COAs

Facility Type	Facility ID/ API	Facility Name/ Number	Operator Name/ Number	Status	Field Name/ Number	Location	Location ID	Related Facilities
WELL	05-123-38833	VOGL 13C-35HZ	KERR MCGEE OIL & GAS ONSHORE LP 47120	SI 4/1/2023	WATTENBERG 90750	WELD 123 SWSW 36 3N68W 6	331358

COGIS - Conditions of Approval Results

Type	Source Document	Conditions of Approval
Engineer	Form: (02 ) 400502804 11/24/2013	Operator acknowledges the proximity of the ROCKY MTN COORS GU #1( API# 123-08330), LEE G GOULD JR. UNIT #1 (123-07854), and HOEKSTRA GU #1 (API # 123-07429). wells. Operator agrees to: provide mitigation option 1 or 2 (per the DJ Basin Horizontal Offset Policy) to mitigate the situation, ensure all applicable documentation is submitted based on the selected mitigation option chosen, and submit a Form 42 (“OFFSET MITIGATION COMPLETED” - for the remediated well) stating what appropriate mitigation occurred and that it has been completed, prior to the hydraulic stimulation of this well.
Engineer	Form: (02 ) 400502804 11/24/2013	1) Submit Form 42 electronically to COGCC 48 hours prior to MIRU. 2) Comply with Rule 317.i and provide cement coverage from TD to a minimum of 200' above Niobrara. Verify coverage with cement bond log. 3) Comply with Rule 321. Run and submit Directional Survey from TD to base of surface casing. Ensure that the wellbore complies with setback requirements in commission orders or rules prior to producing the well.
Permit	Form: (02 ) 400502804 12/31/2013	Open hole resistivity and gamma logs shall be run to describe the stratigraphy of the entire well bore and to adequately verify the setting depth of surface casing and aquifer coverage. On a multi-well pad, these open hole logs are only required on one of the first wells drilled on the pad and the Form 5 for every well on the pad shall identify which well was logged.
Permit	Form: (02 ) 400502804 12/31/2013	Operator shall comply with Buffer Zone Move-In, Rig-Up Notice Policy dated 12-16-2013.
Engineer	Form: (04 ) 401998492 4/8/2019	1. Operator shall implement measures to protect health and safety, and to ensure that vapors and odors from well operations do not constitute a nuisance or hazard to public welfare. 2. Prior to starting bradenhead abatement, collect bradenhead and production gas samples for laboratory analysis. Sampling shall comply with Operator Guidance - Bradenhead Testing and Reporting Instructions, Appendix A: Liquid and Gas Sampling. Copies of all final laboratory analytical results shall be provided to the COGCC within three months of collecting the samples. 3. Bradenhead gas is not to be vented to atmosphere; any gas from the Bradenhead will be routed to an enclosed tank and/or combustor. Operator should measure the gas flow to get an estimate of the gas flow from the bradenhead. The abatement program may be used until 03/05/2020 (one year from the first annual bradenhead test). At the conclusion of the year, submit a Sundry that summarizes current well condition and includes the flow rate information and pressure data.
Engineer	Form: (04 ) 402475220 9/2/2020	1. Operator shall implement measures to control venting, to protect health and safety, and to ensure that vapors and odors from well operations do not constitute a nuisance or hazard to public welfare. 2. If a sample has not been collected within the last twelve months collect bradenhead and production gas samples for laboratory analysis. Sampling shall comply with Operator Guidance - Bradenhead Testing and Reporting Instructions, Appendix A: Liquid and Gas Sampling. Copies of all final laboratory analytical results shall be provided to the COGCC within three months of collecting the samples. 3. Operator shall implement measures to get an estimate of the gas flow rate and/or volume from the bradenhead. Prior to next annual bradenhead test, the bradenhead and any intermediate valves should be shut for in 7 to 14 days. During the shut-in period record pressure data to adequately characterize the build-up. This mitigation plan may be used for twelve consecutive months from the date of Form4 submittal. 4. At the conclusion of the twelve months (08/26/2021), conduct a new bradenhead test and submit the Form 17 within ten days of the test and submit a Form 4 Sundry that summarizes current well condition. The sundry should include details of the future plans, sample analysis results, and the flow rate information and pressure data.
Engineer	Form: (04 ) 402789278 8/27/2021	1. Operator will implement measures to control venting, to protect health and safety, and to ensure that vapors and odors from well operations do not constitute a nuisance or hazard to public welfare. 2. Bradenhead gas is not to be vented to the atmosphere; any gas from the Bradenhead will be routed to an enclosed tank and/or combustor. Shut in bradenhead pressure shall not exceed 50 psig. Operator will implement measures to get an estimate of the gas flow rate and/or volume from the bradenhead. 3. Within thirty days of 08-23-2022, conduct a bradenhead test, submit a Form 17, and submit a Form 4 Sundry that summarizes current well condition. The sundry should include details of the future plans, sample analysis interpretation, bradenhead test description, and the flow rate information and pressure data. 4. Shut well in for at least seven days to monitor build up pressures then conduct a new bradenhead test and submit the Form 17 within ten days of the test. 5. If a sample has not been collected from surface casing within the last twelve months collect bradenhead gas samples for laboratory analysis. Sampling will comply with Operator Guidance - Bradenhead Testing and Reporting Instructions, Appendix A: Liquid and Gas Sampling. Copies of all final laboratory analytical results will be provided to the COGCC within three months of collecting the samples.
Engineer	Form: (04 ) 403122327 8/2/2022	1. Operator will implement measures to control venting, to protect health and safety, and to ensure that vapors and odors from well operations do not constitute a nuisance or hazard to public welfare. 2. Bradenhead gas is not to be vented to the atmosphere; any gas from the Bradenhead will be routed to an enclosed tank and/or combustor. Shut in bradenhead pressure shall not exceed 50 psig. Operator will implement measures to get an estimate of the gas flow rate and/or volume from the bradenhead. 3. Within thirty days of 08/01/2023, conduct a bradenhead test, submit a Form 17, and submit a Form 4 Sundry that summarizes current well condition. The sundry should include details of the future plans, sample analysis interpretation, bradenhead test description, and the flow rate information and pressure data. 4. Shut well in for at least seven days to monitor and collect data to characterize build up pressures then conduct a new bradenhead test and submit the Form 17 within ten days of the test. 5. If a sample has not been collected from surface casing within the last twelve months collect bradenhead gas samples for laboratory analysis. Sampling will comply with Operator Guidance - Bradenhead Testing and Reporting Instructions, Appendix A: Liquid and Gas Sampling. Copies of all final laboratory analytical results will be provided to the COGCC within three months of collecting the samples.
Engineer	Form: (04 ) 403514324 9/8/2023	1. Operator will implement measures to control venting, to protect health and safety, and to ensure that vapors and odors from well operations do not constitute a nuisance or hazard to public welfare. 2. Bradenhead gas is not to be vented to the atmosphere; any gas from the Bradenhead will be routed to an enclosed tank and/or combustor. Bradenhead pressure shall not exceed 50 psig. Operator will implement measures to get an estimate of the gas flow rate and/or volume from the bradenhead. 3. Within thirty days of 08/29/2024, conduct a bradenhead test, submit a Form 17, and submit a Form 4 Sundry that summarizes current well condition. The sundry should include details of the future plans, sample analysis interpretation, bradenhead test description, and the flow rate information and pressure data. 4. Shut well in for at least seven days to monitor and collect data to characterize build up pressures then conduct a new bradenhead test and submit the Form 17 within ten days of the test. 5. If a sample has not been collected from surface casing within the last twelve months collect bradenhead gas samples and production gas samples for laboratory analysis. Sampling will comply with Operator Guidance - Bradenhead Testing and Reporting Instructions, Appendix A: Liquid and Gas Sampling. Copies of all final laboratory analytical results will be provided to the COGCC within three months of collecting the samples.
OGLA	Form: (06 ) 403629227 12/29/2023	COA's provided by the operator as Best Management Practices under Technical Detail / Comments: Signage for P&As: Prior to commencing operations, KMG will post signs in conspicuous locations. The signs will indicate plugging and abandonment operations are being conducted, the well name, well, and the Operator’s contact information. Signs will be placed so as not to create a potential traffic hazard. Notifications: Courtesy notifications will be sent to all parcel owners with building units within 1,500 feet of the location letting them know about out plugging and abandonment operations and providing contact information for Kerr McGee's response line and online resources. Noise: Operations will be in compliance with Table 423-1 requirements. Based off the rig sound signature, rig orientation will be considered to reduce noise levels to nearby building units.
OGLA	Form: (06 ) 403629227 12/29/2023	Operator will implement measures to capture, combust, or control emissions to protect health and safety, and to ensure that vapors and odors from well plugging operations do not constitute a nuisance or hazard to public health, welfare and the environment. Due to the proximity of residential building units (RBUs) all blowdown gasses will be controlled.
OGLA	Form: (06 ) 403629227 12/29/2023	Due to proximity to a mapped wetland and/or surface water, operator will use secondary containment for all tanks and other liquid containers. Operator will implement stormwater BMPs and erosion control measures as needed to prevent sediment and stormwater runoff from entering the wetland and surface water.
Engineer	Form: (06 ) 403629227 1/4/2024	Prior to starting plugging operations a Bradenhead test shall be performed if there has not been a reported Bradenhead test within the 60 days immediately preceding the start of plugging operations. 1) If, before opening the Bradenhead valve, the beginning pressure is greater than 25 psi, sampling is required. 2) If pressure remains at the conclusion of the test, or if any liquids were present during the test, sampling is required. The Form 17 shall be submitted within 10 days of the test. Sampling shall comply with Operator Guidance - Bradenhead Testing and Reporting Instructions. If samples are collected, copies of all final laboratory analytical results shall be provided to the ECMC within three (3) months of collecting the samples.
Engineer	Form: (06 ) 403629227 1/4/2024	1) Provide 2 business day notice of plugging MIRU via electronic Form 42, and provide 48 hours Notice of Plugging Operations, prior to mobilizing for plugging operations via electronic Form 42. These are 2 separate notifications, required by Rules 408.e and 408.I. 2) After placing the shallowest hydrocarbon isolating plug (2685'), operator must wait a sufficient time to confirm static conditions. 3) After placing plug at 2685’ assure that all fluid migration has been eliminated by monitoring the well for a minimum of 8 hours before proceeding to the next plug. If at any time after placing this plug there is evidence of pressure or of fluid migration, contact ECMC engineering before continuing operations. 4) Prior to placing the 1240’ plug: verify that all fluid migration (liquid or gas) has been eliminated. If evidence of fluid migration or pressure remains, contact ECMC Engineer for an update to plugging orders. 5) After isolation has been verified, pump plug and displace. If cement is not circulated to surface, shut-in, WOC 4 hours then tag plug – must be at 1090’ or shallower and provide at least 10 sx plug at the surface. 6) After cut and prior to cap, verify isolation by either a 15 minute bubble test or 15 minute optical gas imaging recording. If there is indication of flow contact ECMC Engineering. Provide a statement on the 6SRA which method was used and what was observed. Retain records of final isolation test for 5 years.
Engineer	Form: (06 ) 403629227 1/4/2024	FLOWLINE AND SITE CLOSURE 1) Consistent with Rule 911.a, a Form 27 must be approved prior to cut and cap, conducting flowline abandonment, or removing production equipment. Allow 30 days for Director review of the Form 27; include the Form 27 document number on the Form 44 for offsite flowline abandonment (if applicable) and on the Form 6 Subsequent. 2) Properly abandon flowlines per Rule 1105. If flowlines will be abandoned in place, include with the Form 27: pressure test results conducted in the prior 12 months as well as identification of any document numbers for a ECMC Spill/Release Report, Form 19, associated with the abandoned line.

COGIS - Best Management Practice Results

BMP Type	Source Document	Best Management Practices
Planning	Form: (02 ) 400502804 1/20/2014	604c.(2).E. Multiwell Pads: In order to reduce surface impact, this 2A application is requesting approval to add three new wells to an existing five-well pad.
Planning	Form: (02 ) 400502804 1/20/2014	604c.(2).Q. Guy Line Anchors: Should guy line anchors be left buried for future use, they shall be identified by a bright marker greater than four (4) feet high and no more than one (1) foot east of the guy line anchor.
Planning	Form: (02 ) 400502804 1/20/2014	604c.(2).R. Tank Specifications: Two 500 barrel skid mounted frac tanks will be temporarily placed on-site for use of the pre-spud rig only. One tank will store water and the other will store water based mud.
Planning	Form: (02 ) 400502804 1/20/2014	604c.(2).S. Access Roads: KMG will utilize a lease access road from Weld County Road 26 for drilling operations and maintenance equipment. The road will be properly constructed and maintained to accommodate for local emergency vehicle access. Water will be placed on dirt access roads to mitigate dust. Magnesium chloride will be used as needed on access roads to further abate dust.
Planning	Form: (02 ) 400502804 1/20/2014	604c.(2).V. Development From Existing Well Pads: KMG will locate the three new horizontal wells on the existing location with Location ID # 331358 to reduce the amount of surface disturbance.
Traffic control	Form: (02 ) 400502804 1/20/2014	Traffic Control 604c.(2).D. Traffic Plan: If required by the local government, a traffic plan will be coordinated with the local jurisdiction prior to commencement of operations.
General Housekeeping	Form: (02 ) 400502804 1/20/2014	604c.(2).O. Loadlines: All loadlines shall be bullplugged or capped.
General Housekeeping	Form: (02 ) 400502804 1/20/2014	604c.(2).P. Removal of Surface Trash: A commercial size trash bin for removing debris will be located on site. This bin will be for use by all parties affiliated with the operation.
Storm Water/Erosion Control	Form: (02 ) 400502804 1/20/2014	604c.(2).W. Site-specific Measures: KMG maintains a Stormwater Management Plan that assesses erosion control for every KMG operated location. This well pad will be added to this plan once construction begins. This plan is updated every fourteen (14) days and after any major weather event.
Material Handling and Spill Prevention	Form: (02 ) 400502804 1/20/2014	604c.(2).N. Control of Fire Hazards: KMG and its contractors will employ best management practices during the drilling and production of its wells and facilities and will comply with appropriate COGCC rules concerning safety and fire. KMG will ensure that any material that might be deemed a fire hazard will remain no less than twenty-five (25) feet from the wellhead(s), tanks and separator(s).
Construction	Form: (02 ) 400502804 1/20/2014	604c.(2).G. Berm Construction: Kerr-McGee will create secondary containment by construction of a berm or diversion dike, site grading, or other comparable measures sufficient to further protect the wetlands located 235’ northeast and the ditches located 265’ east and 781’ southwest of the proposed oil and gas location.
Construction	Form: (02 ) 400502804 1/20/2014	604c.(2).M. Fencing Requirements: The completed wellsites will be surrounded with a fence and gate with adequate lock to restrict access to authorized personnel only. KMG personnel will monitor the wellsites regularly upon completion of the wells. Authorized representatives and/or KMG personnel shall be on-site during drilling and completion operations.
Noise mitigation	Form: (02 ) 400502804 1/20/2014	604c.(2).A. Noise: Sound mitigation barriers (hay bales) will be placed along the south-eastern side of the pad location to damper noise during drilling and completions to the nearby residence. Sound surveys that have been conducted on each rig type are utilized to anticipate any additional noise mitigation once a drilling rig is determined.
Drilling/Completion Operations	Form: (02 ) 400502804 1/20/2014	Kerr McGee acknowledges and will comply with the COGCC Policy for Bradenhead Monitoring during Hydraulic Fracturing Treatments in the Greater Wattenberg Area dated May 29, 2012.
Drilling/Completion Operations	Form: (02 ) 400502804 1/20/2014	Prior to drilling operations, Operator may perform an anti-collision review of existing offset wells that have the potential of being within close proximity of the proposed well. This anti-collision review may include MWD or gyro surveys and surface locations of the offset wells with included error of uncertainty per survey instrument, and compared against the proposed wellpath with its respective error of uncertainty. If current surveys do not exist for the offset wells, Operator may have gyro surveys conducted to verify bottomhole location. The proposed well may only be drilled if the anti-collision review results indicate that the risk of collision is sufficiently low as defined by the anti-collision plan, with separation factors greater than 1.5, or if the risk of collision has been mitigated through other means including shutting in wells, plugging wells, increased drilling fluid in the event of lost returns or as is appropriate for the specific situation. In the event of an increased risk of collision, that risk will be mitigated to prevent harm to people, the environment or property. For the proposed well, upon conclusion of drilling operations, an as-constructed directional survey will be submitted to COGCC with the Form 5. At the time of permitting, the operator has identified the following well(s) as being within close proximity of the proposed well(s): VOGL 35-36, HSR VOGL 13-36A
Drilling/Completion Operations	Form: (02 ) 400502804 1/20/2014	Drilling/Completion Operations 604c.(2).B. Closed Loop Drilling System: KMG will use a closed loop or “pitless” system for drilling and fluid management and will not construct a reserve pit.
Drilling/Completion Operations	Form: (02 ) 400502804 1/20/2014	604c.(2).H. BOPE: Our rigs at a minimum will have a double ram with blind and pipe ram; and annular preventer.
Drilling/Completion Operations	Form: (02 ) 400502804 1/20/2014	604c.(2).I. BOPE Testing for Drilling Operations: Upon initial rig-up, BOPEs will be tested at a minimum of every 30 days.
Drilling/Completion Operations	Form: (02 ) 400502804 1/20/2014	604c.(2).J. BOPE for Well Servicing Operations: Blowout prevention equipment will be used on any servicing operations associated with this well. Backup stabbing valves will be used during any future servicing operations during reverse circulation. Valves shall be pressure tested before each well servicing operation using low-pressure air and high-pressure fluid.
Drilling/Completion Operations	Form: (02 ) 400502804 1/20/2014	604c.(2).K. Pit Level Indicators: All tanks (used in lieu of pits) 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 gages are used on tanks utilized for the surface rig.
Drilling/Completion Operations	Form: (02 ) 400502804 1/20/2014	604c.(2).L. Drill Stem Tests: No drill stem tests are planned and none will be performed without prior approval from the director.
Final Reclamation	Form: (02 ) 400502804 1/20/2014	604c.(2).T. Well Site Cleared: 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.
Final Reclamation	Form: (02 ) 400502804 1/20/2014	604c.(2).U. Identification of Plugged and Abandoned Wells: Pursuant to rule 319.a.(5)., once the well has been plugged and abandoned, KMG will identify the location of the wellbore with a permanent monument that will detail the well name and date of plugging.

COGIS DB