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HomeMy WebLinkAboutALFALFA 8-20HZ - Other - Kerr McGee - 3/25/2024 (2)State 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 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: 403278400 09/13/2023 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. djregulatory@oxy.com (720) 9296564 ( ) 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 20010124 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 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 230900284 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 485787 SPROUT 8-20HZ Number:ALFALFA Name: LOCATION IDENTIFICATION 03/05/2027Expiration Date: Location ID:486291 OGDP ID:485787 Page 1 of 23Date Run: 3/19/2024 Doc [#403278400] 02/10/20231.3 Date of Measurement:GPS Quality Value: 4975667W 2N 20 Ground Elevation:Meridian:Township:SENE 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:40.124550 Longitude:-104.908943 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.” 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. Yes 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:10/09/2023 Current status or disposition of the Relevant Local Government permit application for this proposed Oil and Gas Location:Approved Status/disposition date:01/11/2024 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: Stephanie FrederickContact Name:Contact Phone:970-400-3581 Contact Email:sfrederick@weldgov.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 Municipality Firestone Todd Bjerkas 303-531-6276 tbjerkaas@firestoneco.g ov (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. Contact Name:Contact Phone: Contact Email:Field Office: Page 2 of 23Date Run: 3/19/2024 Doc [#403278400] Additional explanation of local and/or federal process: No 02/01/2023Date 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: 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 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. < No row provided > 304.b.(2).B.i-x Criteria Met: 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?No 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. WPS < 2,000 feet 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). SURFACE & MINERAL OWNERSHIP Surface Owner Info: Page 3 of 23Date Run: 3/19/2024 Doc [#403278400] Name:ANADARKO E&P ONSHORE LLC Phone:7209296000 Fax:1099 18th St. Address: Address:Suite 700 Email:thomas_crouch@oxy.com City:Denver State:CO Zip:80202 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 No N/A Wells Indicate the number and type of major equipment components planned for use on this Oil and Gas Location: SITE EQUIPMENT LIST 13 Drilling Pits 0 Pump Jacks 13 Gas or Diesel Motors 0 Dehydrator Units 0 Oil Tanks 0 Production Pits 0 Separators 7 Electric Motors 0 Vapor Recovery Unit 2 Condensate Tanks 0 Special Purpose Pits 0 Injection Pumps 0 Electric Generators 0 VOC Combustor 0 Water Tanks 0 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 1 Enclosed Combustion Devices 0 Pigging Station 0Meter/Sales Building 2 Vapor Recovery Towers 0 OTHER PERMANENT EQUIPMENT Permanent Equipment Type Number CHEMICAL TOTES 3 AIR COMPRESSORS 1 ELECTRICAL BOXES 2 Maintenance Pump 1 E HOUSES 1 Well manifold 15 FG SCRUBBERS 1 COMMUNICATION TOWERS 1 Oil Cooler 1 Water Pump 2 OTHER TEMPORARY EQUIPMENT Page 4 of 23Date Run: 3/19/2024 Doc [#403278400] Temporary Equipment Type Number PURGE FLARES 3 Sand Tank 4 PROPANE TANKS 1 GENERATOR 1 Sand Trap 3 ENCLOSED COMBUSTION DEVICES 1 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, gas and water pipelines will be used at this location. Water for completions operations will be brought to the location through temporary water lines using KMG's Water on Demand system. The oil and gas pipelines will be constructed by a 3rd party midstream company. 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:1340 Feet Designated Outside Activity Area:5280 Feet Public Road:2114 Feet Above Ground Utility:316 Feet Railroad:5280 Feet Property Line:25 Feet CULTURAL DISTANCE AND DIRECTION Distance N W N NE E S Direction School Facility:5280 Feet Child Care Center:5280 Feet SW NW 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):2005 Feet N High Occupancy Building Unit(HOBU)5280 Feet SW EFeet5280RBU, 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: 0-500 feet 501-1,000 feet 1,001-2,000 feet Page 5 of 23Date Run: 3/19/2024 Doc [#403278400] Building Units Residential Building Units High Occupancy Building Units School Properties School Facilities Designated Outside Activity Areas 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Drilling Fluids Disposal: DRILLING WASTE MANAGEMENT PROGRAM OFFSITE Commercial DisposalDrilling Fluids Disposal Method: Cutting Disposal:OFFSITE Commercial DisposalCuttings Disposal Method: Other Disposal Description: Please see attached Waste Management Plan Multiple E&P waste management facilities are used - they are outlined in the 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: 12.50Size of disturbed area during construction in acres: CONSTRUCTION 4.13 DRILLING PROGRAM Yes No Will oil based drilling fluids be used?Yes 4975 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: AGRICULTURE-DRYLAND CROP Describe the Relevant Local Government’s land use or zoning designation: AGRICULTURE Describe any applicable Federal land use designation: N/A Final Land Use: check all that apply per Rule 304.b.(9). FINAL LAND USE Page 6 of 23Date Run: 3/19/2024 Doc [#403278400] Other Residential RecreationForestry CommercialIndustrial Rangeland Conservation Reserve Program (CRP)Non-IrrigatedIrrigated Subdivided: Non-Crop Land: Crop Land:X 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 N/A Reference Area Latitude: Provide a list of plant communities and dominant vegetation found in the Reference Area. < No row provided > Noxious weeds present: 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:44-Olney loamy sand, 1 to 3 percent slopes NRCS Map Unit Name:72-Vona loamy sand, 0 to 3 percent slopes NRCS Map Unit Name:73 - Vona loamy sand 3 to 5 percent slopes & 70-Valent sand 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:610 Feet E Spring or Seep:5280 Feet N 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: existing well permit number 306439- SWL 6.9' Elevation 4960 4960 – 6.9 = 4953.1 4974-4953.1 = 20.9 21 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: Feet NW1800 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:WFeet511 Page 7 of 23Date Run: 3/19/2024 Doc [#403278400] DITCH 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. 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: A pre-application consultation with CPW, regarding this Oil and Gas Location, occurred on: 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 8 of 23Date Run: 3/19/2024 Doc [#403278400] No BMP Operator Proposed Wildlife BMPs No BMP CPW 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? AIR QUALITY MONITORING PROGRAM Will the Operator install and administer an air quality monitoring program at this Location?Yes Operator Proposed BMPs Page 9 of 23Date Run: 3/19/2024 Doc [#403278400] No BMP CDPHE Proposed COAs OR BMPs No BMP PLANS Total Plans Uploaded: 16 (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 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) Cumulative Impacts Plan (20) Community Outreach Plan X (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 Commission Order number: ALL exceptions and variances require attached Request Letter(s). Refer to applicable rule for additional required attachments (e.g. waivers, certifications, SUAs). Page 10 of 23Date Run: 3/19/2024 Doc [#403278400] 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). Cumulative Impacts Plan 304.c.(20). Community Outreach Plan 304.c.(21). Geologic Hazard Plan Comments OPERATOR COMMENTS AND SUBMITTAL Page 11 of 23Date Run: 3/19/2024 Doc [#403278400] rachel_friedman@oxy.com Geological Advisor 09/13/2023 Rachel Friedman COGCC Approved:Director of COGCC Date:3/19/2024 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. A Weld County 1041 WOGLA was submitted in association with this pad. This location is not proposed within 2,000 feet of a Residential Building Unit, High Occupancy Building Unit, or School Facility located within a Disproportionately Impacted Community, a Rule 304.c.(20) Community Outreach Plan is not required. KMOG's "Community Consultation Plan" attached as "Other" is intended to provide supplemental information regarding efforts on community outreach and communication. A signed EAP is included with this permit KMOG`s general Air Monitoring Plan has been approved by the CDPHE and is attached to the 2B. A site-specific Air Monitoring Plan for this location will be submitted to the ECMC and 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 pipe, buried, and will equal the distance between the well heads and the production facility. 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. 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 pipe, buried, and will equal the distance between the well heads and the tank battery. 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. KMOG is proposing one 25,000 BBL MVLT for this location – 36 feet tall with 70 foot diameter. The proposed manufacturer and vendor is Shalestone Resources. The MLVT is approximately 2,485 feet from the nearest RBU and is a temporary piece of equipment (on location for approximately 2 months). Please see additional mitigation measures in the BMP section. An attachment listed as "other" is included and outlines KMOG's best management practices that are either generally recommended by CDPHE or are not included in any of the attached plans. These are also on the Operator BMPs tab. 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. Best Management Practices No BMP/COA Type Description 1 Pre-Construction An environmental assessment will be conducted immediately prior to pad construction, drilling, and completion operations. ` 2 Traffic control KMOG will upgrade an existing access road off of WCR 18 to access the location for drilling, completions, and production operations, including maintenance of equipment. The road will be properly constructed and maintained to accommodate for emergency vehicle access. ` Page 12 of 23Date Run: 3/19/2024 Doc [#403278400] 3 General Housekeeping All loadlines shall be bullplugged or capped. ` 4 General Housekeeping 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. • Prior to commencement of drilling and completion activities, a partial perimeter, engineered sound wall consisting of approximately 900 linear feet of 32-foot-tall, STC32 wall will be installed around the northern half of the well pad to reduce noise levels at the critical receptor points. • 200 linear feet on west edge of the well pad • 500 linear feet on north edge of well pad • 200 linear feet on the east edge of well pad 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 lightning complaint, KMOG will address the complaint and work with all parties involved to ensure the complaint is resolved. 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 lightning complaint, KMOG will address the complaint and work with all parties Kerr McGee Oil & Gas Onshore LP Alfalfa 8-20 HZ Lighting Mitigation Plan Project Number: 21010-23 Rev. 1, MAY 17, 2023 PAGE 13 of 14 21010 Kerr McGee Alfalfa 8- 20 HZ Lighting Mitigation Plan Rev 1 involved to ensure the complaint is resolved. 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.` 5 General Housekeeping 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. 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.` 6 General Housekeeping Good housekeeping measures will be implemented to prevent sediment, trash and toxic or hazardous substances from entering surface waters or impacting soils. Housekeeping practices include routine inspections, regular cleaning, site and equipment organization and maintenance, and appropriate chemical storage. Dumpsters and trash receptacles will be enclosed and/or covered to prevent dissemination of rubbish when not in use.` 7 Wildlife Alfalfa 8-20HZ If construction coincides with the raptor nesting season, KMOG will perform pre-construction surveys to determine nearby nest statuses. If construction occurs during the Burrowing Owl nesting season, CPW protocol-level surveys will be performed prior to construction. If active Burrowing Owl burrows are identified within 1/4 mile of the Site, KMOG will proceed with CPW consultation.` Page 13 of 23Date Run: 3/19/2024 Doc [#403278400] 8 Storm Water/Erosion Control KMOG will conduct weekly storm water inspections during normal operations in addition to post-precip / melt response inspections based on COR40 permit. ` 9 Storm Water/Erosion Control KMOG will use Modular Large Volume Storage Tanks. ` 10 Storm Water/Erosion Control KMOG will install perimeter controls to control potential sediment-laden runoff in the event of spill or release from Modular Large Volume Storage Tank. ` 11 Storm Water/Erosion Control Outlet protection will be used when a conveyance discharges onto a disturbed area where there is potential for accelerated erosion due to concentrated flow. Outlet protection should be provided where the velocity at the culvert outlet exceeds the maximum permissible velocity of the material in the receiving channel. ` 12 Storm Water/Erosion Control KMOG will ensure that control measures are designed, installed and adequately sized in accordance with good engineering, hydrologic and pollution control practices. ` 13 Storm Water/Erosion Control If it is infeasible to install or repair a control measure immediately after discovering a deficiency, operator will document and keep on record in the stormwater management plan: (a) a description of why it is infeasible to initiate the installation or repair immediately; and (b) a schedule for installing or repairing the control measure and returning it to an effective operating condition as soon as possible. ` 14 Storm Water/Erosion Control KMOG will anchor all tanks to resist floatation.` 15 Storm Water/Erosion Control 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.` 16 Storm Water/Erosion Control A diversion ditch and berm will be implemented to divert stormwater run-on & run-off throughout Alfalfa 8-20HZ to a designated outlet structure(s). ? This BMP will be installed prior surface disturbing activities and will surround the entirety of the location to create continuous perimeter control. ? An additional berm will be installed on the western and southwestern perimeter of the well pad working surface, and on the northern perimeter of the facility pad working surface. ? Diversion ditch and berm will remain in-place until interim reclamation activities are complete.` 17 Storm Water/Erosion Control A temporary spillway and/or outlet are designed to capture sediment transported in surface runoff and slowly release flows to allow time for settling of sediment prior to discharge from the location. ? Spillway and/or outlet will be installed concurrently with the facility diversion ditch and berm, and prior to commencement of surface disturbing activities. ? A temporary spillway/outlet will be installed in the northwestern and southwestern segment of the disturbance area ditch and berm and the southern and southwestern segments of the well pad berm for Alfalfa 8-20HZ. ? All spillways and outlets will remain in-place until interim reclamation activities are complete. Culverts will be installed at the northeastern and eastern location access points for Alfalfa 8-20HZ facility pad and well pad` Page 14 of 23Date Run: 3/19/2024 Doc [#403278400] 18 Storm Water/Erosion Control A temporary diversion ditch & berm around the entire location to manage run-on and run-off; an additional berm placed on the southern and western perimeters of the well pad working surface and the northern perimeter of the facility pad working surface; temporary spillways and outlet structure placed in the northwestern and southwestern portions of the disturbance area ditch and berm and the northeastern portion of the well pad berm, which will allow for settling of sediment from stormwater prior to discharge; ~4 temporary culverts with inlet and outlet protection installed at the location access points to direct stormwater to designated outlet structures; seed & mulch to stabilize areas no longer needed for construction, as well as for topsoil stockpiles which will remain in place until interim and final reclamation. 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. Maintenance and repair will be completed as soon as practicable, immediately in most cases.` 19 Material Handling and Spill Prevention KMOG will refuel vehicles only on impervious surfaces and never during storm events. ` 20 Material Handling and Spill Prevention KMOG will ensure that a fueling contractor is present during the entire fueling process to prevent overfilling, leaks and drips from improper connections. ` 21 Material Handling and Spill Prevention KMOG will install adequate down gradient controls if they can not have a control at the source. ` 22 Material Handling and Spill Prevention KMOG will properly test for and dispose of TENORM. ` 23 Material Handling and Spill Prevention 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 Kerr-McGee's Integrated Operations Center (IOC), which is manned 24 hours per day, 7 days per week.` 24 Material Handling and Spill Prevention Appropriate secondary containment will be utilized when equipment maintenance is conducted on location. KMOG will shut down transfer pump and close supply valve when transfer or circulation is completed. KMOG will ensure fluids cannot enter holding tank through gravity feedback. 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. During operations, all fluid containing equipment is inspected daily.` 25 Material Handling and Spill Prevention Completion: During completions operations, the following site-specific best management practices will be used: KMOG will monitor pressure responses and containment to identify potential leaks. Lines will also be walked continuously throughout operations (between stages) to identify potential leaks. In addition, 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.` 26 Material Handling and Spill Prevention production: 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 Kerr-McGee's Integrated Operations Center (IOC), which is manned 24 hours per day, 7 days per week. 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.` Page 15 of 23Date Run: 3/19/2024 Doc [#403278400] 27 Dust control Access roads are not paved, they are constructed with a minimum of four - inches of gravel road base KMOG will proactively deploy fresh water to suppress dust along access road to well pad/ facility during all phases of pre-production operations ? Speed limits will be reduced to 10 mph on access road and 5 mph once vehicles reach well pad/ facility ? Access roads and Vehicle Tracking Control will receive maintenance as needed throughout operations. In the event of high winds that generate dust that cannot be mitigated with an application of water, KMOG will shut down construction operations. During the Completions phase, KMOG will utilize a fully enclosed sand containerized proppant delivery system that eliminates the use of pneumatic transfer on location. This methodology utilizes a gravity choke feed system that reduces dust significantly. The dust levels from this system are minimal and below Occupational Safety and Health Administration (OSHA) permissible exposure limit which eliminates the need for additional Personal Protective Equipment (PPE)` 28 Dust control Vehicle Tracking VTC will be installed at the primary access for Alfalfa 8-20HZ, which is to the northeast of both the well pad and facility pad. The access road adjoins/intersects Weld County Road 20, approximately 0.59 miles northeast of the location. Additional VTC installation for facility access will be incorporated as needed and constructed.` 29 Noise mitigation Drilling Operations NIA • Compliant with mitigation: Partial-perimeter, engineered sound wall consisting of 800 linear feet of 32-foot-tall wall, rated at STC32 and 100 linear feet of 24- foot-tall wall, rated at STC43 Completions Operations NIA • Compliant with mitigation: Partial-perimeter, engineered sound wall consisting of 800 linear feet of 32-foot-tall wall, rated at STC32 and 100 linear feet of 24- foot-tall wall, rated at STC43 Flowback Operations • Utilizes a fraction of similar, but smaller equipment compared to the three other operations studied. Leave perimeter sound wall in place until flows are initiated. Production Operations NIA • Compliant without mitigation` 30 Emissions mitigation KMOG commits to monitoring ambient air quality during drilling and completion operations and for the first 6 months of production in accordance with Reg. 7. ` 31 Emissions mitigation KMOG will not flare or vent gas during completion or flowback, except in upset or emergency conditions, or with prior written approval from the Director for necessary maintenance operations. ` 32 Emissions mitigation KMOG will control emergency flaring with an enclosed combustor with a destruction efficiency of 98% or better. ` 33 Emissions mitigation KMOG will control bradenhead/casinghead venting. ` 34 Emissions mitigation During Drilling: Rig power will be supplied by two natural gas engines with a battery energy storage system and an automated engine management system. As necessary, a diesel generator will be used to supplement additional power during the highest demand portions of the wells. KMOG uses an automated engine management system that preferentially uses natural gas engines over diesel for rig power. During Completions: During completions KMOG uses a closed loop system. As a standard practice, KMOG has also implemented the pipelined Water on Demand (WOD) system which will eliminate approximately 393,676 truck trips at the Sprout OGDP locations during completions activities. During Flowback: Fluids will flow through separation equipment where the gas will be collected through a gas gathering line instead of vented or burned.` 35 Emissions mitigation During Production: KMOG uses production facilities that have been designed to eliminate most emission sources. Oil will not be stored on location where it could cause emissions but will be gathered and sent via pipeline to a stabilization facility.` 36 Emissions mitigation Produced water will be piped from the Alfalfa locations.` Page 16 of 23Date Run: 3/19/2024 Doc [#403278400] 37 Odor mitigation drilling: 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. • 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. • All drill cuttings are processed through centrifugal dryers to remove residual oil-based drilling fluid not removed by shale shakers. • All tubulars pulled out of the hole will be wiped prior to being racked in the derrick or laid down. • Cuttings storage time on location will be minimized prior to transport to local landfills. • 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.` 38 Odor mitigation production: • KMOG uses pipelines to transport hydrocarbons (oil & gas) from the production facility eliminating odors that could occur during truck loading. • 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. • 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). • KMOG remotely monitors production facilities, this reduces traffic onto production facilities which may create odors from truck traffic.` 39 Drilling/Completion Operations All storage tanks used for active production rig drilling operations, used in lieu of pits, will contain pit level monitors with Electronic Drilling Recorders (EDR). KMOG uses EDRs with pit level monitor(s) and alarm(s) for production rigs. Basic level gauges will be used on tanks associated with the surface rig. ` 40 Drilling/Completion Operations Test separators and associated flow lines, sand traps and emission control systems? shall be installed on-site to accommodate completions techniques. When commercial? quantities of salable quality gas are achieved at each well, the gas shall be? immediately directed to a sales line or shut in and conserved. If a sales line is? unavailable or other conditions prevent placing the gas into a sales line, KMOG shall? not produce the wells. KMOG agrees to comply with both Rules 903.c.(3).B. and 903.c.(3).C.? ` 41 Drilling/Completion Operations Guy line anchors will not be used. Base Beams will be used to stabilize the rig and removed after drilling. ` Page 17 of 23Date Run: 3/19/2024 Doc [#403278400] 42 Drilling/Completion Operations KMOG is proposing one 25,000 BBL MVLT for this location for use during completions – 36 feet tall with a 70 foot diameter. The proposed manufacturer and vendor is Shalestone Resources. The MLVT is approximately 2,485 feet from the nearest RBU and is a temporary piece of equipment (on location for approximately 2 months). The MLVT will be in compliance with the following COGCC safety setbacks. 1. Seventy-five (75) feet from a wellhead, fired vessel, heater-treater, or a compressor with a rating of 200 horsepower or more; 2. Fifty (50) feet from a separator, well test unit, or other non-fired equipment. 3. Signs shall be posted on each MLVT to indicate that the contents are fresh water and that no E&P waste fluids are allowed. Location and additional signage shall conform to Rule 210. 4. MLVTs will be operated with a minimum of 1 foot freeboard at all times. 5. Access to the tanks shall be limited to operational personnel. 6. Construction and installation of the tank structure, liner and sub-grade shall meet or exceed the manufacturer specifications. 7. KMOG follows manufacturers Standard Operating Procedures (SOPs) and will provide these SOPs upon request to the COGCC. 8. KMOG will conduct daily, visual inspections of the exterior wall and general area for any integrity deficiencies before, during, and after filling the MLVTs. If deficiencies are noted, KMOG will repair them as soon as practicable. Records of repairs will be maintained per Rule 205. 9. KMOG will follow pre-construction risk assessment measures to address safety concerns and minimize environmental impacts and property damage in the unlikely event of a MLVT release. 10. In the event of a catastrophic MLVT failure, KMOG shall notify the COGCC as soon as practicable but not more than 24 hours after discovery, submit a Form 22- Accident Report within 10 days after discovery, conduct a root cause analysis´ and provide same to COGCC on a Form 4-Sundry Notice within 30 days of the failure. 11. All MLVT liner seams shall be welded and tested in accordance with applicable ASTM international standards. Any repairs to liners shall be made using acceptable practices and applicable standards. 12. The MLVT shall be constructed and operated in accordance with a design package certified and sealed by a Licensed Professional Engineer either in Colorado or the state where the MLVT was designed or manufactured. 13. KMOG hereby certifies to the Director that the MLVT at this location will be designed and implemented consistent with the Colorado Oil and Gas Conservation Commission policy dated June 13, 2014.` 43 Drilling/Completion Operations The following are BMPs agreed on by the Operator as an outcome of the CDPHE consultation: • Operator will properly maintain vehicles and equipment • Operator will use non-emitting pneumatic controllers • Operator will use Tier IV or equivalent engines, such as NG Tier II w/ battery assist, (or better) for drilling (dual-fuel engines are not considered equivalent) • Operator will use Tier IV or equivalent engines, such as NG Tier II w/ battery assist, (or better) for hydraulic fracturing (dual-fuel engines are not considered equivalent) • Operator will use electric equipment and devices (e.g. vapor recovery units or VRUs, fans, etc.) to minimize combustion sources on site (if yes, operator will provide a list outlining which equipment and devices will be electrified) • Operator will use service providers who utilize at least 50% Tier IV or equivalent engines, such as NG Tier II w/ battery assist, (or better) for nonroad construction equipment (dual-fuel engines are not considered equivalent) • 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) • Operator will implement a "hybrid or modern" production flowack method (eliminates tanks by routing the oil, natural gas and water directly to permanent production equipment) • Operator will use pipelines to transport water used for hydraulic fracturing to location • Operator will have adequate and committed pipeline takeaway capacity for all produced gas and oil • Operator will shut in the facility to reduce the need for flaring if the pipeline is unavailable • Operator will use lease automatic custody transfer (LACT) system to remove/reduce the need for truck loadout Page 18 of 23Date Run: 3/19/2024 Doc [#403278400] • Operator will use OGP Group III drilling fluid • Operator will cover trucks transporting drill cuttings • Operator will use a squeegee or other device to remove drilling fluids from pipes as they exit the wellbore • Operator will ensure that all drilling fluid is removed from pipes before storage • Ozone mitigation on forecasted high ozone days: operator will eliminate use of VOC paints and solvents • Ozone mitigation on forecasted high ozone days: operator will minimize vehicle and engine idling • Ozone mitigation on forecasted high ozone days: operator will reduce truck traffic and worker traffic • Ozone mitigation on forecasted high ozone days: operator will postpone the refueling of vehicles • Ozone mitigation on forecasted high ozone days: operator will suspend or delay the use of non-essential fossil fuel powered ancillary equipment • Ozone mitigation on forecasted high ozone days: operator will adjust construction schedules to postpone non-essential construction activity, including but not limited to temporary tank removals and cleaning on ozone action days • Ozone mitigation on forecasted high ozone days: operator will send notification to all operational staff requesting that where possible, they delay all non-essential operational activity (such as pigging, well unloading and tank cleaning) on ozone action days • Operator will use Modular Large Volume Storage Tanks • Operator will not use fracturing fluids which contain PFAS compounds • Operator will continue to participate in the Colorado Preparedness Resources Network (CPRN)CPRN, which has a non-PFAS foam location identification to be sure, in an emergency, that non-PFAS foam will be available • Operator will coordinate with nearby fire district(s) to evaluate whether PFAS-free foam can provide the required performance for the specific hazard • If PFAS-containing foam is used at a location: operator will properly characterize the site to determine the level, nature and extent of contamination • If PFAS-containing foam is used at a location: operator will perform appropriate soil and water sampling to determine whether additional characterization is necessary and inform the need for and extent of interim or permanent remedial actions • If PFAS-containing foam is used at a location: operator will properly capture and dispose of PFAS-contaminated soil and fire and flush water In addition, CDPHE supports incorporation of each of the BMPs that Oxy has committed to exclusively for the Alfalfa and Clover pads in the Sprout OGDP, as listed below: • Operator will not store produced water in permanent storage tanks on site (other than a maintenance tank possibly used for well unloading or other maintenance activities) • Operator will use pipelines to transport water used for hydraulic fracturing from location` 44 Interim Reclamation The completed wellsite will be surrounded with a fence and gate with adequate lock to restrict access to authorized personnel only. KMOG personnel will monitor the wellsite upon completion of the wells. Authorized representatives and/or KMOG personnel shall be on-site during drilling and completions operations. ` Page 19 of 23Date Run: 3/19/2024 Doc [#403278400] 45 Interim Reclamation 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. Topsoil stabilization with mulch, seeding, track walking, perimeter control or a combination of BMPs. Weeds on stockpiles shall be controlled as to prevent production of weed seed and/or enough biomass that would interfere with redistribution of soil or cause onsite debris. Signage shall be installed to identify topsoil stockpiles to facilitate subsequent reclamation and indicate to personnel that the area may not be disturbed by drilling and completion operations. 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.` 46 Interim Reclamation After topsoil re-distribution, the interim reclamation area shall be cross ripped to a depth of eighteen inches with an agricultural ripper/subsoiler; however, this depth may be adjusted in rocky or shallow soils. Chiseling/ripping will be performed at the minimum depth of topsoil. Cultipacking or disking may be required to reduce soil clod size. Ripping with construction style shanks, for the purpose of surface ridge roughness as a stormwater BMP, is only allowed to a six-inch depth, and will be maintained following any precipitation or surface erosion which has the potential to compromise the BMP.` 47 Interim Reclamation Mulch application in cropland shall be applied as requested by surface owner. If using straw or hay mulch, only mulch that has been certified as weed-free forage may be used. All mulch types must be anchored properly by methods such as crimping, disking and/or tackifier. Contractor may adjust the rate of mulch and type based on site location, soils, slopes, and time of year to maximize seeding and erosion control success.` 48 Interim Reclamation Seed and mulch are utilized in disturbed areas to establish stabilization through vegetative cover. ? Seeding will take place once surface disturbing activities are complete. Topsoil stockpiles will be stabilized with seed and mulch no longer than 14- days after completion of stockpiling efforts unless weather or ground conditions are not suitable to properly create a seedbed and promote successful germination. ? Seed & mulch will be installed on all disturbed areas no longer utilized for construction, and on all topsoil stockpiles which will remain on Alfalfa 8-20HZ for use during final reclamation. Anticipated topsoil stockpiles will be situated along the northern perimeter of the facility and northern, western and southern perimeter of the well pad. ? Seeding will remain in place until re-disturbed during final reclamation efforts. ? In areas to be returned to crop, the seed bed will be prepared and left for surface owner to plant during next agricultural season.` 49 Final Reclamation The wellsite will be cleared of all non-essential equipment within ninety (90) days after all wells associated with the pad have been plugged and abandoned. ` 50 Final Reclamation Once the wells have been plugged and abandoned, KMOG will identify the location of the wellbores with permanent monuments that will detail the well names and date of plugging. ` Total: 50 comment(s) Page 20 of 23Date Run: 3/19/2024 Doc [#403278400] Attachment List Att Doc Num Name 21316815 GEOLOGIC HAZARD MAP 21316819 CORRESPONDENCE 21316821 CDPHE CONSULTATION 21316823 LOCAL GOVERNMENT PERMIT 21316826 OTHER 21316827 OTHER 21316828 OTHER 21316830 DIRECTOR'S RECOMMENDATION 403278400 FORM 2A SUBMITTED 403497610 LGD CONSULTATION 403497618 ACCESS ROAD MAP 403497623 HYDROLOGY MAP 403497625 DIRECTIONAL WELL PLAT 403497628 LOCATION DRAWING 403497635 LOCATION PICTURES 403497637 LOCATION PICTURES 403497652 PRELIMINARY PROCESS FLOW DIAGRAMS 403521422 WILDLIFE HABITAT DRAWING 403521425 OIL AND GAS LOCATION GIS SHP 403521451 OTHER 403521452 CULTURAL FEATURES MAP 403627574 LAYOUT DRAWING 403627581 NRCS MAP UNIT DESC 403627589 RELATED LOCATION AND FLOWLINE MAP 403628649 OTHER Total Attach: 25 Files Page 21 of 23Date Run: 3/19/2024 Doc [#403278400] User Group Comment Comment Date OGLA OGDP ID# 485787and this Form are approved by Commission Order Number 407-3580 03/14/2024 OGLA Due to a technical glitch, the Weld County comments did not save. Weld County emailed the following to ECMC: The Weld County Oil and Gas Energy Department (OGED) submits the following comments: Case number 1041WOGLA23-0047 has been assigned to the Alfalfa 8-20HZ Location. All files associated with the processing and review of this permit are accessible through the Weld County E-Permit Center at https://aca-prod.accela.com/WELD/Default.aspx. If there are any questions relating to the ability to access these files, please call the OGED office at 970-400-3580. The Kerr-McGee Oil & Gas Onshore LP (KMG) Alfalfa location was reviewed and processed under Weld County Code, ORD2021-17. A pre-application meeting was held on February 1, 2023. Attendees included OGED Staff, KMG Staff, ECMC, CPW, Weld County Staff, Town of Firestone representatives. The 1041 WOGLA Application was received on October 9, 2023. The application submitted is compliant with all requirements of Section 21-5-320 of the Weld County Code. Weld County sent referrals to appropriate parties on November 7, 2023. Kerr McGee Oil & Gas Onshore, LP held a Community Outreach meeting on December 6, 2023 at 6pm at the Firestone Town Hall. OGED Staff members attended. There were no residents or community members in attendance. OGED did not receive any public comments or any Applications for Intervention. A 1041 WOGLA Hearing was held on January 11, 2024. The OGED Hearing Officer considered testimony at the 1041 WOGLA hearing, and subsequently approved 1041WOGLA23-0047. The approved Weld County 1041 WOGLA Permit, and KMG’s commitment to best management practices outlined in the application, will protect the health, safety, security and general welfare of the present and future residents of Weld County, while also protecting both the environment and wildlife. The final order was recorded with the Weld County Clerk Recorder on January 23, 2024, reception number (4940730) and was noticed in the Greeley Tribune on January 26. Approval and of KMG’s application creates a vested property right pursuant to Article 68 of Title 24, C.R.S. The approved permit is valid for three (3) years – construction must commence within the timeframe, or an extension must be requested and approved, or the permit will expire. Due to the fact that KMG has completed the 1041 WOGLA Application process, and that a final order has been issued, recorded and legally published, Weld County has no additional concerns with the pending ECMC permit, and would recommend approval. 03/14/2024 OGLA The Director has determined that the OGDP application that this Form is a component of meets all requirements of Rule 306.a. The Director’s Recommendation has been attached to the Form 2A. 02/22/2024 OGLA Operator sent final Local Government siting. ECMC staff updated the information regarding the submittal and approval of the Local permit and has attached the permit. Removed the comment "THE WOGLA WILL BE SUBMITTED SOON - WILL UPDATE OGLA WHEN THAT HAPPENS" as the information has been updated. Attached response to public comments as "OTHER" doc 21316827 and Executive Summary as "OTHER" doc 21316826. 02/16/2024 OGLA A Consultation with CDPHE occurred on 1/22/2024 between CDPHE, Oxy, and ECMC staff. The CDPHE letter for the consultation is attached and the BMPs have been added to the BMP section. 02/12/2024 OGLA Spoke to Operator regarding flowline between the Ruca location (loc ID 458592) to the north and this proposed Alfalfa location on the flowline map. This proposed Alfalfa location will be to the production phase before the Ruca location will be connected to the Alfalfa and the Ruca production equipment removed. As there is not an exact timeline for this to occur, the Ruca is not listed as a remote related location and is not included on the Form 2B for this OGDP. A Sundry for the OGDP will be submitted at a later date when the Ruca production equipment is removed and the flowlines are in place to the Alfalfa location. 01/11/2024 General Comments Page 22 of 23Date Run: 3/19/2024 Doc [#403278400] OGLA Public comment period for this location is 30-days. A technology glitch initially assigned 45 days for public comment ending on 2/11/24. The date has been updated to be 30 days post the OGDP considered Complete on 12/28/2023 for the public comment to end on 1/27/2024. 01/09/2024 OGLA Inform CDPHE the location is in the 8-hour ozone area. CDPHE requested a consultation for the proposed location and OGDP. 01/08/2024 OGLA Attached Completeness spreadsheet as correspondence doc no 21316819 12/28/2023 OGLA The Director has determined this OGDP application is complete. Form pushed to IN PROCESS. 12/28/2023 OGLA Updated the equipment list, Geologic Hazard Plan and map per email and phone correspondence with the Operator. 12/27/2023 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. 12/27/2023 OGLA Completeness review - Return to draft 12/01/2023 Total: 13 comment(s) Public Comments No public comments were received on this application during the comment period. Page 23 of 23Date Run: 3/19/2024 Doc [#403278400]