COAs

Facility Type	Facility ID/ API	Facility Name/ Number	Operator Name/ Number	Status	Field Name/ Number	Location	Location ID	Related Facilities
WELL	05-123-39593	STEWARD 34N-6HZ	KERR MCGEE OIL & GAS ONSHORE LP 47120	PA 10/16/2024	WATTENBERG 90750	WELD 123 SESW 7 1N65W 6	437542

COGIS - Conditions of Approval Results

Type	Source Document	Conditions of Approval
Permit	Form: (02) 400595847 05/22/2014	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 Drilling Completion Report - Form 5 for every well on the pad shall identify which well was logged.
Engineer	Form: (02) 400595847 05/29/2014	1) Submit Form 42 electronically to COGCC 48 hours prior to MIRU. 2) Comply with Rule 317.i and provide cement coverage from end of 7” casing 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.
Engineer	Form: (02) 400595847 05/29/2014	Operator acknowledges the proximity of the listed wells. Operator agrees to provide mitigation Option 1 or 2 (per the DJ Basin Horizontal Offset Policy), ensure all applicable documentation is submitted , and submit a Form 42(s) (“OFFSET MITIGATION COMPLETED”) for the remediated wells, referencing the API Number of the proposed horizontal well(s) stating what appropriate mitigation occurred and that it has been completed, prior to the hydraulic stimulation of this well. Lela F Thomason 1 (API 123-08421)
Engineer	Form: (05A) 402368976 04/20/2020	Plug is just above the liner top.
Engineer	Form: (04) 403022297 04/25/2022	Effective Apr 30, 2022 this well will be designated inactive and must be properly returned to production, plugged, have an approved 5B or added to a Form 6A list no later than November 1, 2022.
OGLA	Form: (06) 403784821 05/17/2024	Operator committed to the following Best Management Practices under the Technical Detail/ Comments section on the Submit Tab: 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. Wellbore Pressure: In some cases, wellbore pressure drawdown operations may occur approximately 1-2 days prior to Move In Rig Up (MIRU) of the workover rig. This is conducted to allow for reduced time that the workover rig is needed on location. These operations will be conducted in accordance with Form 4 and/or Form 6 requirements. Water: Water will be placed on dirt access roads to mitigate dust as needed. Lighting: Operations are daylight-only; no lighting impacts are anticipated from operations. 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. Environmental Concerns: 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.
OGLA	Form: (06) 403784821 05/17/2024	Due to proximity to a wetland and 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) 403784821 05/20/2024	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) 403784821 05/20/2024	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) 403784821 05/20/2024	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 405.e and 405.I. 2) Prior to placing the 1695’ 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 1567’ 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.
Engineer	Form: (06) 403784821 05/20/2024	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 ) 400595847 6/8/2014	604c.(2).E. Multiwell Pads: In order to reduce surface impact, this application is for a 4-well pad.
Planning	Form: (02 ) 400595847 6/8/2014	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 ) 400595847 6/8/2014	604c.(2).R. Tank Specifications: A geosynthetic liner will be laid under the tanks on this location and a metal containment will be constructed. Storage tanks will be designed, constructed and maintained in accordance with National Fire Protection Association (NFPA) Code 30 (2008 version). KMG will maintain written records to verify proper design, construction and maintenance. All records will be available for inspection by the Director.
Planning	Form: (02 ) 400595847 6/8/2014	604c.(2).S. Access Roads: KMG will utilize a lease access road from CR 10 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 as needed. If feasible, magnesium chloride will also be used as needed on access roads to further abate dust.
Traffic control	Form: (02 ) 400595847 6/8/2014	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 ) 400595847 6/8/2014	604c.(2).O. Loadlines: All loadlines shall be bullplugged or capped.
General Housekeeping	Form: (02 ) 400595847 6/8/2014	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 ) 400595847 6/8/2014	604c.(2).W. Site-Specific Measures: KMG maintains a Stormwater Management Plan that assesses erosion control for every KMG operated location. This location will be added to this plan once construction begins. This site will be inspected every fourteen (14) days during construction activities, every thirty (30) days after construction is completed, and after any major weather event.
Material Handling and Spill Prevention	Form: (02 ) 400595847 6/8/2014	604c.(2).F. Leak Detection Plan: 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.
Material Handling and Spill Prevention	Form: (02 ) 400595847 6/8/2014	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 ) 400595847 6/8/2014	604c.(2).G. Berm Construction: A geosynthetic liner will be laid under the tanks on this location and a metal containment will be constructed. Berms or other secondary containment devices will be constructed around crude oil, condensate, and produced water storage tanks and shall enclose an area sufficient to contain and provide secondary containment for 150% of the largest single tank.
Construction	Form: (02 ) 400595847 6/8/2014	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 ) 400595847 6/8/2014	604c.(2).A. Noise: Pending a safety review after construction of the location, sound mitigation barriers (hay bales) will be placed along the west and northwest sides of the pad location to damper noise during drilling and completions to the nearby residences and to Weld County Road 10.
Drilling/Completion Operations	Form: (02 ) 400595847 6/8/2014	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 ) 400595847 6/8/2014	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. Please see the attached 318A.m letter for a list of well(s) identified by the operator as being within 150 feet of the proposed well(s). If no letter is attached, the operator has not identified any wells as being within 150 feet of the proposed well(s) at the time of permitting.
Drilling/Completion Operations	Form: (02 ) 400595847 6/8/2014	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 ) 400595847 6/8/2014	604c.(2).C. Green Completions: KMG will install Vapor Recovery Unit(s) (VRU) to prevent uncontrolled venting of flash gas. Environmental Control Devices or Volatile Organic Compound Combustors (VOC) will be used to control working and breathing vapor losses for oil and water tanks. Temporary above ground polyethylene water pipelines will deliver water to location operations from larger trunk lines to reduce truck traffic and minimize air pollution.
Drilling/Completion Operations	Form: (02 ) 400595847 6/8/2014	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 ) 400595847 6/8/2014	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 ) 400595847 6/8/2014	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 ) 400595847 6/8/2014	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 gauges are used on tanks utilized for the surface rig.
Drilling/Completion Operations	Form: (02 ) 400595847 6/8/2014	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 ) 400595847 6/8/2014	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 ) 400595847 6/8/2014	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