Mountain, LLC’s (TEP’s) Beaver Creek Pit and water from well completions. Water from well completions will be sourced from the wells drilled on Well Pad 36A. Each well is expected to require 50,000 bbls of water for completions. Volumes are listed in Table 4. Table 4. Use of Recycled Produced Water and Water from Well Completions (bbls) Activity Per Well Total Acid Wash/ Hydraulic Fracturing 50,000 1,600,000 2.4 Total Well Development Water Use CPX is maximizing recycling and reuse of water. Recycled produced water and water from well completions represents approximately 97 percent of total water use. Approximately 3 percent of total water use will be fresh water. The well development total volumes are listed in Table 5. Table 5. Total Water Use (bbls) Phase Fresh Water Produced Water Total Drilling 55,250 55,250 Completions 1,600,000 1,600,000 TOTAL 1,655,250 3.0 Fresh Water Source CPX will purchase fresh water from Loesch and Crann Ditch Company under a private contract. Water will be sourced as surface water at the diversion point identified by the Loesch and Crann Ditch Company on Last Chance Ditch. The location is listed in Table 6. Table 6. Fresh Water Source Source Owner Diversion County Water Source Transportation Method Latitude/ Longitude Name Last Chance Ditch Loesch and Crann Ditch Company 39.530896 / -107.713397 Mamm Creek Takeout Garfield Irrigation Ditch Surface Water Truck CPX Piceance Holdings, LLC Water Plan Well Pad 36A 3 November 2022 In accordance with COGCC Rule 304.c.(18).B, the seller’s name and address are listed below. Loesch and Crann Ditch Company P.O. Box 365 Rifle, CO 81650 Fresh water will be transported from Last Chance Ditch to Well Pad 36A by truck. Trucks will be operated by the third-party transport company, Shalestone, Inc., under a contract with CPX. Information for the trucking company is listed in Table 7. Table 7. Trucking Company Information Company Local Office Corporate Office Shalestone, Inc. 2171 I-70 Frontage Rd. De Beque, CO 81630 (970) 283-5555 2768 Compass Dr., Suite 103 Grand Junction, CO 81506 (970) 241-8633 Trucks will use the following Garfield County preferred haul route: • Exit I-70 at Rifle • West on 7th St. and south on Garden Lane • West on County Road (CR) 320 (Rifle-Rulison Road) for approximately 3 miles • South on CR 317 for approximately 5.5 miles • South on Forest Service Road 824 (FS 824) for approximately 2.75 miles • South on private Tepee Park Ranch Road for approximately 1.5 miles to Well Pad 36A Fresh water will be hauled to Well Pad 36A using bobtail trucks with a capacity of 80 bbls. Water will be offloaded to dedicated freshwater tanks at the drill rig. Freshwater tanks will have a capacity of 400 bbls, each. 4.0 Produced Water Sources CPX plans to use recycled produced water and water from well completions to reduce the use of fresh water to approximately 3 percent of total water use. CPX plans to source recycled produced water from TEP. CPX will source water from well completions from the wells drilled on Well Pad 36A. In accordance with Rule 905.c.(5), CPX will submit a produced water sharing agreement for COGCC approval at least 60 days in advance of implementing the water sharing plan. The planned source of recycled produced water is TEP’s Beaver Creek Pit at the location listed in Table 8. Table 8. Recycled Produced Water Source Source Name Location ID Owner Latitude/ Longitude Beaver Creek Pit 432702 TEP Rocky Mountain LLC (Operator #96850) 39.4593 / -107.82296 CPX anticipates that approximately 75 percent of the water for completions will be recycled produced water (1,200,000 bbls). Approximately 25 percent of the water for completions will be water from well completions to use for subsequent completions (400,000 bbls). Recycled produced water purchased from TEP will be treated with residence time and biocides at TEP’s existing centralized facility. CPX Piceance Holdings, LLC Water Plan Well Pad 36A 4 November 2022 Recycled produced water sourced from the Beaver Creek Pit will be transported to CPX’s existing Pad 2 Tanks (Location ID 455779) in the SW ¼ SE¼, Section 13, Township 7 South, Range 94 West, near the intersection of CR 317 and FS 824. Water will be conveyed from the Beaver Creek Pit using an anticipated 8-inch surface line. At Pad 2, water will be conveyed to the approved Well Pad 25A (Location ID 334457) using CPX’s existing buried 8-inch flexsteel water pipeline. Water then will be conveyed from Well Pad 25A to the approved Pad 25B Temporary Water Support Pad (Location ID 482984) using a 4-inch steel surface line. Recycled produced water stored on Pad 25B will be contained in modular large volume tanks (MLVTs). From there, water will be transferred for well completions using a 4-inch steel surface line, either to Well Pad 25A as a SIMOPs support pad or to Well Pad 36A as a non-SIMOPs operation. Similarly, water from well completions from Well Pad 36A will be transferred to Pad 25B for storage using a 4-inch steel surface line. In this way, water from well completions will be recycled and reused for CPX’s own operations. Operations are shown on the Process Flow Diagrams, Related Location and Flowline Map, and Other Location and Flowlines figure submitted with the Form 2A application. A representative sample of background concentrations from existing Well Pad 25A produced water is shown in Table 9. CPX commits to providing background concentrations of chemicals listed in Table 437-1 via Form 4 Sundry. Table 9. Background Concentrations from Representative Well Pad 25A Produced Water Analyte Background Concentrations (mg/L) TPH High Fraction 559 TPH Low Fraction 396 Benzene 35.3 Toluene 400 Ethylbenzene 74.0 Xylene 684 Naphthalene ND 1,3,5-Trimethylbenzene 261 1,2,4-Trimethylbenzene 332 Sample collected January 25, 2022. CPX management of E&P waste under Rule 905.a is listed in Table 10. Table 10. Compliance with Rule 905.a.(3) Rule 905.a.(3).A Recycled produced water and water from well completions will be used for well completions. Rule 905.a.(3).B Volumes and uses are described above and in Table 4. Rule 905.a.(3).C Recycled produced water will be treated at a minimum with residence time and biocides. It will be stored in MLVTs on Temporary Water Support Pad 25B. Rule 905.a.(3).D CPX will not add additives listed in Table 437-1 to produced water. CPX will test for chemicals listed in Table 437-1, which have a standard in Table 915-1, to determine background concentrations of produced water. CPX Piceance Holdings, LLC Water Plan Well Pad 36A 5 November 2022 Rule 905.a.(3).E Any excess recycled produced water and water from well completions will be disposed of at CPX’s proposed UIC Well TPR 176-25 on Well Pad 25A under a permit issued by COGCC. As a contingency, CPX may use a third-party disposal facility, such as Greenleaf Environmental Services. Rule 905.a.(3).G CPX will use recycled produced water and water from well completions for well completions following well drilling. Rule 905.a.(3).I Recycled produced water will be conveyed from TEP’s Beaver Creek Pit for use on TPR as described in Section 4.0. 5.0 Hydraulic Fracturing Chemicals In conformance with Rule 437.a, CPX will not add additives listed in Table 437-1 to recycled produced water. Representative samples of untreated produced water at Well Pad 25A are listed in Tables 9 and 11. They show representative background concentrations from the formation. Per Rule 437.c., chemical constituents listed in Table 437-1 that have a standard in 915-1 are: • Benzene • Ethylbenzene • Xylene • 1,3,5-trimethylbenzene Analytical results from Well Pad 25A for Rule 437.c. are listed in Table 11. Table 11. Representative Analytical Results from Well Pad 25A for Rule 437.c. Analyte Benzene Ethylbenzene Xylene 1,3,5 Trimethylbenzene Background Concentration (mg/L) 35.3 74.0 684 261 Samples collected January 25, 2022 CPX Piceance Holdings, LLC 34 S. Wynden Drive, Suite 240 Limited Impact Review Garfield County, Colorado Houston, TX 77056 TPR Well Pad 36A Article 9 Oil and Gas Permit Application Cumulative Impacts Plan COGCC Rule 304.c.(19) CUMULATIVE IMPACTS PLAN Well Pad 36A December 2022 1.0 OIL AND GAS LOCATION DESCRIPTION CPX Piceance Holdings, LLC (CPX) owns and operates Tepee Park Ranch (TPR) in Garfield County, Colorado. CPX has prepared this Cumulative Impacts Plan for continued development of the existing Well Pad 36A on TPR. The Well Pad 36A Oil and Gas Development Plan (OGDP) has been prepared as an amendment to CPX’s approved OGDP ID 482255. The sections below correspond to Colorado Oil & Gas Conservation Commission (COGCC) Rule 304.c.(19) to prepare a Cumulative Impacts Plan consistent with the provisions of the rule. CPX proposes the continued development of the existing Well Pad 36A on TPR. TPR is privately owned and operated by CPX, predominantly for the exploration and development of natural gas wells. CPX will develop CPX fee minerals and federal minerals from this location. Well Pad 36A is an existing natural gas well pad on an established disturbed surface. The location is approximately 12 miles south of Rifle, Colorado in the SW ¼ NE ¼ Section 36, Township 7 South, Range 94 West. The site elevation is approximately 9,355 feet. TPR is historically disturbed from human activity, hunting, logging, grazing, shale excavation, oil and gas development, and dirt roads. The location is greater than 1 mile fro m the nearest residence. Well Pad 36A contains three permitted natural gas wells. One is designated drilled but uncompleted (DG). Two are designated expired permit (EP). CPX proposes to develop a total of 32 new natural gas wells on the location in CPX fee minerals (25 wells) and federal minerals (7 wells) and to plug and abandon the drilled but uncompleted well (Well 132-36). The location is further described in Table 1. Existing and proposed wells are listed in Table 2. Table 1. Existing Well Pad 36A Location Legal Description Location Coordinates Location ID County SW ¼, NE 1/4, Section 36 Township 7 South, Range 94 West Latitude: 39.395017 Longitude: -107.831908 334460 Garfield Table 2. Existing and Proposed Wells Existing Wells Proposed Wells One Spud but Uncompleted Well (DG): TPR 132-36 (API # 05-045-16949) Two Expired Permits (EP): TPR 143-36 (API # 05-045-16950) TPR 112-6 (API # 05-045-16951) 32 Natural Gas Wells Plug and Abandon Well 132-36 Well Pad 36A is located in an area zoned Rural by Garfield County. This portion of TPR is bounded by U.S. Forest Service land to the north, south, and east. It is surrounded by additional CPX lands to the west. The area is predominantly spruce/fir forest with an understory of native forbs and grasses. Beaver Creek, a perennial waterbody, flows from south to north across TPR. The creek is immediately downgradient to the west of Well Pad 36A and is designated as Rule 1202.c.(1).R High Priority Habitat (HPH) for cutthroat trout designated crucial habitat and native fish and other native aquatic species conservation waters (within 500 feet of ordinary high water mark). CPX performed an Alternative Location Analysis (ALA) and conducted consultation with Colorado Parks & Wildlife (CPW) for the location’s proximity to Rule 304.b.(2).B.vii and viii surface water and HPH. CPX Piceance Holdings, LLC Cumulative Impacts Plan Well Pad 36A 2 December 2022 TPR is accessed using the existing 20-foot-wide unpaved private Tepee Park Ranch road. Existing off- location flowlines are buried in a shared trench from TPR to CPX’s Pad 2 Tanks in Section 13, Township 7 South, Range 94 West. The off-location flowlines transport natural gas, condensate, and water. Where the off-location flowlines cross Forest Service land, they were permitted under an easement gran ted by the Forest Service. CPX proposes to extend the buried flowlines to Well Pad 36A in a single trench adjacent to the Tepee Park Ranch road. The flowlines were described in the approved application for Well Pad 25A (Location ID 334457). Existing Well Pad 25A is in the SW ¼ SE ¼ Section 25, Township 7 South, Range 94 West. Well Pad 25A has two existing and producing natural gas wells. The Well Pad 25A location was approved for development of 34 new natural gas wells and conversion of one drilled but uncompleted well for use as a Class 2 Underground Injection Control Well. CPX also received approval to construct Temporary Water Support Pad 25B (Location ID 482984) in the SW ¼ SE ¼ Section 25, Township 7 South, Range 94 West. Pad 25B is proposed to contain 12 modular large volume tanks to store recycled produced water and water from well completions to use for subsequent well completions on TPR. CPX proposes to use Well Pad 25A as a remote frac pad to support SIMOPs for Well Pad 36A. Using Well Pad 25A as a frac support pad to conduct SIMOPs on Well Pad 36A would allow CPX to expedite the completions schedule. Alternatively, equipment for completions would be located on Well Pad 36A. Likewise, CPX proposes to use Well Pad 36A as a remote frac pad for development of the other locations on TPR. CPX does not propose to expand Well Pad 36A. Disturbance is complete, and the pad is stabilized. An additional 4 to 6 inches of aggregate will be added to the well pad surface to support drilling equipment. CPX anticipates 1 month for site preparation, 8 months for drilling, 8 months for completions, 1 month for interim reclamation, and a 30-year life of operations. The disturbance areas and anticipated schedule are shown in Tables 3 and 4. Table 3. Disturbance Areas Area Acres Description Oil and Gas Location 5.45 Existing Disturbance Working Pad Surface 2.06 Existing Disturbance Well Pad After Interim Reclamation 1.34 Existing Disturbance Tepee Park Ranch Road 3.63 Existing Disturbance Total New Disturbance 0.00 Table 4. Anticipated Schedule Location Schedule Construction 1 month Drilling 8 months Completions 8 months Interim Reclamation 1 month Production 30 years This Plan addresses the COGCC requirement at Rule 304.c.(19) to address cumulative impacts to resources identified in Rule 303.a.(5). Pursuant to Rule 304.c.(19), the Plan includes: CPX Piceance Holdings, LLC Cumulative Impacts Plan Well Pad 36A 3 December 2022 A. A description of resources to which cumulative adverse impacts are expected to increase; B. A description of measures taken to avoid or minimize the extent to which cumulative impacts are increased; C. A description of measures taken to mitigate or offset cumulative impacts; and D. Additional information determined to be reasonable and necessary to the evaluation of cumulative impacts. Resources listed in Rule 303.a.(5) and addressed in this Plan are: • Air Resources • Public Health • Water Resources • Terrestrial and Aquatic Wildlife Resources & Ecosystems • Soil Resources • Public Welfare, including: o Noise o Light o Odor o Dust o Recreation and Scenic Values 2.0 AIR RESOURCES A. Cumulative Impacts The proposed Oil and Gas Location is in Garfield County, Colorado. The area is designated attainment for National Ambient Air Quality Standards established by the U.S. Environmental Protection Agency. There will be cumulative impacts from air emissions of criteria and non-criteria pollutants from equipment used during pre-production and production. Cumulative impacts from the estimated short-term pre-production emissions and long-term production emissions are shown below. Pre-production emissions include operations for construction, drilling, and completions. Production emissions represent 1 year of operation. Diesel vehicle road miles are shown for all phases of development. Table 5. Pre-Production Emissions (tons) CPX Piceance Holdings, LLC Cumulative Impacts Plan Well Pad 36A 4 December 2022 Table 6. Production Emissions (tons) Table 7. Diesel Vehicle Road Miles Diesel Vehicle Road Miles Construction Drilling Completions Interim Reclamation Production1 Well Pad 36A 2,520 97,031 82,497 504 49,841 1Life of production B. Measures to Avoid or Minimize Cumulative Impacts To avoid or minimize air impacts, CPX will: • Use the existing Well Pad 36A and maximize its well count to limit surface disturbance. • Submit for review and implement a pre-production Air Quality Monitoring Program to establish baseline, pre-production emissions, and 6 months of emissions during production. • Use a closed-loop drilling system to minimize emissions. • Contain flowback and produced water in enclosed tanks. Vapors will be controlled using an enclosed combustor. • Implement a leak detection and repair (LDAR) program using audio, visual, and olfactory (AVO) monitoring for leak and spill detection. • Conduct annual flowline integrity testing in accordance with Rule 1104. • Maintain and periodically test tank seals to ensure that they provide the required back pressure and prevent emissions. • Use automated tank gauges to gauge liquids without opening the thief hatch. • Commit to connecting to a gas gathering system after well drilling and completions. • Comply with conditions of permits issued by the Colorado Department of Public Health and Environment (CDPHE), Air Pollution Control Division. CPX Piceance Holdings, LLC Cumulative Impacts Plan Well Pad 36A 5 December 2022 • Require that employees and contractors observe posted speed limits on public roads and a 25 mile per hour speed limit on TPR access roads. • Regularly inspect the access road for evidence of inadequate drainage and formation of potholes. • Grade, blade, and fill potholes to maintain the road surface and discourage vehicles from widening the roadway or contributing to erosion. • Use spot graveling to avoid erosion, formation of silts, and to stabilize surfaces for truck travel. • Use fresh water from an approved water source to wet the surface for control of fugitive dust on the well pad, access road, or pipeline corridor. • Mound the soil stockpile to prevent loose soils and promote vegetative growth. • Haul proppant in closed containers and offload it within secondary containment around the proppant storage silos. C. Measures to Mitigate or Offset Cumulative Impacts To mitigate or offset air impacts, CPX will: • Use existing flowlines and proposed new flowlines to reduce truck traffic for completions (9,000 truckloads, est.) and life of operations (28,000 truckloads, est.). • Use the proposed CPX UIC well for disposal of produced water and water from well completions generated on TPR to avoid truck trips (28,000 truckloads, est.). • Reclaim the areas not needed to support production in the first growing season and within 6 months after completing well development. D. Additional Information See detailed information in the Dust Mitigation Plan and Topsoil Protection Plan submitted with the Form 2A application. 3.0 PUBLIC HEALTH A. Cumulative Impacts The Oil and Gas Location is greater than 1 mile from the nearest residence. There are no Disproportionately Impacted Communities affected by the location. The wells will be drilled using a water-based mud and a closed-loop drilling system. During pe-production and production, the facility will operate with an enclosed combustor and in accordance with CDPHE standards. The vapor controls from the enclosed combustor have a manufacturer control rating of at least 95 percent destruction. There will be no cumulative impacts to public health because of the closed-loop drilling system, enclosed tanks, vapor controls, and significant distance to the nearest receptor. Estimated short-term pre-production emissions and long-term production emissions of hazardous air pollutants are shown below. Production emissions represent 1 year of operation. Estimated vehicle trips also are shown below for all phases of production. CPX Piceance Holdings, LLC Cumulative Impacts Plan Well Pad 36A 6 December 2022 Table 8. Pre-Production Emissions (pounds) Table 9. Production Emissions (pounds) Table 10. Estimated Vehicle Trips B. Measures to Avoid or Minimize Cumulative Impacts To avoid or minimize public health impacts, CPX will: • Submit for review and implement a pre-production Air Quality Monitoring Program to establish baseline, pre-production emissions, and 6 months of emissions during production. • Use a closed-loop drilling system to minimize emissions. • Contain flowback and produced water in enclosed tanks. Vapors will be controlled using an enclosed combustor. • Implement a leak detection and repair (LDAR) program using audio, visual, and olfactory (AVO) monitoring for leak and spill detection. • Conduct annual flowline integrity testing in accordance with Rule 1104. Vehicle Trips Construction Drilling Per Mo / Yr Completions Per Mo / Yr Interim Reclamation Production Per Mo / Yr Well Pad 36A 140 630 / 5,050 372 / 2,966 24 115 / 1,380 CPX Piceance Holdings, LLC Cumulative Impacts Plan Well Pad 36A 7 December 2022 • Maintain and periodically test tank seals to ensure that they provide the required back pressure and prevent emissions. • Use automated tank gauges to gauge liquids without opening the thief hatch. • Commit to connecting to a gas gathering system after well drilling and completions. • Comply with conditions of permits issued by CDPHE. C. Measures to Mitigate or Offset Cumulative Impacts To mitigate or offset air impacts, CPX will: • Develop operations that maximize the distance to the nearest receptor. D. Additional Information See detailed illustration of the surrounding areas on the Cultural Features Map submitted with the Form 2A application. 4.0 WATER RESOURCES A. Cumulative Impacts The nearest water well is approximately 320 feet west and across Beaver Creek from the location. The water well was developed by CPX. Shallow water will not be extracted from the well. Water will be extracted from the well at depths below 60 feet. The nearest downgradient surface water, Beaver Creek, is approximately 130 feet to 223 feet west of the location. Beaver Creek is designated Rule 1202.c.(1).R cutthroat trout designated crucial habitat and native fish and other native aquatic species conservation waters (within 500 feet of ordinary high water mark). CPX performed an ALA and conducted Rule 309.e.(2).A consultation with CPW for the location’s proximity to Rule 304.b.(2).B.vii and viii surface water and HPH. Specifically, Well Pad 36A is in Rule 1202.c.(1).R HPH, with portions of the west side of the pad within 300 feet of Rule 1202.c.(1).R HPH. CPX conducted a pre-application consultation meeting and site visit with officials from CPW on May 27, 2021. CPW staff viewed the existing Well Pad 36A, its environmental setting, mapped water features, and the controls on Well Pad 36A to prevent runoff of soils and sediments and potential impacts to HPH. Following the site visit and consultation, CPW provided CPX with a written waiver and variance recommendation for Well Pad 36A on June 18, 2021 for new natural gas development within the Rule 1202.c.(1).R buffer. CPW renewed the waiver and variance recommendation on July 13, 2022. CPW cited the location’s engineered controls and best management practi ces and stated that it incentivizes the use of already disturbed locations when no adverse impacts are anticipated. CPW further stated that construction of a new location, instead of continued use of the existing location, would cause more undesired disturbance and habitat fragmentation, and would pose more risk to HPH and the watershed. CPW provided an additional and related written waiver on November 18, 2022 to waive the restriction from staging, refueling, and Chemical storage areas within 500 feet of the ordinary high water mark of any river, perennial or intermittent stream, lake, pond, or wetland. Through its waiver, CPW found that, the already developed location, avoidance measures, and BMPs are sufficient ly protective. There will be no cumulative impacts to water wells or surface water because of the depth to groundwater; distance and monitoring of the water well; natural gas well development without use of pits or ponds; steel secondary containment around liquids storage; significant engineered stormwater controls; and drill cutting CPX Piceance Holdings, LLC Cumulative Impacts Plan Well Pad 36A 8 December 2022 burial in a drill cuttings trench on the location after testing for compliance with constituents in Table 915 -1. Additional measures are described below. Water use for well development will be an estimated 55,250 bbls of freshwater and 1,600,000 bbls of recycled produced water and water from well completions. Freshwater will be sourced from the Loesch and Crann Ditch Company intake on Last Chance Ditch in Rifle, Colorado that will be trucked to the location. CPX plans to source recycled produced water from the Terra Energy Partners Beaver Creek Pit and pipe it to the location using a temporary above-ground water support line and CPX’s existing buried flowline at its Pad 2 Tanks. There will be cumulative impacts from the volume of freshwater used for well development. B. Measures to Avoid or Minimize Cumulative Impacts To avoid or minimize water impacts, CPX will: • Contain flowback and stimulation fluids in tanks that are placed on a Working Pad Surface in an area with downgradient perimeter berming. • Construct lined containment devices pursuant to Rule 603.o around any new condensate and produced water storage tanks. There will be no crude oil storage on Well Pad 36A. • Visually inspect secondary containment for evidence of damage, deterioration, or loss of integrity. Repairs will be made promptly to prevent the risk of migration from a leak or spill. • Inspect the location on a daily basis. Well drilling and completions will be manned and monitored 24/7 by CPX personnel and contract operators. Drips, leaks, or spills will be detected visually or by a pressure loss to avoid or contain fluid or material within the multiple layers of secondary containment. • Maintain adequate spill response equipment on the location during drilling and completion operations. • Develop wells without utilization of fluid pits or ponds. • Maintain an earthen berm around the perimeter of the well pad with 2-foot-high earthen berms, compacted to 95 percent soil/moisture density. The outside slopes of the berms have 80 percent vegetative cover. The berms are stable with high structural integrity. • Capture stormwater on the location using a system consisting of a drain on the well pad, which is piped to a lined trench and lined catchment basin. Solids will settle in the catchment basin for removal. The stormwater will evaporate. • Ensure that the drill rig and horsepower equipment have liners to capture and contain drips or leaks. • Provide secondary containment for temporary equipment and materials used during well drilling and completions. • If performing SIMOPs on a remote temporary frac pad: ▪ Place a temporary frac line adjacent to the private access road. ▪ Sleeve the temporary frac line crossing Beaver Creek and intermittent streams during completions with 12-inch diameter welded steel pipe. ▪ Install a lined catch basin on either side of the stream crossing to capture fluid in case of a leak. ▪ Size catch basins to contain the volume of the frac line run. CPX Piceance Holdings, LLC Cumulative Impacts Plan Well Pad 36A 9 December 2022 • Provide continuous flow and pressure monitoring for temporary frac lines during completions for prompt identification of loss of pressure. • Monitor equipment and transfer lines daily during well drilling and completion for signs of drips, leaks, or spills, which will be corrected promptly. • Use a closed loop solids control system with no reserve pits. • Test tanks per manufacturer’s specifications prior to putting them into service for production. Periodic integrity testing after initial startup will occur per API or STI standards and manufacturer’s recommendations. • Conduct annual flowline integrity testing in accordanc e with Rule 1104. • Conduct Rule 615 baseline water well sampling prior to setting conductor pipe, followed by subsequent monitoring of the water well within 12 months after completions, between 60 and 72 months after completions, and every 5 years for the life of the well. C. Measures to Mitigate or Offset Cumulative Impacts To mitigate or offset water impacts, CPX will: • Minimize the number of produced water and condensate tanks during production to a projected two of each set back from surface water by greater than 300 feet. They will be surrounded by steel secondary containment. • To protect Beaver Creek, tank loading and unloading will not occur on the well pad. Tank loading and unloading were moved off of TPR to CPX’s Pad 2 Tanks along County Road 317. • Develop wells using a closed-loop drilling system to reduce water use by recycling water in- situ. • Use recycled produced water and water from well completions, in lieu of freshwater, for well completions. • Install a SCADA continuous monitoring platform for remote monitoring, alerting, and shut -in capabilities. • Perform interim reclamation during the first growing season and within 6 months after well development to reclaim disturbed soil. D. Additional Information See detailed information in the Fluid Leak Detection Plan, Stormwater Management Plan, Interim Reclamation Plan, Wildlife Plan, and on the Hydrology and Wildlife Habitat Maps submitted with the Form 2A application. 5.0 TERRESTRIAL AND AQUATIC RESOURCES & ECOSYSTEMS A. Cumulative Impacts Section 4.0, above, describes that the Oil and Gas Location is an area designated HPH under Rule 1202.c.(1).R cutthroat trout. CPX consulted with CPW pursuant to Rule 309.e.(2).A, and CPW reviewed the location during a site visit on May 27, 2021. CPW issued a written waiver and variance recommendation for Well Pad 36A on June 18, 2021, renewed the waiver and variance recommendation on July 13, 2022, and issued an additional waiver on November 18, 2022 for the location’s proximity to Beaver Creek under Rule 1202.a.(3). There will be no cumulative impacts to aquatic resources with implementation of the engineered controls and practices described in Section 4.0. CPX Piceance Holdings, LLC Cumulative Impacts Plan Well Pad 36A 10 December 2022 The Oil and Gas Location is not within mapped HPH for terrestrial wildlife. There is no mapped terrestrial HPH within 1 mile of the Working Pad Surface. U.S. Forest Service data shows mapped lynx denning habitat approximately 1,770 feet south and lynx winter habitat approximately 1,740 feet south of the location. Development on Well Pad 36A will avoid potential impacts to mapped lynx habitat. The well pad represents a continued land use in the area. It is separated from mapped habitat by approximately one-third mile of spruce/fir forest, ridgelines, and a drainage. The combination of distance, forest cover, and topography attenuates noise and light and avoids potential impacts to mapped habitat. Lighting will occur only during well drilling and completions and will be cast downward. The location will be unlit during production. The White River National Forest Land and Resource Management Plan (2002) and Forest Service Southern Rockies Lynx Amendment (2008) list management practices for lynx including protecting water quality and habitat connectivity in linkage areas; managing vegetation, grazing, and recreation; and discouraging snow compaction in lynx habitat. There are no references to noise or light in relation to lynx. The well pad represents continued activity that has occurred historically on TPR . The 2018 National Environmental Policy Act Environmental Assessment for realignment of Forest Service Road 824 and other improvements (U.S. Forest Service 2018) had a Finding of No Signif icant Impact for construction adjacent to the mapped lynx habitat. There will be no cumulative impacts to lynx habitat because of the distance to habitat, separation in elevation from normal lynx habitat, and findings established previously by the Forest Service. Colorado is part of a broad Central Flyway for migratory birds, one of four North America flyways. There is no mapping specific to migratory bird pathways near the Oil and Gas Location, according to data provided by the U.S. Fish and Wildlife Service, Colorado Parks and Wildlife, and National Audubon Society. There will be no cumulative impacts to migratory bird pathways. Vegetation clearing is complete for the well pad. The location is zoned Rural by Garfield County. Allowable land uses in areas zoned rural include oil and gas development. The land use represents continued use of an existing 5.45-acre location After interim reclamation of the well pad, the cumulative loss of cover and foraging habitat for birds and wildlife will be reduced to the 1.34-acre area supporting production. B. Measures to Avoid or Minimize Cumulative Impacts To avoid or minimize terrestrial and aquatic wildlife resources and ecosystem impacts, CPX will conduct the measures described in Section 4.0. CPX additionally will: • See all measures in Section 4.0 to protect aquatic resources. • Avoid open liquids storage on the locations during pre-production and production. • Keep the location unlit during production. • Ensure that trenches left open for more than 5 consecutive days during construction of flowlines regulated under the 1100 Series Rules have wildlife escape ramps at a minimum of one ramp per 0.25 miles of trench. • Either conduct all vegetation removal necessary for oil and gas operations outside of the nesting season for migratory birds (April 1 to August 31) or conduct a pre-construction nesting migratory bird survey within the approved disturbance areas prior to any vegetation removal during the nesting season. • Consolidate and centralize fluid collection and distribution facilities to minimize impacts to wildlife. CPX Piceance Holdings, LLC Cumulative Impacts Plan Well Pad 36A 11 December 2022 • Install screening or other devices on the stacks and on other openings of the heated separator to prevent entry by migratory birds. C. Measures to Mitigate or Offset Cumulative Impacts To mitigate or offset terrestrial and aquatic wildlife resources and ecosystem impacts, CPX will: • Downsize the location during interim reclamation to a 1.34-acre Production Pad. • Reclaim the remaining portion of the Oil and Gas Location to pre-construction habitat. • Cross rip the reclaimed area to decompact the soil and establish a seedbed. Seed the area using a U.S. Forest Service-recommended seed mix, which is appropriate to the site’s plant community next to Forest Service lands and to its elevation. • Transport natural gas and condensate off location by buried flowline to CPX’s Pad 2 Tanks in Section 13, Township 7 South, Range 94 West. • Use CPX’s proposed UIC well for disposal of produced water and water from well completions generated on TPR to avoid truck trips on and off the location. D. Additional Information See detailed information in the Wildlife Protection Plan and Interim Reclamation Plan, and on the Wildlife Habitat Map submitted with the Form 2A application. 6.0 SOIL RESOURCES A. Cumulative Impacts Soils at the Oil and Gas Location and access road are 104A: Haplocryolls-Cryaquolls complex; 220B: Angostura Family; 331C: Woodrock-Angostura families complex; 338B: Wetopa-Doughspon-Echemoor families complex; and 449C: Tampico-Echemoor-Eyre families complex. Collectively, these soils have between 0 and 65 percent slopes. The A horizon is loam, silt loam, and silty clay loam. This overlays generally silty loam, clay loam, and cobbly loam. The soils are well drained. The Oil and Gas Location has an existing disturbance of 5.45 acres and an existing access road of 3.63 acres of disturbance. The Tepee Park Ranch road is long-established and pre-dates oil and gas development on TPR. Disturbance for the Oil and Gas Location is complete. There are previous cumulative impacts to soil resources and vegetation from disturbance of topsoil at the well pad and access road. After interim reclamation, the impacts will be reduced to 1.34 acres during production, plus the continued use of the Tepee Park Ranch road. After final reclamation, the impacts will be eliminated by plugging the well s in accordance with COGCC requirements, removing equipment and surfacing material, and restoring the location to specifications from COGCC. Table 11. Disturbance Area Location Oil and Gas Location (ac) TPR Access Road (ac) Total New Disturbance (ac) Location After Interim Reclamation (ac) Well Pad 36A 5.45 3.63 0.00 1.34 CPX Piceance Holdings, LLC Cumulative Impacts Plan Well Pad 36A 12 December 2022 B. Measures to Avoid or Minimize Cumulative Impacts To avoid or minimize soil impacts, CPX will: • Protect topsoil from contamination by stockpiling it in a location free from drilling, fuel storage, and parking. • Protect soil from compaction by designating it as topsoil for reclamation. • Protect the topsoil stockpile from wind degradation by mounding at an appr oximately 3.5:1 slope to prevent loose soils while promoting continued microbial activity. • Protect the topsoil stockpile from erosion by ensuring that stormwater controls and diversions are installed, where needed, to divert stormwater away from the stockpile. • Allow vegetation to establish on the topsoil stockpile to stabilize it, outcompete weeds, and promote soil microbial activity. • Maintain erosion controls to prevent stormwater runoff from the well pad. C. Measures to Mitigate or Offset Cumulative Impacts To mitigate or offset soil impacts, CPX will: • Use the existing 5.45-acre Oil and Gas Location and Tepee Park Ranch road. • Conduct interim reclamation during the first favorable growing season and within 6 months after well drilling is complete. D. Additional Information See detailed information in the Topsoil Protection Plan, Stormwater Management Plan, and Interim Reclamation Plan submitted with the Form 2A application. 7.0 PUBLIC WELFARE A. Cumulative Impacts Noise TPR proposes continuation of existing land uses, which have included historical logging operations and current natural gas production. There are no residences within 2,000 feet, or within 1 mile, of the Oil and Gas Location. The nearest residence is a single residence greater than 1 mile northwest of the Oil and Gas Location, as shown on the Cultural Features Map submitted with the Form 2A application . This residential building unit (RBU) is separated from Well Pad 36A by aspen and spruce/fir forest. The existing well pad is constructed. There will be no construction noise. Noise from drilling and completions is not expected to be perceptible at the RBU because of its significant distance from the well pad. The location is not in HPH except for aquatic habitat. The location is historically disturbed from human activity, hunting, logging, grazing, shale excavation, oil and gas development, and dirt roads. During production, the location will contain only wellheads, separators, an enclosed combustor, tank storage, and associated equipment. Routine inspection and maintenance visits will be conducted using a light -duty pickup truck. Produced water is not anticipated to be loaded by truck from this location because the UIC well proposed for TPR will be the primary source of disposal for produced water and water from well completions generated on TPR. No processing will occur on the location. There will be no cumulative impacts from noise because of the distance to the nearest residence; continuation of existing land uses; lack of terrestrial HPH; and the limited truck trips during production. CPX Piceance Holdings, LLC Cumulative Impacts Plan Well Pad 36A 13 December 2022 Light There are no RBUs within 2,000 feet, or within 1 mile, of Well Pad 36A. The nearest residential building unit is greater than 1 mile northwest of the location. The RBU is separated from Well Pad 36A by aspen and spruce/fir forest. Light used on the well pad will be cast downward during drilling and completions. Light is not expected to be perceptible because of the significant distance to the RBU and screening from the intervening greater than 1 mile of forest. The Oil and Gas Location is not within HPH except for aquatic habitat. The location will be unlit during production. Odor The wells will be drilled using a water-based mud and a closed-loop drilling system. During production, the locations will operate with vapor recovery controls and using enclosed combustors with a manufacturer control rating of at least 95 percent destruction efficiency. The nearest residence is greater than 1 mile away. There will be no cumulative impacts from odor because of the controls in place and lack of receptors. Dust The Oil and Gas Location and access road are constructed. The Working Pad Surface will be reduced to 1.34 acres during production. The reclaimed area will be revegetated. Proppant used during completions will be hauled to the location using pre-pneumatic dry bulk trailers. Three cones on the trailer will be full of proppant, and an air compressor will be used to transfer the proppant pneumatically out of the truck to sand storage silos. A hose and air blower will transfer proppant to a blender bulk hopper and gravity fed chute with a vacuum system that captures fugitive dust in filter canisters. Dust will be contained during this transfer process. Offloading will occur within secondary containers around the proppant storage silos. Containment will be a rubber or plastic liner with 8-inch supported sides. During well drilling and completions, haul traffic will be reduced by piping recycled produced water from CPX’s Pad 2 Tanks to the approved Temporary Water Support Pad 25B. During production, haul traffic will be substantially minimized by disposing of produced water using CPX’s proposed UIC well. CPX will continue its practice of watering the FS 824 and Tepee Park Ranch road to reduce fugitive dust. Cumulative impacts from dust will be controlled using best management practices (BMPs) listed below and in the operator’s Dust, Topsoil, Interim Reclamation , and Stormwater Management Plans. Recreation and Scenic Values The location is in remote Garfield County on private property located at an elevation of approximately 9,355 feet. The area is disturbed from historical human activity, hunting, logging, grazing, shale excavation, oil and gas development, and dirt roads. The nearest residence is greater than 1 mile northwest. The U.S. Forest Service Battlement Trail is located approximately 390 feet east. The trail crosses TPR private property under a CPX perpetual easement. The trail is screened from the well pad by dense vegetation in spruce/fir forest. Development on Well Pad 36A is a continued existing use on private property proximate to the trail. The Oil and Gas Location is greater than 1.5 miles by road from the nearest public access point. The cumulative impact to recreation and scenic values will be from the extent to which well drilling and completions noise is perceptible or activity is visible on the well pad from vantage points on the trail crossing CPX private property. There are no other nearby state parks, state wildlife areas, trust lands, or designated outdoor activity areas. B. Measures to Avoid or Minimize Cumulative Impacts To avoid or minimize public welfare impacts, CPX will: • Maintain equipment and vehicles in proper working condition to minimize noise. • Cast lights downward on the operations during well drilling and completions. CPX Piceance Holdings, LLC Cumulative Impacts Plan Well Pad 36A 14 December 2022 • Water the well pad and access when indicated by loose soils to stabilize the soil and form a crust. • Reclaim the areas not needed to support production during the first growing season and within 6 months of completing well development. C. Measures to Mitigate or Offset Cumulative Impacts To mitigate or offset public welfare impacts, CPX will: • Comply with the noise levels specified in Rule 423.b.(1). • Reduce truck traffic by using the proposed UIC well and buried flowlines. • Paint tanks to blend with the surrounding landscape. D. Additional Information See detailed information in the Dust Control Plan, Topsoil Protection Plan, and Location Drawing submitted with the Form 2A application.