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Home My WebLink AboutMIDWEST PAD - - Crestone - 1/21/2026State of Colorado Energy & Carbon Management 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 01/25 This Oil and Gas Location Assessment is to be submitted to the ECMC 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 ECMC website at https://ecmc.state.co.us/ for all accompanying information pertinent this Oil and Gas Location Assessment. Document Number: 404141703 05/30/2025 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 # This location includes a Rule 309.f.(1).A.ii. variance request. rachel_friedman@oxy.com (720) 929-6564 ( ) RACHEL FRIEDMAN email: Fax: Phone: Contact Information Name: 80217-3779COZip:State:DENVER P O BOX 173779 KERR MCGEE OIL & GAS ONSHORE LP 47120 City: Address: Name: Operator Operator Number: FINANCIAL ASSURANCE FOR THIS LOCATION (check all that apply) Plugging, Abandonment, and Reclamation 20230087 Gas Gathering, Gas Processing, and Underground Gas Storage Facilities 20190011Centralized E&P Waste Management Facility X 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 LocationX 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 250500093 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 491891 MIDWEST PAD Number:MIDWEST Name: LOCATION IDENTIFICATION 01/13/2029Expiration Date: Location ID:492821 OGDP ID:491891 Page 1 of 26Date Run: 1/21/2026 Doc [#404141703] 02/17/20251.7 Date of Measurement:GPS Quality Value: 4877668W 3N 34 Ground Elevation:Meridian:Township:SESE QuarterQuarter: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. Range: Type of GPS Quality Value:PDOP Latitude:40.178307 Longitude:-104.983491 RELEVANT LOCAL GOVERNMENT SITING INFORMATION WELD 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.” MeadCounty: 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:06/09/2025 Current status or disposition of the Relevant Local Government permit application for this proposed Oil and Gas Location:Approved Status/disposition date:12/08/2025 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: Erika RasmussenContact Name:Contact Phone:970-535-4477 Contact Email:ERasmussen@townofmead.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. Type of Proximate Govt County Municipality Contact Name Contact Phone Contact Email County WELD Stephanie Frederick 970-400-3581 SFREDERICK@WELD. GOV Municipality Firestone Todd Bjerkaas 303-531-6276 TJBERKAAS@FIREST ONE.GOV (Enter as many Related Locations as necessary. Enter the Form 2A document # only if there is no established COGCC Location ID#) 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: 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. Page 2 of 26Date Run: 1/21/2026 Doc [#404141703] Contact Name:Contact Phone: Contact Email:Field Office: Additional explanation of local and/or federal process: A Special Use Permit (SUP) is required by Mead, with the final approval from the Town of Mead Board of Trustees. KMOG has participated in a pre-application meeting on January 5, 2023 and is working on the SUP with an anticipated submittal later this spring. Did a pre-application Formal Consultation Process occur with the Relevant Local Government per Rule 301.f.(3)? PRE-APPLICATION MEETINGS AND CONSULTATIONS Complete this section for any pre-application meeting or 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. If a pre-application Director Meeting occurred, attach a Pre-Application Director Meeting Summary. If a pre-application Community Meeting occurred, attach a Pre-Application Community Meeting Summary. Date of local government consultation: Did a pre-application Formal Consultation Process occur with the Federal land manager per Rule 301.f.(3)? Date of federal consultation: Did a pre-application Director Meeting occur per Rule 301.g.(1)? Date of Director Meeting: Was a pre-application Community Meeting required per Rule 301.g.(2)? Did a pre-application Community Meeting occur per Rule 301.g.(2)? Date of Community Meeting: RELEVANT LOCAL GOVERNMENT OR FEDERAL PRE-APPLICATION CONSULTATION 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 < 1/2 mile from RBU/HOBUX X ii. WPS < 1/2 mile from School/Child Care Center iii. WPS < 1,500 feet from DOAA 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 corridorX Page 3 of 26Date Run: 1/21/2026 Doc [#404141703] 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 40.166592 -104.921174 x x x AL5 NWSW Sec.5 2N 67W -This AL is within 2,640' of 17 RBU -This AL upgradient of a mapped NWI riparian corridor -Located within 5,280' of RBU within a DIC -KMOG is unable to fully develop the DSU from this AL, requiring a 2nd location. - This AL is in crop land. KMOG attempts to avoid or minimize the impact to agriculture which is important to Weld County 40.177567 -104.982802 x x x x AL34 SESE Sec.34 3N 68W -This AL is within 2,640' of 20 RBUs -This AL is within 2,640' of a School Facility -This AL upgradient of a mapped NWI riparian corridor Tail Water Ditch and and non-jurisdictional wetlands -This AL is within the floodplain -This AL is within HPH Native Aquatic Species Conservation Waters 40.158827 -104.954768 x x x AL12 NENW Sec.12 2N 68W -Located within 5,280' of 749 RBU, 16 HOBU School Facilities -This AL is within 5,280' of RBU, HOBU or School within DIC -KMOG is unable to fully develop the DSU from this AL, requiring a 2nd location. 304.b.(2).B.i-x Criteria Met: iv. WPS < 2,000 feet from jurisdictional boundary and PLG objects/requests ALA v. WPS within a Floodplain viii. WPS within HPH and CPW did not waive ix. Operator using Surface bond x. WPS < 1 mile from RBU/HOBU/School within a DIC 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 4 of 26Date Run: 1/21/2026 Doc [#404141703] 40.166165 -104.964090 x x AL2 NESE Sec. 2 2N 68W -This AL is within 2,640' of 534 RBUs and 19 HOBU -This AL upgradient of a mapped NWI riparian corridor -KMOG is unable to fully develop the DSU from this AL, requiring a 2nd location. -KMOG anticipates challenges negotiating SUA with Mining Operators. 40.180586 -105.007386 x x x x AL33 NWSE Sec. 33 3N 68W -This AL is within 2,640' of 56 RBUs & HOBU (School Facility) -Located upgradient from an NWI Mapped wetland -This AL is within 5,280' of RBU, HOBU or School within DIC -KMOG is unable to fully develop the DSU from this AL, requiring a 2nd location. 40.148310 -104.972268 x x x AL11 SESW Sec. 11 2N 68W -This AL is within 2,640' of 470 RBUs and 9 HOBU -This AL upgradient of a mapped NWI wetland 128' east -This AL is within 5,280' of RBU, HOBU or School within DIC -KMOG is unable to fully develop the DSU from this AL, requiring a 2nd location. SURFACE & MINERAL OWNERSHIP Name:Tharaldson Motels II Inc Phone:303-346-7006 303-468-6705 Fax:8678 Concord Center Drive Address: Address:Suite 200 Email:bhoran@ventanacap.com City:Englewood State:CO Zip:80012 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 Page 5 of 26Date Run: 1/21/2026 Doc [#404141703] 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:N/A 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 12 Drilling Pits 0 Pump Jacks 12 Gas or Diesel Motors 0 Dehydrator Units 0 Oil Tanks 0 Production Pits 0 Separators 2 Electric Motors 0 Vapor Recovery Unit 0 Condensate Tanks 1 Special Purpose Pits 0 Injection Pumps 0 Electric Generators 0 VOC Combustor 0 Water Tanks 4 Multi-Well Pits 0 Heater-Treaters 0 Fuel Tanks 0 Flare 0 Buried Produced Water Vaults 0 Modular Large Volume Tank 1 Gas Compressors 0 LACT Unit 2 Enclosed Combustion Devices 1 Pigging Station 0Meter/Sales Building 2 Vapor Recovery Towers 0 OTHER PERMANENT EQUIPMENT Permanent Equipment Type Number GAS COOLER 1 AIR COMPRESSORS 2 COMMUNICATION TOWERS 1 E-HOUSES 2 ELECTRICAL BOXES 3 MULTI PHASE FLOW METER 1 WELL MANIFOLD 12 FG SCRUBBER 1 GAS SCRUBBER 1 OIL COOLER 1 CHEMICAL TOTES 6 OTHER TEMPORARY EQUIPMENT Temporary Equipment Type Number PURGE FLARES 3 ENCLOSED COBUSTION DEVICES 5 WATER TANKS 22 WATER COOLERS 2 OIL SKIM PUMP 1 GENERATOR 1 VAPOR RECOVERY UNIT 1 PROPANE TANKS 1 MULTI PHASE COOLERS 2 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 Page 6 of 26Date Run: 1/21/2026 Doc [#404141703] FLOWLINE DESCRIPTION Per Rule 304.b.(6), provide a description of all onsite and off-location oil, gas, and/or water flowlines. Flowlines - 2-3" size (outside diameter), constructed of carbon steel. Oil and gas pipelines will be used at this location. Water for completion operations will be brought to the location through temporary water lines using KMOG's Water on Demand system. The oil and gas pipelines will be constructed by a 3rd party midstream company. Provide the distance and direction to the nearest cultural feature as measured from the edge of the Working Pad Surface. Building:1108 Feet Designated Outside Activity Area:5280 Feet Public Road:345 Feet Above Ground Utility:599 Feet Railroad:5280 Feet Property Line:159 Feet CULTURAL DISTANCE AND DIRECTION Distance SW W E SE W SE Direction School Facility:2433 Feet Child Care Center:5280 Feet NW E Rule 604.b Conditions Satisfied (check all that apply): 604.b. (1)Details of Condition(s) Disproportionately Impacted (DI) Community: 1072 Feet S 604.b. (2) 604.b. (3) 604.b. (4) Residential Building Unit (RBU):2277 Feet NE High Occupancy Building Unit(HOBU)2433 Feet NW SWFeet4170RBU, HOBU, or School Facility within a DI Community. RULE 604.a.(2). EXCEPTION LOCATION REQUEST 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 0 0-500 feet 0 0 0 0 0 0 501-1,000 feet 0 0 0 0 0 0 1,001-2,000 feet Page 7 of 26Date Run: 1/21/2026 Doc [#404141703] Drilling Fluids Disposal: DRILLING WASTE MANAGEMENT PROGRAM OFFSITE Centralized E&P WMFDrilling Fluids Disposal Method: Cutting Disposal:OFFSITE Commercial DisposalCuttings Disposal Method: Other Disposal Description: Please see attached Waste Management Plan Beneficial reuse or land application plan submitted?Yes Reuse Facility ID:or Document Number: Centralized E&P Waste Management Facility ID, if applicable:456644 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: 20.90Size of disturbed area during construction in acres: CONSTRUCTION 6.64 DRILLING PROGRAM Yes No Will oil based drilling fluids be used?Yes 4873 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). X Describe the current land use: Rangeland Describe the Relevant Local Government’s land use or zoning designation: RSF-4 Residential Single Family (4 dwelling units per acre) Describe any applicable Federal land use designation: N/A 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). X FINAL LAND USE REFERENCE AREA INFORMATION Page 8 of 26Date Run: 1/21/2026 Doc [#404141703] 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): Rangeland 40.177050 -104.984310Reference Area Latitude: Provide a list of plant communities and dominant vegetation found in the Reference Area. Plant Community Dominant vegetation Disturbed Grassland 1) Perennial ryegrass (Lolium perenne) Disturbed Grassland 2) Tall tumblemustard (Sisymbrium altissimum) Disturbed Grassland 3) Rubber rabbitbrush (Ericameria nauseosa) Noxious weeds present:Yes 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 ECMC website GIS Online map page. Instructions are provided within the ECMC website help section. NRCS Map Unit Name:15-Colby loam, 1 to 3 percent slopes NRCS Map Unit Name:59-Shingle loam, 3 to 9 percent slopes, 82-Wiley-Colby complex, 1 to 3 percent slopes NRCS Map Unit Name:61-Tassel fine sandy loam, 5 to 20 percent slopes,65-Thedalund loam, 3 to 9 percent slopes, GROUNDWATER AND WATER WELL INFORMATION Provide the distance and direction, as measured from the Working Pad Surface, to the nearest: water well:745 Feet N 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: Field Collected Data - depth of 3.2 ft. 3 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: Ditch Feet S0 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: Pad Surface:SEFeet541 Page 9 of 26Date Run: 1/21/2026 Doc [#404141703] 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 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. X When Rule 309.e.(2) Consultation must occur, check all that apply: This location is included in a Wildlife Mitigation Plan 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: 02/08/2023 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. 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. Page 10 of 26Date Run: 1/21/2026 Doc [#404141703] No Target Species BMP Type Description 1 BALD EAGLE Wildlife - Avoidance Construction activities (including access road but excluding the cutting of trees within the Location), Drilling and Completions Operations will be conducted outside the seasonal timing restriction for the Bald Eagle Winter Night Roost High Priority Habitat (November 15th – March 15th). 2 BALD EAGLE Wildlife - Minimization The Operator will install 760 linear feet of 32-foot tall engineered STC32 sound walls on the southwest and southeast sides of the location Operator Proposed Wildlife BMPs 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. 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): < No row provided > 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? N/A Is a Compensatory Mitigation Fee proposed for this Oil and Gas Location? Direct impact habitat mitigation fee amount: $ No No No No 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? N/A 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? Page 11 of 26Date Run: 1/21/2026 Doc [#404141703] 3 BURROWING OWL Wildlife - Minimization To minimize impacts to BUOW, three rounds of surveys for burrowing owls at all suitable habitat locations will be conducted within 0.25-mile of the Location in accordance with CPW protocol if construction is planned between March 15 –October 31. If an active BUOW nest burrow is identified, KMOG will not start operations within 0.25-mile of the active nest burrow(s) and will consult with CPW for approval on next steps and necessary documentation. No Target Species BMP Type Description 1 CPW Proposed Wildlife BMPs PLANS Total Plans Uploaded: 15 (1) Emergency Spill Response Program consistent with the requirements of Rules 411.a.(4).B, 411.b.(5).B, & 602.j X (2) Noise Mitigation Plan consistent with the requirements of Rule 423.a (3) Light Mitigation Plan consistent with the requirements of Rule 424.aX (4) Odor Mitigation Plan consistent with the requirements of Rule 426.aX (5) Dust Mitigation Plan consistent with the requirements of Rule 427.aX For this Location, are pre-production operations planned between May 1 to September 30 time period? Ozone Nonattainment Area & Enhanced Systems and Practices Yes Yes Is this proposed Location within the Ozone Nonattainment Area? If this Location is proposed within the Ozone Nonattainment Area, select which of the below Enhanced Systems & Practices (ESPs) will be implemented at the Location. Will this ESP be implemented? Yes 316.c.(4).A.i: The Operator will not store hydrocarbon liquids in permanent storage tanks on site (other than a maintenance tank possibly used for Well unloading or other maintenance activities). Yes 316.c.(4).A.ii: The Operator will have adequate and committed pipeline takeaway capacity for all produced oil. Yes 316.c.(4).A.iii: The Operator will use pipelines (e.g., lay-flat hose) to transport water used for hydraulic fracturing to the Location. Yes 316.c.(4).A.iv: If centrifugal compressors are used on the Location, they will be equipped with dry seals. Yes 316.c.(4).C.i: The Operator will use grid power or onsite solar power for all permanent powered production equipment onsite, excluding external combustion sources. No 316.c.(4).C.ii: All drill rig engines and/or turbines with a manufacturer’s design rate greater than or equal to 50 horsepower will be powered by grid power or non-fossil fuel generated power. No 316.c.(4).C.iii: The Operator will not store produced water in permanent storage tanks on site (excluding normally empty maintenance tanks and tanks utilized in produced water recycling/reuse) for new Oil and Gas Locations. If any ESPs were selected as “NO”, an attachment explaining the practicability of the ESPs MUST be attached. OPERATOR BMPs & ESPs Page 12 of 26Date Run: 1/21/2026 Doc [#404141703] 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 (17) Wildlife Plan consistent with the requirements of Rule 1201 X (18) Water Plan X (19) Community Outreach Plan (20) 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 ECMC Rule or Commission Order number:NO ALL exceptions and variances require attached Request Letter(s). Refer to applicable rule for additional required attachments (e.g. waivers, certifications, SUAs). Page 13 of 26Date Run: 1/21/2026 Doc [#404141703] 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 304.c.(2). Noise Mitigation Plan 304.c.(3). Light Mitigation Plan 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). Community Outreach Plan 304.c.(20). Geologic Hazard Plan Comments OPERATOR COMMENTS AND SUBMITTAL Page 14 of 26Date Run: 1/21/2026 Doc [#404141703] A Town of Mead Special Use Permit (SUP) will be submitted in association with this Midwest pad. There are three structures near the proposed Midwest Location that are owned by Tharaldson Motels II Inc. (the Surface Owner). Structure 1 is an abandoned RBU that has been vacant for over 60 years and is considered uninhabitable. Structure 2 is a barn from the same era that is considered a Building. Structure 3 is a mobile home or trailer, used temporarily before and after hunting. Based on OGLA Staff guidance we are not identifying any of these as RBUs. The attached EAP will be submitted to the Mountain View Fire Protection District. Once the plan is approved a signed copy will be sent to the ECMC OGLA staff. A site-specific Air Monitoring Plan for this location will be submitted to the CDPHE for approval of air monitor locations prior to operations. Flowlines: Flow lines will flow to the production facility location. During production, flow direction in the flow lines is from the wellhead to the production facility. Flow lines will be constructed from steel pipes, buried, and will equal the distance between the well heads and the production facility. Gas lift lines are also occasionally installed (one per well) from the well head to the production facility. During operation flow direction in the gas lift lines will be from the production facility to the well head. The size of the gas lift lines is typically 2''. Gas lift lines will be constructed from steel pipes, buried, and will equal the distance between the well heads and the tank battery. Gas custody transfer will occur at the custody transfer meter located on the proposed production facility location. Oil custody transfer will occur at the LACT Unit located on the proposed production facility location. Air Supply Lines: Compressed air supply lines will also be installed from the well head to the production facility. During operation flow direction in the supply lines will be from the production facility to the well head. The size of the supply lines is typically 1''. Supply lines will be constructed from steel pipe, buried, and will equal the distance between the well heads and the production facility. There will be 22 temporary 500-barrel skid-mounted frac tanks will be utilized during flowback and initially for produced water. It is estimated there are 5 temporary ECDs and the temporary tanks will be on location for 9 - 12 months and will be removed as water production declines. A temporary generator may be placed on location if needed and would be in place until electric power is available. Temporary purge flares may be placed on location for up to 60 days. A temporary 500-gallon propane tank will be used on location to provide fuel gas during facility equipment startup. The Location is considered within a sensitive area for water resources because there are surface waters of the state nearby and shallow groundwater. KMOG is proposing one temporary MLVT up to 25,000 bbl - 36 feet tall and 70 feet diameter. The vendor of the MLVT is Shalestone and will be utilized for completion operations at the Well Location. This MLVT is more than 2,000 feet from the nearest RBU. KMOG acknowledges the ECMC MLVT Policy and will adhere to that policy. A non-redacted version of the Confidential Water Plan was emailed to John Noto on 5/21/2025. The location is in Bald Eagle Winter Night Roost, which is a Rule 309.e.1 consultation trigger. KMOG has had informal consultations with CPW on multiple occasions regarding this pad and will commit to not performing major operations between November 15 and March 15. Please send both questions and comments to both rachel_friedman@oxy.com and djregulatory@oxy.com. Page 15 of 26Date Run: 1/21/2026 Doc [#404141703] djregulatory@oxy.com Geological Advisor 05/30/2025 Rachel Friedman ECMC Approved:Director of ECMC Date:1/21/2026 Based on the information provided herein, this Oil and Gas Location Assessment complies with ECMC 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. 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. CONDITIONS OF APPROVAL, IF ANY LIST COA Type Description Drilling/Completion Operations COA from Commission Hearing: The operator will comply with Rule 316.c.(4).C.ii, Specifically All drill rig engines and/or turbines with a manufacturer’s design rate greater than or equal to 50 horsepower will be powered by grid power or non-fossil fuel generated power. Planning COAs from Commission Hearing: •Pad construction will be conducted from June 1, 2026 to August 30, 2026. •The production facility construction will occur between June 1, 2026 – August 30, 2026 or during drilling and completions operations. •Ditch construction is not covered under this timing restriction. •Drilling and completions will be conducted from April 1, 2027 through September 30, 2027. However, the operator will make best efforts to complete drilling and completion operations by September 9, 2027. •If the ground conditions do not allow the operator to comply with these timing stipulations regarding pad construction and production facility construction, the operator may file a Form 4 Sundry to request a deviation from the timing stipulations stated here. •The Form 4 Sundry can be elevated to the full Commission if it proposes a “significant change” that requires Commission approval pursuant to Rule 301.c., in which case the Form 4 will be scheduled for consideration by the Commission at the earliest possible hearing. •The operator will report monthly from April through mid-August on a report generated to the Director and delivered to the Commission regarding progress and compliance with the timing stipulations regarding pad construction, production facility construction, and drilling and completion operations. Planning Within 6 months of the construction of the Working Pad Surface, operator will submit a survey via Form 4 Sundry that measures the distance between the Working Pad Surface and both the nearest school property line and the nearest proposed or existing school building. 3 COAs Page 16 of 26Date Run: 1/21/2026 Doc [#404141703] No BMP/COA Type Description 1 Community Outreach and Notification Community Outreach Plan BMPs Air Quality and Climate ? We have eliminated oil tanks at the Midwest Location, the largest source of emissions from oil and gas locations. ? From the Integrated Operations Center (IOC), our personnel can turn wells and equipment on and off, measure tank levels, and verify pressures and temperatures, which reduces truck traffic to the location and, therefore, emissions. ? We will use BMPs to reduce unloading events and to reduce emissions when liquids unloading is necessary (i.e., maintenance activities to remove liquids from existing wells that are inhibiting production). ? Production facilities are inspected regularly by our staff to make sure the equipment is working properly and necessary maintenance is performed. ? We will plug and abandon 5 wells and remove 3 facilities. This will eliminate 240 truck trips annually in the area along with 1.09 TPY NOx, 3.6 TPY VOC, 1 TPY CO, and 0.05 TPY Benzene. ? The Midwest location will use an electric drilling rig and completions technology as set forth in AQCC Regulation No. 7 Part B.VI.E.1. ? We have the lowest emissions inventory intensity of any oil and gas operator in the DJ Basin and have already met the 2030 CDPHE Regulation 22 target. As seen in the chart below, since 2020, we've collected over 11,500 samples, and all are well below the CDPHE Health Guidance Values of 9 parts per billion (ppb). 2 Traffic control A. Water-on-Demand (WOD) - Water for completion operations will be secured by KMOG through its own “Water-on-Demand” (WOD) system, or from a water supplier in the immediate area of the drill site. This WOD system is a network of over 180 miles of underground pipeline that stretches the length of the 20-mile by 30-mile field to source and transport water to completions crews. This system eliminates more than 2,000 truck trips per day field-wide, while also reducing associated impacts of traffic, noise, emissions, and dust. KMOG anticipates this location will have approximately 115,300 truck trips eliminated during the completions process by using the WOD system. B. Reduced Facility Size - KMOG works hard to reduce the facility size and create compact development areas. KMOG’s production facilities are designed and constructed to eliminate oil storage tanks, and the associated emissions and traffic associated with trucking oil. KMOG intends to utilize a comprehensive below ground oil and gas pipeline system to transport produced oil and gas to central processing facilities, resulting in a smaller production facility with fewer tanks. This pipeline infrastructure mitigates truck traffic in the area, thereby significantly reducing impacts to roads, noise, and emissions. C. Remote monitoring reduces traffic - all new well sites are remotely monitored 24 hours a day, seven day a week by representatives in KMOG’s Integrated Operations Center (IOC). This monitoring also helps reduce traffic to well sites. From the IOC, KMOG personnel can turn wells and equipment on and off, measure at tank levels, verify pressures and temperatures. This remote monitoring reduces daily traffic to the location. 3 General Housekeeping CDHPE Consultation BMPs • Operator will make reasonable efforts to minimize heavy haul traffic and deliveries during school pick up and drop off times. • Operator will use Modular Large Volume Storage Tanks • Operator will reduce the use of natural gas burners for production equipment (e.g. heaters, separation, etc.) when possible, excluding ECDs • Operator will provide access and/or siting locations for air monitoring equipment at the request of CDPHE or ECMC • Operator will collaborate with CDPHE/ECMC to assist in identifying potential sources of emission events observed by CDPHE or ECMC monitoring equipment (e.g. provide event summaries onsite during observed emissions, meet with Agency staff, provide requested additional information timely, etc.) • Operator will properly maintain vehicles and equipment • Operator will employ service providers whose nonroad construction equipment fleets have engines with emission ratings of at least EPA Tier 4 Final Non-Genset or equivalent (e.g. EPA Natural Gas Spark-Ignited Tier 2) • On forecasted high ozone days: operator will, as practicable, postpone construction Operator Best Management Practices Page 17 of 26Date Run: 1/21/2026 Doc [#404141703] activities • Operator will maintain a publicly accessible digital information source (e.g. webpage, social media) with information about this application including a primary contact method to address complaints and concerns • Operator will maintain a publicly accessible digital information source (e.g. webpage, social media) with information about this application including notices of Venting as described in Rule 903(d)(1)(B) and (E), at the time such notice of Venting is required to be made to ECMC • Operator will maintain a publicly accessible digital information source (e.g. webpage, social media) with information about this application, including maps of pads, facilities, and truck routes (e.g. materials presented to the ECMC during OGDP approval hearing and/or referenced in Director’s Recommendations) • The Operator will hold a virtual information session or post a video in both Spanish, English, and any language deemed necessary on its website, no sooner than 30 days after approval of this application and before commencement of drilling. The virtual session or video will be open to residents of the areas surrounding the Location(s) and will provide an overview of the timing and potential impacts during the project's pre- production and production phases, following ECMC's best practices for engagement and outreach. 4 Wildlife The following site-specific wildlife BMPs will be implemented at the Location: 1. The well site will be remotely monitored 24 hours a day, seven days a week by representatives in KMOG’s Integrated Operations Center (IOC). 2. Ditch and berm shall be installed around the perimeter of the location, and subsequently around all topsoil stockpiles, to intercept and divert stormwater run- on/run-off and sediment from precipitation and melt events. 3. Water for completions will be piped to location via the Water-on-Demand pipeline system. 4. Weed control will occur seasonally and as needed to hinder the spread of weeds throughout the topsoil stockpile(s) and help native grass establishment. 5. Install screening or other devices on the stacks and on other openings of heater treaters or fired vessels to prevent entry by migratory birds. 6. Chemical storage and diesel tanks/refueling bays shall be contained in secondary containment. 5 Wildlife Tree Removal on Location Activity at the Location will be limited to 1000 to 1400 daily per guidance provided by CPW, to minimize disturbances during high raptor activity/foraging times (CPW 2020). o Phase 1 – All the trees within the Location will be cut down. Activity during this stage will be 7 days per week from 1000 to 1400 daily. o Phase 2 – Clean-up of the cut down trees, including chipping and hauling off site. Activity during this stage will be 5 to 7 days per week from 1000 to 1400 daily. o Severe weather during either Phase, KMOG will cease operations until weather improves. Cutting down the trees (Phase 1) will be completed by the beginning of red-tailed hawk nesting season on 2/15. It is possible that tree clean up (Phase 2) may extend beyond 2/15. KMOG will consult with CPW prior to any activity after 2/15. Raptor surveys will be conducted as follows: o Approximately 7 days prior to the start of tree removal, a raptor survey will be conducted. Results of the survey will be sent to CPW o Phase 1 operations - Raptor surveys will be conducted every other day, alternating between dusk and dawn surveys. KMOG will consult with CPW if there is bald eagle roosting or nesting activity in the trees within the Location. o Phase 2 operations - Raptor surveys will be conducted twice per week with one survey at dusk and the other at dawn. KMOG will consult with CPW if there is bald eagle roosting or nesting activity in the trees within the Location. 6 Storm Water/Erosion Control 11.1 Stormwater will be managed during construction by a combination of site-specific erosion and sediment control measures including: 11.1.1 Delineation of limits of construction to establish a workspace. 11.1.2 A Vehicle Tracking Control (VTC) placed along the northern portion of the access road to the well pad and production facility pad to mitigate off-site sediment migration from vehicle traffic onto Weld County Road 28, approximately 0.75 miles Page 18 of 26Date Run: 1/21/2026 Doc [#404141703] north of the well pad and production facility pad. 11.1.3 A Diversion ditch (DD) around the entire location to manage run-on and run-off. A secondary diversion ditch will be installed along the perimeter of the production facility pad and well pad, and a berm around the eastern and southern perimeter of the topsoil stockpile to divert stormwater run-off to a designated outfall structure. 11.1.4 Temporary Spillways and Outlet (SW/O) structures placed in the southwestern portion of the disturbance area ditch and berm, which will allow for settling of sediment from stormwater prior to discharge. 11.1.5 Approximately 2 Culverts (C) with inlet and outlet protection will be installed in the primary well pad and production facility pad access points to direct stormwater to designated discharge structures. 11.1.6 Seed & Mulch (SM) to stabilize areas no longer needed for construction, as well as for topsoil stockpiles which will remain in place until interim and final reclamation. 11.1.7 During active construction, daily inspections will be completed by on-site personnel. A contractor will conduct stormwater compliance inspections every 14-days and/or following a rain event which produces 0.25” of precipitation or equivalent snow melt which causes surface erosion. Inspections will review all control measures / BMPs implemented, their status, and whether repair or replacement is needed. 11.1.8 Maintenance and repair will be completed as soon as practicable, immediately in most cases. 7 Material Handling and Spill Prevention Waste Management Plan BMPs a. Site specific details of each phase of operation are presented in the attached site- specific Table 1. Waste type, storage container, disposal facility, volumes, frequency, waste characterization, potential hazards, Resource Conservation and Recovery (RCRA) exemption status are included in the table. b. Wastes will be stored in containers or on lined containment that are chosen for compatibility and checked periodically for leaks or integrity problems. Examples of containment include but are not limited to 3-sided steel tanks, steel tanks, lined containment, plastic totes, drums, etc. c. All specific wastes in the attached site-specific Table 1 will have a detailed Safety Data Sheet available which includes information such as the properties of the wastes; the physical, health, and environmental health hazards; protective measures; and safety precautions for handling, storing, and transporting the chemical. d. The proper personal protective equipment will always be worn when handling waste. Employees will refer to the Safety Data Sheet for additional information. e. Good housekeeping measures for trash included closed receptacles designed to exclude potential wildlife and prevent overflowing. f. During drilling, completions, and facility construction, human waste and septic from temporary buildings will be stored in tanks. These tanks will be emptied via vacuum truck for disposal. Temporary portable restrooms will also be available for workers during this phase. Good housekeeping measures for these include regular servicing and inspections. Temporary portable restrooms will be staked to the ground to prevent from tipping over. g. Waste will be segregated and stored according to its waste type. h. When feasible, wastes will be recycled, re-used, or treated onsite. As a BMP, fluids are generally reused from location to location if possible. No onsite treatment or recycling is planned onsite for this location. In the event that onsite treatment or recycling is feasible, a written management plan will be submitted to the ECMC Director for approval on a Form 4. i. All waste streams will be transported off location for recycling or disposal in a timely manner in accordance with local, state, and federal regulations. j. During drilling, completion, and facility constructions, inspection of trash receptacles, sewage tanks, temporary restrooms, waste and material storage areas are performed by a third party and documented during regular stormwater inspections. k. All spills or leaks will be cleaned up upon discovery in accordance with local, state, and federal testing and cleanup standards. All waste generated from the cleanup process will be profiled, as required by local, state, and federal regulations, for recycling or disposal. Manifests will be used to track all waste generated. 8 Material Handling and Spill Prevention Fluid Leak Detection Plan BMPs Part 1 Drilling Operations Best Management Practices (BMPs) a. Two drilling crew members required and dedicated for all fluid transfers (no exceptions) from start to finish of the operation. Their sole focus is on the transfer. No fluid transfer will occur during crew change. Crew members conducting the fluid transfer will not leave the area until transfer operations completed. Page 19 of 26Date Run: 1/21/2026 Doc [#404141703] b. Tanks (along with auxiliary equipment installed in tanks) will be inspected prior to use and replaced/repaired if damaged. c. During rig up, hoses and lines will be properly assembled, all bolts properly made up and gaskets installed (when applicable). d. Appropriate secondary containment will be utilized when equipment maintenance is conducted on location. e. Contractors will maintain an updated copy of their Spill Prevention and Control and Countermeasures (SPCC) plan on location and its personnel will be trained accordingly. f. Tanks will be labeled (signs, magnets, etc.) indicating the contents of the tank. g. Verify tank capacity is capable of handling estimated volumes prior to operations start. h. Tanks will have hatches, valves and bull plugs secured prior to transfers. i. Shut down transfer pump and close supply valve when transfer or circulation is completed. Ensure fluids cannot enter holding tank through gravity feedback. j. Pre-job inspection will be conducted prior to start up which include the visual inspection of hoses, lines, and valves to ensure proper connection and alignment. k. During operations, all fluid containing equipment is inspected daily. l. Walk all lines and confirm valve alignment before starting the transfer. m. Walk the lines as soon as the transfer starts to confirm no leaks. n. All personnel on location on behalf of Kerr-McGee Oil & Gas Onshore LP (KMOG) are trained in Auditory, Visual, Olfactory monitoring (AVO) techniques. All personnel are empowered with ‘Stop Work Authority’ and to report any leaks immediately. Completion Operations Best Management Practices a. Two completion crew members required and dedicated for all fluid transfers (no exceptions) from start to finish of the operation. Their sole focus is on the transfer. No fluid transfer will occur during crew change. Crew members conducting the fluid transfer will not leave the area until transfer operations completed. b. Tanks (along with auxiliary equipment installed in tanks) will be inspected prior to use and replaced/repaired if damaged. c. Appropriate secondary containment will be utilized when equipment maintenance is conducted on location. d. Contractors will maintain an updated copy of their SPCC plan on location and its personnel will be trained accordingly. e. Tanks will be labeled (signs, magnets, etc.) indicating the contents of the tank. f. Verify tank capacity is capable of handling estimated volumes prior to operations start. g. Tanks will have hatches, valves and bull plugs secured prior to transfers. h. Shut down transfer pump and close supply valve when transfer or circulation is completed. Ensure fluids cannot enter holding tank through gravity feedback. i. Pre-job inspection will be conducted prior to start up which include the visual inspection of hoses, lines, and valves to ensure proper connection and alignment. j. During operations, all fluid containing equipment is inspected daily. k. Walk all lines and confirm valve alignment before starting the transfer. l. Walk the lines as soon as the transfer starts to confirm no leaks. m. Temporary produced water storage tanks will be designed, constructed, and maintained in accordance with the following portions of the National Fire Protection Association (NFPA) Code 30 (2008 version): o Tanks are built to engineering standards using noncombustible materials, with relief device sizing based on API 2000 standards. o Tanks are inspected and maintained while in use. o The only pipes within the containment are related to the temporary tanks (i.e., no external piping is co-located within the containment), and firefighting equipment is, likewise, not stored within the containment area. n. The temporary produced water storage tanks will be staged on a geosynthetic liner and surrounded by an earthen berm. The berms will enclose an area sufficient to provide secondary containment for 150% of the volume of the largest single tank and will be sufficiently impervious to contain spilled or released material. Berms and the liner and all secondary containment devices will be inspected at the same time as stormwater inspections, with personnel on location, daily inspections will occur. During non-active, but while under construction, site inspections will occur every 14 days. When construction is completed and the location is on production, site inspections will occur every 28 days at a minimum. o. Monitor pressure responses and containment to identify potential leaks. Lines will be Page 20 of 26Date Run: 1/21/2026 Doc [#404141703] walked continuously throughout operations (between stages) to identify potential leaks. p. There is a slam valve and control valve with Emergency Shut Down system in line to the external temp tanks to prevent overflowing tanks during the green flowback duration. q. Hourly walk-throughs and pressure measurements recorded during flowback operations for leak detection. r. During operations, all fluid containing equipment is inspected daily. s. All personnel on location on behalf of KMOG are trained in AVO techniques. All personnel are empowered with ‘Stop Work Authority’ and to report any leaks immediately 9 Material Handling and Spill Prevention Fluid Leak Detection Plan BMPs Part 2 Production Operations Best Management Practices a. Berm Construction: A geosynthetic liner will be laid under the permanent tanks on this location and a metal containment will be constructed. Secondary containment devices will be constructed around crude oil, condensate, and produced water storage tanks and will enclose an area sufficient to contain and provide secondary containment for 150% of the largest single tank. Secondary containment devices will be inspected at the same time as stormwater inspections, with personnel on location, daily inspections will occur. During non-active, but while under construction, site inspections will occur every 14 days. When construction is completed and the Location is on production, site inspections will occur every 28 days. b. Automation technology will be utilized at this facility. This technology includes the use of fluid level monitoring for the tanks and produced water sumps, high-level shut offs, and electronic sensors to monitor the interstitial space of double-walled produced water sumps. All automation is monitored by KMOG’s Integrated Operations Center (IOC), which is manned 24 hours per day, seven days per week. c. Field Inspections include the following: Field-Constructed Above Ground Containers; Secondary Containment Structures; Shop-Built Containers; Generators / Fuel Tanks and associated secondary containment; Pressure Vessels (separators, heater treaters, pigging stations); Portable Containers and all Manifolded Piping; Onsite and Offsite Pipelines (flowlines, production piping, gathering lines) Field Drainage Systems (oil traps, sumps, or skimmers); and Additional equipment used during separation, storage, containment, or transferring of produced fluids. d. All personnel on location on behalf of KMOG are trained in AVO techniques. All personnel are empowered with ‘Stop Work Authority’ and to report any leaks immediately. e. KMOG complies with Colorado Energy & Carbon Management Commission (ECMC) Rule 609. f. For pressure vessels, KMOG will adhere to API standard 510. With an additional pre-installation inspection of all vessels. g. For tanks, KMOG will adhere to API standard 653 & 12R1. With an additional pre- installation inspection of all tanks. h. After the first year, KMOG will pressure test flowlines annually. 10 Material Handling and Spill Prevention During drilling operations KMOG will place a liner along the well row beneath the drilling sub. Liquid chemical totes and barrels will be stored on a secondary containment skid. Dry chemicals will be stored in conex boxes. During completions operations KMOG will place a secondary containment liner beneath hydraulic fracturing horsepower, chemical storage areas, and fuel storage areas. During flowback operations flowback equipment is surrounded by a berm and placed on a liner 11 Construction Light Plan BMPs Construction Phase: • During construction of all phases, KMOG will only conduct day light operation and there will be no nighttime operations that require lighting. • Exterior lighting shall be directed away from residential and other sensitive areas or shielded from said areas to eliminate glare. Light spillage beyond the perimeter of the well site shall be minimized. • Bulbs shall be fully shielded to prevent light emissions above a horizontal plane drawn from the bottom of each fixture. • Figure 4.1 on page 7 shows an abandoned RBU (residential building unit) that will not be considered a receptor in the Midwest Pad Lighting Mitigation Plan. Page 21 of 26Date Run: 1/21/2026 Doc [#404141703] • Prior to commencement of drilling and completion activities, a partial-perimeter, engineered sound wall consisting of approximately 760 linear feet of 32-foot-tall, STC32 wall will be installed on the southeast and southwest edges of the well pad to reduce noise levels at the critical receptor points. Drilling Phase: • KMOG will utilize LED fixtures to reduce skyglow. • KMOG will position all lights to point in a downward direction where vertical lighting is not required. Where it is required, lights are angled in a vertical direction to provide task lighting for safety and operations involving personnel. • Derrick mast lighting in Section 6.1 is facing horizontally to provide adequate lighting for safe operation. • Lighting is angled to mitigate the amount of light leaving the location boundary, and away from surrounding off site buildings. • Lighting within the Drilling area has been reduced to provide a minimum acceptable value for safe operation. • Light masts are automatically switched off/on based on lighting sensors. • Lights are switched off when not required. • Low power (63 W) LED lights are used for the drill rig. • In the event of a lighting complaint, KMOG will address the complaint and work with all parties involved to ensure the complaint is resolved. • Figure 4.1 on page 7 shows an abandoned RBU (residential building unit) that will not be considered a receptor in the Midwest Pad Lighting Mitigation Plan. Completions and Flowback Phases: • KMOG will utilize LED fixtures to reduce skyglow. • KMOG will position all lights to point in a downward direction where vertical lighting is not required. Where it is required, lights are angled in a vertical direction to provide task lighting for safety and operations involving personnel. • Lighting is angled to mitigate the amount of light leaving the location boundary, and away from surrounding off site buildings. • Lighting within the Completion and Flowback areas have been reduced to provide a minimum acceptable value for safe operation. • Light masts are automatically switched off/on based on lighting sensors. • Lights are switched off when not required. • Lights are directed to task areas only. • In the event of a lighting complaint, KMOG will address the complaint and work with all parties involved to ensure the complaint is resolved. • Figure 4.1 on page 7 shows an abandoned RBU (residential building unit) that will not be considered a receptor in the Midwest Pad Lighting Mitigation Plan. Production Phase: • KMOG will utilize LED fixtures to reduce skyglow. • KMOG will position all lights to point in a downward direction, in order to mitigate light leaving the location boundary. • Lighting within the Production areas have been reduced to provide a minimum acceptable value for safe operation. • In the event of a lighting complaint, KMOG will address the complaint and work with all parties involved to ensure the complaint is resolved. Page 22 of 26Date Run: 1/21/2026 Doc [#404141703] 12 Noise mitigation • KMOG conducted a Noise Impact Assessment (NIA) for each phase of operations (drilling, completions, and production) to assess operational noise levels against the maximum permissible dBA and dBC noise levels stated in both the Colorado ECMC Rule 423 and the Town of Mead Section 10-13 noise regulations. Each phase of operation will comply with the MPNLs of both codes as summarized in Table 1 (for ECMC compliance) and Table 3 (for Town of Mead compliance) in Section 2 of this document. • Prior to commencement of drilling and completion activities, a partial-perimeter, engineered sound wall consisting of approximately 760 linear feet of 32-foot-tall, STC32 wall will be installed on the southeast and southwest edges of the well pad to reduce noise levels at the critical receptor points. • KMOG will utilize a low noise completions fleet for all completions operations. • Flowback operations and equipment were reviewed as part of this Noise Mitigation Plan (NMP). Flowback utilizes a fraction of similar, but smaller equipment compared to the three other operations studied. Perimeter sound walls will be left in place until drill out is complete and flows are initiated to appropriately manage noise levels for this operation. • A pre-operational ambient sound level survey was conducted at the one location outlined in Figure 3 of Section 7 to quantify pre-existing A- and C-weighted sound levels. • If the drilling rig or completions fleet is changed prior to commencement of operations, the mitigation measures employed will be equally or more protective. • KMOG will post contact information to receive and address noise complaints arising from pre-production operations around the clock, 24 hours, 7 days per week. Upon receipt of a complaint, either directly to KMOG, from the Colorado ECMC, or from town of Mead, a KMOG representative will contact the associated stakeholder within 48 hours of receipt. 13 Odor mitigation Best Management Practices used to manage odor during pre-production operations: A. All oil-based drilling fluids will be built using a Group III base oil with negligible aromatic content and PAH less than 0.001% so that it does not emit odor during all production drilling operations. B. The Group III base oil will be utilized in a closed loop drilling fluid system and eliminate odor at the shakers, transfer tank, active/reserve tanks, and cuttings in collection tanks and during transport. C. All drill cuttings are processed through centrifugal dryers to remove residual oil- based drilling fluid not removed by shale shakers. D. All tubulars pulled out of the hole will be wiped prior to being racked in the derrick or laid down. E. Cuttings storage time on location will be minimized prior to transport to local landfills. F. New drilling fluid will be built using transfer line outlets located below tank fluid level to minimize splashing/agitation. New fluid will only be built using Group III base oils. VIII. Best Management Practices used to manage odor during production operations: A. KMOG uses pipelines to transport hydrocarbons (oil & gas) from the production facility eliminating odors that could occur during truck loading. B. Production facilities are inspected regularly by KMOG to make sure the equipment is working property and necessary maintenance is performed, to reduce potential odors. KMOG incorporates Audio, Visual, Olfactory (AVO) observations at production facility inspections. C. KMOG will use Best Management Practices to reduce unloading events and to reduce potential odor causing emissions when liquids unloading is necessary (i.e., maintenance activities to remove liquids from existing wells that are inhibiting production). D. KMOG remotely monitors production facilities, this reduces traffic onto production facilities which may create odors from truck traffic. 14 Interim Reclamation Topsoil Protection Plan BMPs 6.1 Construction Phase ? Ditch and berm shall be installed around the perimeter of the location, and subsequently around all topsoil stockpiles, to intercept and divert stormwater run- on/run-off and sediment from precipitation and melt events. ? Track packing all topsoil stockpiles will occur to prevent erosion from stormwater and wind, as well as provide temporary stabilization. ? Seeding and crimped straw mulch will be applied to prevent erosion and soil loss Page 23 of 26Date Run: 1/21/2026 Doc [#404141703] from stormwater and wind. ? Vegetation establishment through seeding efforts will promote soil health and maintain carbon exchange. ? Weed control will occur seasonally and as needed to hinder the spread of weeds throughout the topsoil stockpile(s) and help native grass establishment. 6.2 Drilling Phase ? Ditch and berm shall be installed around the perimeter of the location, and subsequently around all topsoil stockpiles, to intercept and divert stormwater run- on/run-off and sediment from precipitation and melt events. ? Track packing all topsoil stockpiles will occur to prevent erosion from stormwater and wind, as well as provide temporary stabilization. ? Seeding and crimped straw mulch will be applied to prevent erosion and soil loss from stormwater and wind. ? Vegetation establishment through seeding efforts will promote soil health and maintain carbon exchange. ? Weed control will occur seasonally and as needed to hinder the spread of weeds throughout the topsoil stockpile(s) and help native grass establishment. 6.3 Production Phase ? Vegetation establishment through seeding efforts will promote soil health and maintain carbon exchange. ? Weed control will occur seasonally and as needed to hinder the spread of weeds throughout the topsoil stockpile(s) and help native grass establishment. 8.1. Topsoil will be managed during construction by a combination of site-specific erosion and sediment control measures including: 8.1.1. A temporary Diversion Ditch & Berm (DD) around the entire location to manage run-on and run-off. 8.1.2. Short term management of topsoil will include track packing to prevent wind and water erosion. 8.1.3. Long term management will include seeding with a native seed mix and crimping straw mulch for erosion control and water retention. 8.1.4. Vegetation establishment on stockpiles and weed control will reduce erosion as well as maintain microbial activity. 8.1.5. During the construction phase topsoil will be stockpiled ~25’ at its tallest with an average height of 10’ at a 4 to 1 slope along the eastern portion of the production facility pad to minimize erosion potential. 8.1.6. Topsoil managed during interim and production phases will be maintained with BMPs including seeding with a native seed mix and crimped straw mulch and weed monitoring / management. 8.1.7. Long-term topsoil stockpile will be placed along the eastern perimeter of the production facility pad ~25’ at its tallest with an average height of 10’ tall at a 4 to 1 slope to reduce erosion and maintain microbial activity for an extended time. 8.1.8. Inspections will review all control measures / BMPs implemented, their status, and whether repair, replacement, or addition is needed, including weed maintenance when necessary. Maintenance and repair will be completed as soon as practicable, immediately in most cases. Total: 14 comment(s) Page 24 of 26Date Run: 1/21/2026 Doc [#404141703] ATTACHMENT LIST Att Doc Num Name 2369538 LOCAL GOVERNMENT PERMIT 2369539 WILDLIFE PLAN 2369540 DIRECTOR'S RECOMMENDATION 404141703 FORM 2A SUBMITTED 404222461 LOCATION DRAWING 404222465 LOCATION PICTURES 404222480 WILDLIFE HABITAT DRAWING 404222484 PRELIMINARY PROCESS FLOW DIAGRAMS 404222487 HYDROLOGY MAP 404222488 ACCESS ROAD MAP 404222491 RELATED LOCATION AND FLOWLINE MAP 404222493 DIRECTIONAL WELL PLAT 404222500 GEOLOGIC HAZARD MAP 404222501 LOCATION AND WORKING PAD GIS SHP 404222505 OTHER 404222511 NRCS MAP UNIT DESC 404222517 SURFACE AGRMT/SURETY 404222537 CPW CONSULTATION 404222542 PRE-APPLICATION DIRECTOR MEETING SUMMARY 404336110 REFERENCE AREA MAP 404336111 REFERENCE AREA PICTURES 404336136 PRE-APPLICATION COMMUNITY MEETING SUMMARY 404345682 CULTURAL FEATURES MAP 404345694 ESP PRACTICABILITY SUMMARY 404345725 ALA DATASHEET 404346205 ALA NARRATIVE SUMMARY 404347021 DISPROPORTIONATELY IMPACTED COMMUNITY MAP 404347025 LAYOUT DRAWING 404401013 CUMULATIVE IMPACTS ANALYSIS Total Attach: 29 Files Page 25 of 26Date Run: 1/21/2026 Doc [#404141703] User Group Comment Comment Date OGLA OGDP ID# 491891 and this Form are approved by Commission Order Number 407-3804.01/20/2026 OGLA The Director has determined that the OGDP application, that this Form 2A is a component of, conditionally meets all requirements of Rule 306.a. The Director’s Recommendation has been attached to the Form 2A. 12/30/2025 OGLA Attached the local government permit and Wildlife Mitigation Plan. With operator's concurrence, checked that the location is in a Rule 309.e.(2). consultation habitat. 12/29/2025 OGLA Updated distance to RBU in DIC with information from operator. Updated status of local permit with information from operator. 12/22/2025 OGLA Added wildlife BMPs, BMPs from Transportation Plan, CDPHE Consultation BMPs.12/18/2025 CPW CPW submitted a Wildlife Consultation Summary to ECMC for review by them and any interested stakeholders. 12/18/2025 OGLA Comment provided to ECMC via email. The Weld County Oil and Gas Energy Department (OGED) submits the following comments: As a Proximate Local Government, Weld County appreciates the opportunity to comment on the Kerr McGee Oil & Gas Onshore LP’s (KMOG) Midwest Pad. The Location is within the municipal boundary of the Town of Mead, and Weld County has no jurisdiction over the land use for this development. Please note, there may be other Weld County permits needed for this development such as access permits, Right-of-Way Use permits, or over-sized transport permit, and we would request that KMOG continues to communicate with Weld County regarding any of these items that may need to be addressed. Weld County respects the land use authority of the Town of Mead, and have no additional comments or BMPs we would recommend. 10/31/2025 OGLA Public comment period extended from 30 to 45 days.10/24/2025 OGLA The Director has determined this OGDP application is complete. Form pushed to IN PROCESS. 10/22/2025 OGLA The Conditions of Approval (COA) and Best Management Practices (BMPs) on the Form 2A and the Final Order are the final enforceable permit conditions for this Oil and Gas Location. Any plan or attachment that contains information or language that is contrary to or less protective than ECMC rules or the COAs and BMPs on the Form 2A or Final Order does not relieve the operator from compliance with the applied COAs, BMPs or any ECMC rules. 10/22/2025 OGLA Updated Community Outreach Plan and Cumulative Impact Analysis with files provided by operator. 10/22/2025 OGLA Form returned to Draft to address issues noted on review sheet. Pulled BMPs from the plans onto the Form 2A. 08/27/2025 CPW-Wildlife - Minimization- BALD EAGLE Operator proposed the following BMP: The Operator will install 760 linear feet of 32-foot tall engineered STC32 sound walls on the southwest and southeast sides of the location CPW commented as follows: This BMP is designed to minimize the noise, light, odor and human activity impacts on park visitors and wildlife, rather than just Bald Eagles. Stamp Upon Approval Total: 13 comment(s) General Comments Page 26 of 26Date Run: 1/21/2026 Doc [#404141703]