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COGIS DB
 
Facility TypeFacility ID/
API		Facility Name/
Number		Operator Name/
Number		StatusField Name/
Number		LocationLocation IDRelated Facilities
WELL05-123-52025MOSER
21-7HZ 		KERR MCGEE OIL & GAS ONSHORE LP
47120		WO
4/1/2023		WATTENBERG
90750		WELD  123
NENW 21 3N65W 6		336383View Related
 
COGIS - Conditions of Approval Results
TypeSource DocumentConditions of Approval
EngineerForm: (02 )
403230208
1/17/2023		1) Submit Form 42 electronically to COGCC 2 business days prior to MIRU (spud notice) for the first well activity with a rig on the pad and provide 2 business day spud notice via Form 42 for all subsequent wells drilled on the pad. 2) Comply with Rule 408.j. and provide cement coverage from TD to a minimum of 500' above Niobrara and from 500’ below Sussex to 500’ above Sussex. Verify coverage with a cement bond log.
EngineerForm: (02 )
403230208
1/17/2023		Operator acknowledges the proximity of the listed wells. Operator agrees to: provide mitigation option 1 or 2 (per the Offset Well Evaluation and Hydraulic Fracturing Operator Guidance Document) 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”) stating that appropriate mitigation occurred and that it has been completed, prior to the hydraulic stimulation of this well. 123-07256 J J WARDELL 'B' #1 123-07670 STATE #23 123-10438 B B DRAW H FEDERAL #4-4J 123-10535 B B DRAW H #3-3J 123-12720 ARISTOCRAT #42-4C 123-13323 BEEBE DRAW UPPR #42-9 #4 123-13659 ARISTOCRAT ANGUS #22-4 123-13660 ARISTOCRAT ANGUS #24-4 123-13661 ARISTOCRAT ANGUS #31-4 123-13662 ARISTOCRAT ANGUS #33-4 123-14204 BEEBE DRAW UPRR #41-17 123-14203 BEEBE DRAW UPRR #32-17 123-14205 BEEBE DRAW UPRR #42-17 123-14455 UPRR 22 PAN AM #UNIT "T" #1 123-14736 BEEBE DRAW UPRR #32-9 123-15052 MEGAN H #16-10 123-15076 MEGAN H #16-7 123-15111 MEGAN H #16-2 123-15112 MEGAN H #16-6 123-15114 MEGAN H #16-2J 123-16449 ARISTOCRAT ANGUS #13-4 123-16572 ARISTOCRAT ANGUS #23-4C 123-17032 ARISTOCRAT ANGUS #14-10 123-17136 FEDERAL #12-10 123-17263 HSR-RICHARDS #16-9A 123-17304 HSR-OBORNE #9-5 123-20457 BB Draw Federal #H04-07JI 123-22396 ARISTOCRAT ANGUS FEDERAL #1-2-10
EngineerForm: (02 )
403230208
1/17/2023		Operator acknowledges the proximity of the listed non-operated well. Operator assures that this offset will be remediated per the Offset Well Evaluation and Hydraulic Fracturing Operator Guidance Document Operator using Option 3. Operator will submit a Form 42 (“OFFSET MITIGATION COMPLETED”) stating what appropriate mitigation occurred and that it has been completed, prior to the hydraulic stimulation of this well. 123-13323 BEEBE DRAW UPPR #42-9 #4
EngineerForm: (02 )
403230208
1/17/2023		Operator acknowledges the proximity of the listed non-operated wells. Operator assures that this offset list will be remediated per the Offset Well Evaluation and Hydraulic Fracturing Operator Guidance Document (option 4). Operator will submit a Form 42 (“OFFSET MITIGATION COMPLETED”) stating that appropriate mitigation will be completed, during the hydraulic stimulation of this well. This Form 42 shall be filed 48 hours prior to stimulation. Surface and production casing pressures of this offset well list will be actively monitored during the entire stimulation treatment of this pad. If there is indication of communication between the stimulation treatment and an offset well, treatment will be stopped and COGCC Engineering notified. 123-29341 MOSER #27-21 123-31770 MOSER #H28-30 123-35347 REI H #17-21D 123-44609 Centennial State #G34-612 123-46838 Lory #9N 123-46854 Lory #8N
EngineerForm: (02 )
403230208
1/17/2023		Per COGCC Order 1-232, Bradenhead tests shall be performed according to the following schedule and Form 17 submitted within 10 days of each test: 1) Within 60 days of rig release, prior to stimulation. If any pressure greater than 200 psi is observed or if there is continuous flow, Operator must contact COGCC engineering for approval prior to stimulation. 2) If a delayed completion, a second test is required between 6-9 months after rig release and must be conducted prior to stimulation. If any pressure greater than 200 psi is observed or if there is continuous flow, Operator must contact COGCC engineering for approval prior to stimulation. 3) A post-production test within 60 days after first sales, as reported on the Form 10, Certificate of Clearance.
EngineerForm: (02 )
403460561
7/12/2023		1) Submit Form 42 electronically to COGCC 2 business days prior to MIRU (spud notice) for the first well activity with a rig on the pad and provide 2 business day spud notice via Form 42 for all subsequent wells drilled on the pad. 2) Comply with Rule 408.j. and provide cement coverage from TD to a minimum of 500' above Niobrara and from 500’ below Sussex to 500’ above Sussex. Verify coverage with a cement bond log.
EngineerForm: (02 )
403460561
7/12/2023		Operator acknowledges the proximity of the listed wells. Operator agrees to: provide mitigation option 1 or 2 (per the Offset Well Evaluation and Hydraulic Fracturing Operator Guidance Document) 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”) stating that appropriate mitigation occurred and that it has been completed, prior to the hydraulic stimulation of this well. 123-07256 J J WARDELL 'B' #1 123-07670 STATE #23 123-10438 B B DRAW H FEDERAL #4-4J 123-10535 B B DRAW H #3-3J 123-12720 ARISTOCRAT #42-4C 123-13323 BEEBE DRAW UPPR #42-9 #4 123-13659 ARISTOCRAT ANGUS #22-4 123-13660 ARISTOCRAT ANGUS #24-4 123-13661 ARISTOCRAT ANGUS #31-4 123-13662 ARISTOCRAT ANGUS #33-4 123-14204 BEEBE DRAW UPRR #41-17 123-14203 BEEBE DRAW UPRR #32-17 123-14205 BEEBE DRAW UPRR #42-17 123-14455 UPRR 22 PAN AM #UNIT "T" #1 123-14736 BEEBE DRAW UPRR #32-9 123-15052 MEGAN H #16-10 123-15076 MEGAN H #16-7 123-15111 MEGAN H #16-2 123-15112 MEGAN H #16-6 123-15114 MEGAN H #16-2J 123-16449 ARISTOCRAT ANGUS #13-4 123-16572 ARISTOCRAT ANGUS #23-4C 123-17032 ARISTOCRAT ANGUS #14-10 123-17136 FEDERAL #12-10 123-17263 HSR-RICHARDS #16-9A 123-17304 HSR-OBORNE #9-5 123-20457 BB Draw Federal #H04-07JI 123-22396 ARISTOCRAT ANGUS FEDERAL #1-2-10
EngineerForm: (02 )
403460561
7/12/2023		Operator acknowledges the proximity of the listed non-operated well. Operator assures that this offset will be remediated per the Offset Well Evaluation and Hydraulic Fracturing Operator Guidance Document Operator using Option 3. Operator will submit a Form 42 (“OFFSET MITIGATION COMPLETED”) stating what appropriate mitigation occurred and that it has been completed, prior to the hydraulic stimulation of this well. 123-13323 BEEBE DRAW UPPR #42-9 #4
EngineerForm: (02 )
403460561
7/12/2023		Operator acknowledges the proximity of the listed non-operated wells. Operator assures that this offset list will be remediated per the Offset Well Evaluation and Hydraulic Fracturing Operator Guidance Document (option 4). Operator will submit a Form 42 (“OFFSET MITIGATION COMPLETED”) stating that appropriate mitigation will be completed, during the hydraulic stimulation of this well. This Form 42 shall be filed 48 hours prior to stimulation. Surface and production casing pressures of this offset well list will be actively monitored during the entire stimulation treatment of this pad. If there is indication of communication between the stimulation treatment and an offset well, treatment will be stopped and COGCC Engineering notified. 123-29341 MOSER #27-21 123-31770 MOSER #H28-30 123-35347 REI H #17-21D 123-44609 Centennial State #G34-612 123-46838 Lory #9N 123-46854 Lory #8N
EngineerForm: (02 )
403460561
7/12/2023		Per COGCC Order 1-232, Bradenhead tests shall be performed according to the following schedule and Form 17 submitted within 10 days of each test: 1) Within 60 days of rig release, prior to stimulation. If any pressure greater than 200 psi is observed or if there is continuous flow, Operator must contact COGCC engineering for approval prior to stimulation. 2) If a delayed completion, a second test is required between 6-9 months after rig release and must be conducted prior to stimulation. If any pressure greater than 200 psi is observed or if there is continuous flow, Operator must contact ECMC engineering for approval prior to stimulation. 3) A post-production test within 60 days after first sales, as reported on the Form 10, Certificate of Clearance.
EngineerForm: (04 )
404015173
12/16/2024		1) Provide electronic Form 42 Notice of MIRU 2 business days ahead of operations. 2) 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.
 
COGIS - Best Management Practice Results
BMP TypeSource DocumentBest Management Practices
Drilling/Completion OperationsForm: (02 )
403230208
1/30/2023		KMOG 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 OperationsForm: (02 )
403230208
1/30/2023		Anti-Collision: KMOG will perform an anti-collision evaluation of all active (producing, shut in, or temporarily abandoned) offset wellbores that have the potential of being within 150 feet of a proposed well prior to drilling operations for the proposed well. Notice shall be given to all offset operators within 150 feet prior to drilling.
Drilling/Completion OperationsForm: (02 )
403230208
1/30/2023		Open Hole Logging Exception: One of the first wells drilled on the pad will be logged with cased-hole neutron log with gamma-ray log from 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 (or intermediate casing if a production liner is run_ into the surface casing. The horizontal portion of every well will be logged with a measured-while drilling gamma-ray long. 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 state "Open Hole Logging Exception-No open-hole logs were run" and shall clearly identify the type of log and the well (by API number) in which open-hole logs were run.
Drilling/Completion OperationsForm: (02 )
403460561
7/13/2023		KMOG 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 OperationsForm: (02 )
403460561
7/13/2023		Anti-Collision: KMOG will perform an anti-collision evaluation of all active (producing, shut in, or temporarily abandoned) offset wellbores that have the potential of being within 150 feet of a proposed well prior to drilling operations for the proposed well. Notice shall be given to all offset operators within 150 feet prior to drilling.
Drilling/Completion OperationsForm: (02 )
403460561
7/13/2023		Open Hole Logging Exception: One of the first wells drilled on the pad will be logged with cased-hole neutron log with gamma-ray log from 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 (or intermediate casing if a production liner is run_ into the surface casing. The horizontal portion of every well will be logged with a measured-while drilling gamma-ray long. 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 state "Open Hole Logging Exception-No open-hole logs were run" and shall clearly identify the type of log and the well (by API number) in which open-hole logs were run.
PlanningForm: (04 )
404015173
12/16/2024		Site lighting will be shielded and directed downward and inward toward operations to avoid glare on public roads and nearby Building Units.
Community Outreach and NotificationForm: (04 )
404015173
12/16/2024		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.
Community Outreach and NotificationForm: (04 )
404015173
12/16/2024		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.
WildlifeForm: (04 )
404015173
12/16/2024		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 Kerr McGee's Health, Safety, and Environment (HSE) department.
Dust controlForm: (04 )
404015173
12/16/2024		Water will be placed on dirt access roads to mitigate dust as needed.
Noise mitigationForm: (04 )
404015173
12/16/2024		Noise associated with pipe handling, traffic, and other operational activity will be minimized between 7:00 pm and 7:00 am. Based off the rig sound signature, rig orientation will be considered to reduce noise levels to nearby building units.