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COGIS DB
 
Facility TypeFacility ID/
API		Facility Name/
Number		Operator Name/
Number		StatusField Name/
Number		LocationLocation IDRelated Facilities
WELL05-123-38390XCEL
12N-22HZ 		KERR MCGEE OIL & GAS ONSHORE LP
47120		PR
11/1/2025		WATTENBERG
90750		WELD  123
SWSW 27 1N67W 6		428011View Related
 
COGIS - Conditions of Approval Results
TypeSource DocumentConditions of Approval
PermitForm: (02)
400476155
09/23/2013		Operator must meet water well testing requirements per Rule 318A.
EngineerForm: (02)
400476155
10/11/2013		1)Note surface casing setting depth change from 843’ to 1025’. Increase cement coverage accordingly and cement to surface. 2)Provide notice of MIRU via an electronic Form 42. 3)Comply with Rule 317.i and provide cement coverage from the 7” casing TD to a minimum of 200' above the Niobrara and from 200’ below Sussex to 200’ above Sussex. Verify coverage with a cement bond log. 4)Operator acknowledges the proximity of the UPRR 42 PAN AM K 1 (API# 123-07792), Grenemeyer Wagner C Unit 1 (API #123-10492), and the UPRR 42 Pan AM GU AM 1 (API #123-09215) wells. Operator agrees to: provide mitigation option 1, 2 or 3 (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 (“OTHER – AS SPECIFIED BY PERMIT CONDITION”) stating what appropriate mitigation occurred and that it has been completed, prior to the hydraulic stimulation of this well.
EngineerForm: (04)
402301302
05/07/2020		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. Prior to starting bradenhead mitigation, 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 initial estimate of the gas flow rate and/or volume from the bradenhead. During the shut-in period record pressure data to adequately characterize the build-up. 4. This mitigation plan may be used for six consecutive months from the approved sundry date. At the conclusion of the six months, 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 and the flow rate information and pressure data.
EngineerForm: (04)
402560081
01/04/2021		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. Prior to starting bradenhead abatement, if a sample has not been collected within the last twelve months collect bradenhead 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. 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 will implement measures to get an initial estimate of the gas flow rate and/or volume from the bradenhead. The abatement program may be used for twelve consecutive months. 4. Operator will submit a Form 42 (“OTHER”) stating that “bradenhead abatement program has started.” 5. At the conclusion of the twelve months, 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, flow rate information, pressure data and a discussion of the sample analysis.
EngineerForm: (04)
402560081
01/04/2021		Shut in bradenhead pressure shall not exceed 50 psig.
EngineerForm: (04)
402618912
03/18/2021		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. Prior to starting bradenhead abatement, if a sample has not been collected within the last twelve months collect bradenhead 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. 3. Operator will implement measures to get an initial estimate of the gas flow rate and/or volume from the bradenhead. 4. Operator will submit a Form 42 (“OTHER”) stating that “bradenhead abatement program has started.” 5. Within thirty days of 04-Sep-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, flow rate information, pressure data and a discussion of the sample analysis. 6. Shut in bradenhead pressure shall not exceed 50 psig.
EngineerForm: (04)
402737669
07/09/2021		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. Prior to starting bradenhead mitigation, if a sample has not been collected within the last twelve months collect bradenhead 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. 3. Operator will implement measures to get an initial estimate of the gas flow rate and/or volume from the bradenhead. During the shut-in period record pressure data to adequately characterize the build-up. This mitigation plan may be used for six consecutive months from the date test reported on the Form 17. 4. At the conclusion of the six months (16-Dec-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 interpretation, and the flow rate information and pressure data. Shut in bradenhead pressure shall not exceed 50 psig.
EngineerForm: (04)
402882130
12/01/2021		All placed cement shall be verified with a CBL and submitted to COGCC on a Form4 sundry. Submit successful pressure tests with follow up sundry.
 
COGIS - Best Management Practice Results
BMP TypeSource DocumentBest Management Practices
PlanningForm: (02 )
400476155
11/9/2013		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.
PlanningForm: (02 )
400476155
11/9/2013		604c.(2).S. Access Roads: KMG will utilize the lease access road from WCR 4 for drilling operations and maintenance equipment. The road will be properly constructed and maintained to accommodate for local emergency vehicle access.
PlanningForm: (02 )
400476155
11/9/2013		604c.(2).V. Development From Existing Well Pads: KMG is developing three new reservoirs on an existing six-well well pad.
PlanningForm: (02 )
400476155
11/9/2013		Kerr-McGee Oil & Gas Onshore LP (“KMG”) respectfully requests the Director to waive Rule 318A.m for this well. KMG is the operator of the encroached upon well(s).
PlanningForm: (02 )
400476155
11/9/2013		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: 1 UPRR 42 PAN AM AU, DRY CREEK 5-27, XCEL 12-27, XCEL 13-27
Traffic controlForm: (02 )
400476155
11/9/2013		604c.(2).D. Traffic Plan: KMG will utilize Weld COuntry roads to access the pad. No additional traffic control was required and/or requested.
General HousekeepingForm: (02 )
400476155
11/9/2013		604c.(2).O. Loadlines: All loadlines shall be bullplugged or capped.
General HousekeepingForm: (02 )
400476155
11/9/2013		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 ControlForm: (02 )
400476155
11/9/2013		604c.(2).W. Site-specific Measures: KMG maintains a Stormwater Management Plan that includes each wellsite location that assesses erosion control for each well pad. This plan is updated every fourteen (14) days and after any major weather event.
Material Handling and Spill PreventionForm: (02 )
400476155
11/9/2013		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 PreventionForm: (02 )
400476155
11/9/2013		604c.(2).N. Control of Fire Hazards: KMG will ensure that any material that might be deemed a fire hazard will be will remain no less than twenty-five (25) feet from the wellhead(s), tanks and separator(s).
ConstructionForm: (02 )
400476155
11/9/2013		604c.(2).E. Multiwell Pads: This application is part of a nine-well pad (six existing, three new).
ConstructionForm: (02 )
400476155
11/9/2013		604c.(2).G. Berm Construction: A geosynthetic liner will be laid under the tanks on this location and a metal containment will be constructed.
ConstructionForm: (02 )
400476155
11/9/2013		604c.(2).M. Fencing Requirements: Per specific landowner request, no fencing will be installed to avoif interfering with farming operations.
ConstructionForm: (02 )
400476155
11/9/2013		604c.(2).R. Tank Specifications: Condensate storage tanks will be designed, constructed and maintained pursuant to code 30 of the National Fire Protection Association. KMG will maintain written records to verify proper design.
Noise mitigationForm: (02 )
400476155
11/9/2013		604c.(2).A. Noise: A sound mitigation burier (hay bales) will be placed on the north and west side of the pad location to damper noise during drilling and completions to the nearby Weld County Road 4 and 19. Sound surveys have been conducted on each rig type; which is utilized to anticipate any additional noise mitigation if necessary.
Drilling/Completion OperationsForm: (02 )
400476155
11/9/2013		604c.(2).B. Closed Loop Drilling System: A closed loop drilling system will be utilized during drilling of the wells on this location.
Drilling/Completion OperationsForm: (02 )
400476155
11/9/2013		604c.(2).C. Green Completions: KMG will install Vapor Recovery Unit(s) (VRU’s) to prevent uncontrolled venting of flash gas. Environmental Control Devices (ECD) will be used to control working and breathing vapor losses for oil and water tanks. Produced oil and gas will be piped off of location to minimize air pollution.
Drilling/Completion OperationsForm: (02 )
400476155
11/9/2013		604c.(2).H. BOPE: Our rigs at a minimum will have a double ram with blind and pipe ram; and annular preventer.
Drilling/Completion OperationsForm: (02 )
400476155
11/9/2013		604c.(2).I. BOPE Testing for Drilling Operations: Upon initial rig-up, BOPE’s will be tested at a minimum of every 30-days.
Drilling/Completion OperationsForm: (02 )
400476155
11/9/2013		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 OperationsForm: (02 )
400476155
11/9/2013		604c.(2).K. Pit Level Indicators: All mud pits contain pit level monitors with Electronic Drilling Recorders (EDR) KMG uses an Electronic Drilling Recorder (EDR) with pit level monitor(s) and alarm(s) for production rigs. Basic level gages are used on pits utilized for the surface rig.
Drilling/Completion OperationsForm: (02 )
400476155
11/9/2013		604c.(2).L. Drill Stem Tests: No drill stem tests will be performed without prior approval from the director.
Drilling/Completion OperationsForm: (02 )
400476155
11/9/2013		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.
Final ReclamationForm: (02 )
400476155
11/9/2013		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.
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