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HomeMy WebLinkAboutHICKORY 10-34HZ - Development Notification - Kerr McGee - 6/17/2024State 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 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: 403563270 11/27/2023 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) 929-6463 ( ) Sarah Clark 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 231100358 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 486434 Hickory 10-34HZ Number:HICKORY Name: LOCATION IDENTIFICATION 06/11/2027Expiration Date: Location ID:487050 OGDP ID:486434 Page 1 of 25Date Run: 6/17/2024 Doc [#403563270] 09/25/20231.5 Date of Measurement:GPS Quality Value: 4872667W 3N 34 Ground Elevation:Meridian:Township:NWSE 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:40.180772 Longitude:-104.872610 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:12/15/2023 Current status or disposition of the Relevant Local Government permit application for this proposed Oil and Gas Location:Approved Status/disposition date:03/22/2024 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:970-470-3581 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. < No row provided > (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 25Date Run: 6/17/2024 Doc [#403563270] Additional explanation of local and/or federal process: KMOG will update the ECMC when a WOGLA final disposition is recorded. No 07/19/2023Date 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 Complete this section for any pre-application consultation related to this proposed Oil and Gas Location that occurred prior to the submission of this Form 2A. If a pre-application Formal Consultation Process occurred, attach a Consultation Summary. ALA APPLICABILITY AND CRITERIA If YES, indicate by checking the box for every Rule 304.b.(2).B criterion met by this proposed Location, and attach an ALA. See Rule 304.b.(2).B.i-x for full text of criteria. Does the proposed Oil and Gas Location meet any of the criteria listed in Rule 304.b.(2)B?Yes i. WPS < 2,000 feet from RBU/HOBUX 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 X Is the proposed Oil and Gas Location within the exterior boundaries of the Southern Ute Indian Reservation, and the Tribe objects to the Location or requests an ALA? If YES, attach an ALA to the Form 2A. Operator requests the Director waive the ALA requirement per Rule 304.b.(2).A.i: No Provide an explanation for the waiver request, and attach supporting information (if necessary). Page 3 of 25Date Run: 6/17/2024 Doc [#403563270] 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 40.195011 -104.874396 x 40.224612 -104.874423 x 40.183503 -104.872994 x x 40.220622 -104.878432 x 304.b.(2).B.i-x Criteria Met: SURFACE & MINERAL OWNERSHIP Name:Gerald and Katherine Haml Phone:970-302-3178 N/A Fax:6678 Secretariat Drive Address: Address: Email:Kathy.hamlin@comcast.net City:Longmont State:CO Zip:80503 Surface Owner Info: X IndianFederalStateFeeSurface Owner at this Oil and Gas Location: All operations on this Oil & Gas Location will develop the minerals beneath the Location, and the Operator intends to use a surface bond per Rule 703 to secure access to this Location – attach lease map or provide lease description. All operations on this Oil & Gas Location will develop the minerals beneath the Location, and the surface owner owns the minerals beneath this Location and is committed to an oil and gas lease – attach lease map or provide lease description. The Operator has a signed Surface Use Agreement for this Location – attach SUA. The Operator/Applicant is the surface owner. Check only one: X Minerals beneath this Oil and Gas Location will be developed from or produced to this Oil and Gas Location: Mineral Owner beneath this Oil and Gas Location: Surface Owner protection Financial Assurance type:Surety ID Number: Lease description if necessary:Township 3 North, Range 67 West, 6th P.M., Section 15: NW, Section 22: S2SE, NWSE 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 12 Drilling Pits 0 Pump Jacks 12 Gas or Diesel Motors 0 Dehydrator Units 0 Oil Tanks 0 Production Pits 0 Separators 4 Electric Motors 0 Vapor Recovery Unit 0 Condensate Tanks 1 Special Purpose Pits 0 Injection Pumps 0 Electric Generators 0 VOC Combustor 1 Water Tanks 4 Multi-Well Pits 0 Heater-Treaters 0 Fuel Tanks 0 Flare 0 Buried Produced Water Vaults 0 Modular Large Volume Tank 0 Gas Compressors 0 LACT Unit 2 Enclosed Combustion Devices 0 Pigging Station 0Meter/Sales Building 2 Vapor Recovery Towers 0 OTHER PERMANENT EQUIPMENT Page 4 of 25Date Run: 6/17/2024 Doc [#403563270] Permanent Equipment Type Number Gas Cooler 1 Electrical Boxes 3 Gas Scrubber 1 Communication Towers 1 E houses 2 FG Scrubbers 1 Chemical Totes 4 Air Compressors 1 Oil Cooler 1 OTHER TEMPORARY EQUIPMENT Temporary Equipment Type Number Multi-Phase Cooler 2 Water Tanks 22 Enclosed Combustion Devices 7 FWKO (Free Water Knockout)1 MLVT 1 Propane Tanks 1 Water Cooler 2 Generator 1 Purge Flares 3 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:1000 Feet Designated Outside Activity Area:5280 Feet Public Road:1954 Feet Above Ground Utility:262 Feet Railroad:5280 Feet Property Line:50 Feet CULTURAL DISTANCE AND DIRECTION Distance SW W S W E E Direction Rule 604.b Conditions Satisfied (check all that apply): 604.b. (1)Details of Condition(s) 604.b. (2) 604.b. (3) 604.b. (4) XResidential Building Unit (RBU):1346 Feet S High Occupancy Building Unit(HOBU)5280 Feet NE Page 5 of 25Date Run: 6/17/2024 Doc [#403563270] School Facility:5280 Feet Child Care Center:5280 Feet NE NE Disproportionately Impacted (DI) Community: 5280 Feet W WFeet5280RBU, 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 9 9 1,001-2,000 feet 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: 12.38Size of disturbed area during construction in acres: CONSTRUCTION 4.93 DRILLING PROGRAM Yes No Will oil based drilling fluids be used?Yes 4872 or equal to 100 ppm?If YES, attach H2S Drilling Operations Plan.No No Page 6 of 25Date Run: 6/17/2024 Doc [#403563270] 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 Describe the Relevant Local Government’s land use or zoning designation: AGRICULTURE Describe any applicable Federal land use designation: Other Residential RecreationForestry CommercialIndustrial Rangeland Conservation Reserve Program (CRP)Non-IrrigatedIrrigated Subdivided: Non-Crop Land: Crop Land: Final Land Use: check all that apply per Rule 304.b.(9). X FINAL LAND USE Reference Area Latitude: If Final Land Use includes Non-Crop Land (as checked above), the following information is required: Describe landowner’s designated final land use(s): REFERENCE AREA INFORMATION AGRICULTURAL 40.181760 -104.876010Reference Area Latitude: Provide a list of plant communities and dominant vegetation found in the Reference Area. Plant Community Dominant vegetation Disturbed Grassland smooth brome (Bromopsis inermis) Disturbed Grassland intermediate wheatgrass (Thinopyrum intermedium) Disturbed Grassland crested wheatgrass (Agropyron cristatum) 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:13- Cascajo gravelly sandy loam, 5 to 20 percent slopes NRCS Map Unit Name:35- Loup-Boel loamy sands, 0 to 3 percent slopes NRCS Map Unit Name:72- Vona loamy sand, 0 to 3 percent slopes Page 7 of 25Date Run: 6/17/2024 Doc [#403563270] GROUNDWATER AND WATER WELL INFORMATION Provide the distance and direction, as measured from the Working Pad Surface, to the nearest: water well:1201 Feet SW Spring or Seep:2640 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: Two monitoring wells were drilled to a depth of 8' within the proposed oil and gas location. Groundwater was encountered at 3.4' and 6.0'. KMOG conservatively estimates depth to groundwater at 3'. 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: Irrigation Ditch Feet NE153 If less than 2,640 feet, is the Waters of the State identified above within 15 stream miles upstream of a Public Water System intake?No Provide the distance and direction to the nearest downgradient wetland, measured from the Working Provide a description of the nearest downgradient surface Waters of the State: If the proposed Oil and Gas Location is within a Rule 411.a Surface Water Supply Area buffer zone, select the buffer If the proposed Oil and Gas Location is within a Rule 411.b GUDI/Type III buffer zone, select the buffer Is a U.S. Army Corps of Engineers Section 404 permit required for the proposed Oil and Gas Location, access road, or If a U.S. Army Corps of Engineers Section 404 permit is required, provide the permit status, and permit number if available: zone type: associated pipeline corridor?No Pad Surface:NEFeet153 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 When Rule 309.e.(2) Consultation must occur, check all that apply: This location is included in a Wildlife Mitigation Plan Page 8 of 25Date Run: 6/17/2024 Doc [#403563270] 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. 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. The applicant has obtained a Rule 309.e.(5).D.iv CPW waiver and is requesting an exception from Rule 1202.c.(1) in accordance with an approved CAP. X The applicant has obtained a Rule 1202.a CPW waiver. The applicant has obtained a Rule 1202.b CPW waiver. In accordance with Rule 1203.a.(3), the applicant requests an exception from compensatory mitigation Rule(s): HIGH PRIORITY HABITAT AND COMPENSATORY MITIGATION This Oil and Gas Location, associated access roads, utility, or Pipeline corridor falls wholly or partially within the following High Priority Habitats (Note: dropdown options are abbreviated - see Rule 1202 for full rule text): < 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: Page 9 of 25Date Run: 6/17/2024 Doc [#403563270] No BMP Operator Proposed Wildlife BMPs No BMP CPW Proposed Wildlife BMPs 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 No BMP Operator Proposed BMPs CDPHE Proposed COAs OR BMPs No BMP PLANS Total Plans Uploaded: 15 Page 10 of 25Date Run: 6/17/2024 Doc [#403563270] (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 (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 ECMC 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 11 of 25Date Run: 6/17/2024 Doc [#403563270] 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 12 of 25Date Run: 6/17/2024 Doc [#403563270] djregulatory@oxy.com Staff Geologist 11/27/2023 Sarah Clark ECMC Approved:Director of ECMC Date:6/17/2024 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. A Weld County 1041 WOGLA will be 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. The attached EAP will be submitted to the Platteville Gilcrest Fire Protection District. Once the plan is approved a signed copy will be sent to the ECMC OGLA staff. 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. It is estimated that the 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. 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 1,382 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. Note: Estimated post-construction ground elevation on Construction, Drilling & Waste tab and Ground Elevation on Location (D & Local Govt Info tab is actually 4871.5'. Webforms would not accept a decimal point in these fields. Best Management Practices No BMP/COA Type Description 1 General Housekeeping All loadlines shall be bullplugged or capped. ` COA Type Description 0 COA CONDITIONS OF APPROVAL, IF ANY LIST All representations, stipulations and conditions of approval stated in this Form 2A for this location shall constitute representations, stipulations and conditions of approval for any and all subsequent operations on the location unless this Form 2A is modified by Sundry Notice, Form 4 or an Amended Form 2A. Page 13 of 25Date Run: 6/17/2024 Doc [#403563270] 2 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 1,040 linear feet of 32-foot-tall, STC32 wall and 72 linear feet of 24foot-tall STC43 wall will be installed around the edge 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 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 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.` Page 14 of 25Date Run: 6/17/2024 Doc [#403563270] 3 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. ? All specific wastes in the attached site-specific Table 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. ? The proper personal protective equipment will always be worn when handling waste. Employees will refer to the Safety Data Sheet for additional information. ? Good housekeeping measures will be implemented in the operating area and to ensure safety and environmental well-being. ? Wastes will be segregated and stored according to its waste type. ? 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. ? All waste streams will be transported off location for recycling or disposal in a timely manner in accordance with local, state, and federal regulations. ? 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. ? 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.` Page 15 of 25Date Run: 6/17/2024 Doc [#403563270] 4 General Housekeeping • Operator will properly maintain vehicles and equipment • Operator will use non-emitting pneumatic controllers • Operator will use electric drilling rigs if available, and will demonstrate best-effort if unable to utilize them • Operator will utilize two Tier II Natural Gas engines with battery assist, with a third auxiliary diesel generator for high demand operations, including an automated engine management system for increased efficiencies and reduced emissions • 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 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 flowback 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 take away 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 • 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 commit to not fueling vehicles on location • 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 • Ozone mitigation on forecasted high ozone days: operator will reschedule non- essential operational activities such as pigging, well unloading and tank cleaning • Operator will use Modular Large Volume Storage Tanks • Operator will not use fracturing fluids which contain PFAS compounds • Operator will contribute to nearby fire district(s) to support transition away from PFAS-containing foam through funding, buy-back program participation/promotion, etc. • 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` Page 16 of 25Date Run: 6/17/2024 Doc [#403563270] 5 Wildlife The chemical totes to be used on the Location will be built within a secondary containment and are made of steel. Additionally, KMOG will construct earthen berms on the downgradient edges of the pad to restrict contaminant pathways and all other tanks on location will be within steel bermed secondary containments compliant with EPA rule 40CFR 112 Subpart A, B, C. If Location construction starts between December 1 and July 31, CPW recommends surveys for nesting eagles. If construction starts between February 1 and August 15, CPW recommends surveys for nesting non-eagle raptors. For ground disturbances beginning between March 15 and August 31, 2024, a follow- up survey will be completed no more than twenty-one (21) days prior to the start of work, to check for possible encroachment from prairie dogs. If potentially suitable habitat is observed within 0.25 miles from the Location, the full three-survey CPW- protocol will be completed no more than seven (7) days prior to the start of work. If burrowing owls are observed using burrows within 0.25 miles of the Location, KMOG will consult with CPW to determine appropriate mitigation measures. KMOG will disinfect water suction hoses and water tanks withdrawing from or discharging into natural surface waters using a CPW-approved disinfectant or with water greater than 140° F for at least 10 minutes. KMOG will fence and net or install other CPW-approved exclusion devices on new or existing (if ECMC determines it’s necessary to protect Wildlife Resources) drilling pits, production pits, and other pits associated with Oil and Gas Operations that are intended to contain Fluids. KMOG will install wildlife escape ramps for trenches that are left open for more than 5 consecutive days. KMOG will use CPW-recommended seed mixes for Reclamation and use CPWrecommended fence designs when consistent with the Surface Owner’s approval and any local soil conservation district requirements. KMOG will use CPW-recommended fence designs when consistent with the Surface Owner’s approval and any Relevant Local Government requirements. KMOG will conduct all vegetation removal necessary for operations outside of the nesting season for migratory birds (April 1 to August 31) or will need to conduct pre- construction nesting migratory bird surveys within the approved disturbance area prior to any vegetation removal during the nesting if hazing or exclusion devices were not installed prior to April 1. 1. Inform and educate employees and contractors on wildlife conservation practices, including no hunting, harassment, or feeding of wildlife. 2. Consolidate and centralize fluid collection and distribution facilities to minimize impact to wildlife. 3. Adequately size infrastructure and facilities to accommodate both current and future gas production. 4. Protect culvert inlets from erosion and sedimentation and install energy dissipation structures at outfalls. 5. Implement fugitive dust control measures. 6. Install screening or other devices on the stacks and on other openings of heater treaters or fired vessels to prevent entry by migratory birds. 7. Mow or brush hog vegetation where appropriate, leaving root structure intact, instead of scraping the surface, where allowed by the surface owner. 8. Limit access to oil and gas access roads where approved by surface owners, surface managing agencies, or local government. 9. Post speed limits and caution signs to the extent allowed by surface owners, Federal and state regulations, local government, and land-use policies. 10. Use wildlife-appropriate fencing where acceptable to the surface owner. 11. Use topographic features and vegetative screening to create seclusion areas, where acceptable to the surface owner. 12. Use remote monitoring of well production to the extent practicable. 13. Reduce traffic associated with transporting drilling water and produced liquids through the use of pipelines, large tanks, or other measures. 14. Install automated emergency response systems (e.g., high tank alarms, emergency shutdown systems).` Page 17 of 25Date Run: 6/17/2024 Doc [#403563270] 6 Storm Water/Erosion Control Topsoil will be managed during construction by a combination of site-specific erosion and sediment control measures including: a temporary diversion ditch & berm around the entire location to manage run-on and run-off. Short term management of topsoil will include track packing to prevent wind and water erosion. Long term management will include seeding with a native seed mix and crimping straw mulch for erosion control and water retention. Vegetation establishment on stockpiles and weed control will reduce erosion as well as maintain microbial activity. During the construction phase topsoil will be stockpiled ~8 tall along the western perimeter of the facility at a 4 to 1 slope and ~8’ tall along the northern perimeter of the well pad at a 4 to 1 slope to minimize erosion potential. 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. Long-term topsoil stockpiles will be placed along the western perimeter of the facility pad at a variable height at a 5 to 1 slope, and the southern perimeter of the well pad ~6’ tall at a 4 to 1 slope to reduce erosion and maintain microbial activity for an extended time. 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. ? 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. ? 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. ? 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.` Page 18 of 25Date Run: 6/17/2024 Doc [#403563270] 7 Storm Water/Erosion Control Stormwater will be managed during construction by a combination of site-specific erosion and sediment control measures including: delineation of limits of construction to establish a work space; a vehicle tracking control placed along the northern portion of the access road to the well pad and the facility pad to mitigate off-site sediment migration from vehicle traffic onto Weld County Road 28, approximately 0.50 miles north of the location; a temporary diversion ditch & berm around the entire location to manage runon and run-off and a berm on the northern, eastern and southern edges of the well pad, and the northern, western and southern edges of the production facility pad; temporary spillways and outlet structures placed in the eastern, northern and western portions of the disturbance area ditch and the northwestern portion of the production facility pad and eastern portion of the well pad berm, which will allow for settling of sediment from stormwater prior to discharge; ~1 temporary culvert with inlet and outlet protection will be installed in the primary well pad access point to direct stormwater to designated discharge 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. Stormwater will be managed during the interim reclamation and production phase by a combination of site-specific erosion and sediment control measures including: a berm around the northern, western and southern perimeter of the production facility pad, and around the perimeter of the well pad to manage run-on and run-off; stabilization of slopes and associated topsoil stockpile(s) by seed and crimped mulch application; permanent culverts with inlet & outlet protection may be installed at access roads and crossing, as determined in the field during construction; a spillway and outlet along the northwestern portion of the production facility berm and eastern perimeter of the well pad berm, which will remain in place until final reclamation. Post construction, daily inspections will be completed by on-site operations personnel. A third-party consultant will conduct stormwater compliance inspections every 30-days until final stabilization is achieved. Inspections will review all control measures / BMPs implemented, their status, and whether repair or replacement is needed, including weed maintenance when necessary. Maintenance and repair will be completed as soon as practicable, immediately in most cases.` 8 Material Handling and Spill Prevention 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 without an approved variance. ` 9 Material Handling and Spill Prevention KMOG will properly characterize and dispose of all waste (i.e. the specific landfill/waste disposal location allows for acceptance of the waste stream) ` 10 Material Handling and Spill Prevention KMOG will properly test for and dispose of TENORM ` Page 19 of 25Date Run: 6/17/2024 Doc [#403563270] 11 Material Handling and Spill Prevention The following site-specific best management practices will be used on location: 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. During the production phase, 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. During drilling operations, the following site-specific best management practices will be used: 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. 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. During production operations, the following site-specific best management practices will be used: 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.` 12 Dust control ? 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)` 13 Construction KMOG will extend an existing access road off of CR 28 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.` 14 Construction 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 20 of 25Date Run: 6/17/2024 Doc [#403563270] 15 Construction KMOG will only construct during day light and there will be no nighttime operations that require lighting. ` 16 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 ECMC Rule 423 and the WOGLA Section 21-5-435 noise regulations. Each phase of operation will comply with the MPNLs of both codes as summarized in Table 5 in Section 2 of this document. • Prior to commencement of drilling and completion activities, a partial perimeter, engineered sound wall consisting of approximately 1,040 linear feet of 32-foot-tall, STC32 wall and 72 linear feet of 24-foot-tall STC43 wall will be installed around the edge of the well pad to reduce noise levels at the critical receptor points. • KMOG is utilizing a modified drilling rig designed to reduce overall noise levels. This will include low noise level shale shakers and modifications to the generator house to reduce noise levels from the exhaust vents and radiator fans. Additional noise reduction modifications may also be implemented depending on the rig contractor utilized following a noise survey study. • 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 four locations outlined in Figure 3 of Section 7 to quantify pre-existing A- and C-weighted sound levels. • Throughout the duration of preproduction operations and any construction lasting longer than 24-hours, KMOG will conduct continuous noise monitoring at the ambient monitoring locations described in Figure 3 of Section 7 of this document. • If the drilling rig or completions fleet is changed prior to commencement of operations, the mitigation measures employed will be equally or more protective. A sundry form will be submitted to outline any changes, per both codes, as required. • 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 ECMC, or from Weld County, a KMOG representative will contact the associated stakeholder within 48 hours of receipt.` 17 Emissions mitigation KMOG will shut in production when pipeline is not available ` 18 Emissions mitigation Temporary ECD(s) will be utilized to mitigate releases of emissions from temporary produced water storage tanks for the duration which the tanks are on location and being used. ` Page 21 of 25Date Run: 6/17/2024 Doc [#403563270] 19 Odor mitigation ? 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. ? 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.` 20 Drilling/Completion Operations Guy line anchors will not be used. Base Beams will be used to stabilize the rig and removed after drilling. ` 21 Drilling/Completion Operations 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. ` Page 22 of 25Date Run: 6/17/2024 Doc [#403563270] 22 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. ` 23 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). KMG 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. ` 24 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. ` 25 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. ` Total: 25 comment(s) Page 23 of 25Date Run: 6/17/2024 Doc [#403563270] ATTACHMENT LIST Att Doc Num Name 2473675 CDPHE CONSULTATION 2473676 OTHER 2473677 INFORMED CONSENT LETTER 2473678 OTHER 2473679 OTHER 2473680 LOCAL/FED FINAL PERMIT DECISION 2473681 DIRECTOR'S RECOMMENDATION 403563270 FORM 2A SUBMITTED 403597680 LOCATION PICTURES 403597684 LOCATION PICTURES 403597686 LOCATION DRAWING 403597688 WILDLIFE HABITAT DRAWING 403597690 PRELIMINARY PROCESS FLOW DIAGRAMS 403597694 HYDROLOGY MAP 403597695 ACCESS ROAD MAP 403597696 RELATED LOCATION AND FLOWLINE MAP 403597697 DIRECTIONAL WELL PLAT 403597698 ALA NARRATIVE SUMMARY 403597700 OIL AND GAS LOCATION GIS SHP 403597704 REFERENCE AREA PICTURES 403597706 OTHER 403597707 SURFACE AGRMT/SURETY 403597713 CULTURAL FEATURES MAP 403597715 CPW WAIVER 403597721 LGD CONSULTATION 403597724 GEOLOGIC HAZARD MAP 403597726 REFERENCE AREA MAP 403597736 ALA DATASHEET 403711516 NRCS MAP UNIT DESC 403711667 LAYOUT DRAWING 403748803 INFORMED CONSENT LETTER 403749052 CORRESPONDENCE Total Attach: 32 Files Page 24 of 25Date Run: 6/17/2024 Doc [#403563270] User Group Comment Comment Date OGLA OGDP ID# 486434 and this Form are approved by Commission Order Number 407-3629.06/17/2024 OGLA With concurrence from the operator, an updated Cumulative Impacts Plan was attached.06/17/2024 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. 05/29/2024 OGLA Added LGD comment at Weld County request. Updated information regarding the Final WOGLA order, and uploaded the Final Order as an attachment. 05/28/2024 LGD The Weld County Oil and Gas Energy Department (OGED) submits the following comments: Case number 1041WOGLA23-0064 has been assigned to the Hickory 10-34HZ 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/. 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) Hickory location was reviewed and processed under Weld County Code, ORD2021-17. A pre-application meeting was held prior to application submittal on July 19 2023. Attendees included OGED Staff, KMG Staff and ECMC. The 1041 WOGLA Application was received on December 15, 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 January 23, 2024. OGED did not receive any public comments or any Applications for Intervention. The 1041 WOGLA hearing was held on March 14, 2024. The Hearing Officer considered testimony at the hearing and subsequently approved 1041WOGLA23-0064. The final order was recorded with the Weld County Clerk Recorder on April 10, 2024, at reception number 4953892, and was noticed in the Greeley Tribune on April 12, 2024. Approval and publication of the final order creates a vested property right pursuant to Article 68 of Title 24, C.R.S. 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 approved permit is valid for three (3) years – construction must commence within that 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. 05/28/2024 OGLA The Director has determined this OGDP application is complete. Form pushed to IN PROCESS. 04/10/2024 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. 04/10/2024 OGLA Returned to DRAFT for the following reasons: Attachment corrections. Datafield corrections. 02/12/2024 Total: 8 comment(s) General Comments Page 25 of 25Date Run: 6/17/2024 Doc [#403563270]