COAs

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Facility Type	Facility ID/ API	Facility Name/ Number	Operator Name/ Number	Status	Field Name/ Number	Location	Location ID	Related Facilities
WELL	05-123-47577	BAJA BERG 35-7HZ	KERR MCGEE OIL & GAS ONSHORE LP 47120	PA 4/2/2020	WATTENBERG 90750	WELD 123 SESW 35 2N67W 6	456589

COGIS - Conditions of Approval Results

Type	Source Document	Conditions of Approval
Engineer	Form: (02 ) 401600302 7/9/2018	1) Submit Form 42 electronically to COGCC 48 hours prior to MIRU (spud notice) for the first well activity with a rig on the pad and provide 48 hour spud notice via Form 42 for all subsequent wells drilled on the pad. 2) Comply with Rule 317.j. and provide cement coverage from TD to a minimum of 200' above Niobrara and from 200’ below Shannon to 200’ above Sussex. Verify coverage with cement bond log. 3) Oil-based drilling fluid is to be used only after all fresh water aquifers are covered.
Engineer	Form: (02 ) 401600302 7/9/2018	Bradenhead tests shall be performed according to the following schedule and the Form 17 submitted within 10 days of each test: 1) Within 60 days of rig release and prior to stimulation and 2) If a delayed completion, 6 months after rig release and prior to stimulation. 3) Within 30 days after first production, as reported on Form 5A. If a bradenhead test reports a surface casing pressure greater than 200 psig stimulation is not allowed until the Engineering Supervisor has been consulted.
Engineer	Form: (04 ) 402050750 5/23/2019	1. CIBP will be set at 7000’ with 10 sacks of cement placed on top. A CIBP will be set at 6900’ with two sacks on top. A CIBP will be set at 5700’ with 2 sacks on top. 2. Submit a copy of the sample analysis results to COGCC within 3 months of sampling date. 3. A copy of all logs run on this well must be submitted to COGCC. 4. The bradenhead of this well must be monitored during the offset stimulation, if any communication between the surface casing and the offset stimulation is observed, shut down and contact COGCC.
Engineer	Form: (06 ) 402152077 8/27/2019	Operator shall implement measures to control venting, 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 welfare.
Engineer	Form: (06 ) 402152077 8/27/2019	1) Provide 48 hour notice of plugging MIRU via electronic Form 42. 2) Prior to placing the 1985' plug: verify that all fluid migration (liquid or gas) has been eliminated. If evidence of fluid migration or pressure remains, contact COGCC Engineer for an update to plugging orders. 3) 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 480' or shallower and provide 10 sack plug at surface. 4) Leave at least 100’ of cement in the wellbore for each plug. 5) Properly abandon on-location flowlines as per Rule 1105. File electronic Form 42 once abandonment is complete. Within 30 days of an operator completing abandonment requirements for an off-location flowline or crude oil transfer line, the operator must submit a Flowline Report, Form 44. 6) With the Form 6 SRA operator must provide written documentation which positively affirms each COA has been addressed. 7) After placing the shallowest hydrocarbon isolating plug (4370'), operator must wait a sufficient time to confirm static conditions. If at any time after placing this plug there is evidence of pressure or of fluid migration, contact COGCC engineering before continuing operations.
Engineer	Form: (06 ) 402152077 8/27/2019	If there has not been a reported Bradenhead test within 60 days of plugging this well, prior to starting plugging operations, a Bradenhead test shall be performed. 1) If, before opening the Bradenhead valve, the beginning pressure is greater than 25 psi, sampling is required, and the COGCC engineering staff must be contacted. 2) If pressure remains at the conclusion of the test, or if any liquids were present during the test, sampling is required. 3) If sampling is required contact COGCC engineering for a confirmation of plugging requirements prior to placing any plugs. Sampling shall comply with Operator Guidance - Bradenhead Testing and Reporting Instructions. The Form 17 shall be submitted within 10 days of the test.
Engineer	Form: (06 ) 403638032 12/28/2023	Operator shall implement measures to control venting, 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 welfare.
Engineer	Form: (06 ) 403638032 12/28/2023	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 405.e and 405.I. 2) Prior to placing the 2000’ plug: verify that all fluid migration (liquid and gas) has been eliminated. If evidence of fluid migration or pressure remains, contact ECMC Engineer for an update to plugging orders. 3) After isolation has been verified, pump surface casing shoe plug. If cement is not circulated to surface, shut-in, WOC 4 hours then tag plug – must be at 1833’ or shallower and provide 10 sx plug at the surface. 4) Leave at least 100’ of cement in the wellbore for each plug without mechanical isolation. 5) 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. 6) With the Form 6 SRA operator must provide written documentation which positively affirms each COA listed above has been addressed.

COGIS - Best Management Practice Results

BMP Type	Source Document	Best Management Practices
Drilling/Completion Operations	Form: (02 ) 401600302 8/13/2018	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 ) 401600302 8/13/2018	Anti-Collision: Kerr-McGee will perform an anti-collision evaluation of all active (producing, shut in, or temporarily abandoned) offset wellbores that have the potential of being within one hundred fifty (150) feet of a proposed well prior to drilling operations for the proposed well. Notice shall be given to all offset operators within one hundred fifty (150) feet prior to drilling.
Drilling/Completion Operations	Form: (02 ) 401600302 8/13/2018	317.p Logging Program: One of the first wells drilled on the pad will be logged with Cased-hole Pulsed Neutron Log with Gamma Ray Log the kick-off point into the surface casing. All wells on the pad will have a cement bond log with gamma-ray run on production casing (or on intermediate casing if production liner is run) into the surface casing. The horizontal portion of every well will be logged with a measured-while-drilling gamma-ray log. The Form 5, Completion Report, for each well on the pad will list all logs run in that well and have those logs attached. The Form 5 for each well shall clearly state “No open-hole logs were run” and shall reference the Rule 317.p Exception granted for the well.
Drilling/Completion Operations	Form: (02 ) 401600302 8/13/2018	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 ) 401600302 8/13/2018	604c.(2).I. BOPE Testing for Drilling Operations: BOPEs will be tested upon rig-up and, at a minimum, every 30 days.
Drilling/Completion Operations	Form: (02 ) 401600302 8/13/2018	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 ) 401600302 8/13/2018	604c.(2).L. Drill Stem Tests: No drill stem tests are planned and none will be performed without prior approval from the Director.
Planning	Form: (04 ) 403637151 1/19/2024	Planning Operations are daylight-only; no lighting impacts are anticipated from operations.
Community Outreach and Notification	Form: (04 ) 403637151 1/19/2024	Signs will be placed in conspicuous locations and will include Oxy contact information; the Oxy Stakeholder Relations team will respond to all community member inquiries. The signs will be placed so as not to create a potential traffic hazard
Community Outreach and Notification	Form: (04 ) 403637151 1/19/2024	Courtesy notifications will be sent to all parcel owners with building units within 2,000 feet of the location letting them know about our subsequent well operations and providing contact information for Kerr McGee’s response line and online resources
Wildlife	Form: (04 ) 403637151 1/19/2024	This location was reviewed using a desktop method to review publicly available wildlife data (including CPW & ECMC data) as well as internal wildlife datasets and aerial imagery. All field personnel are trained to identify wildlife risks and raise concerns noticed during operations with the KMOG Health, Safety, and Environment (HSE) department.
Dust control	Form: (04 ) 403637151 1/19/2024	Water will be placed on dirt access roads to mitigate dust as needed.
Noise mitigation	Form: (04 ) 403637151 1/19/2024	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.