COAs

Skip to Main Content

Facility Type	Facility ID/ API	Facility Name/ Number	Operator Name/ Number	Status	Field Name/ Number	Location	Location ID	Related Facilities
WELL	05-123-48937	Guttersen C28-765	NOBLE ENERGY INC 100322	PR 8/1/2023	WATTENBERG 90750	WELD 123 SESW 33 4N64W 6	459550

COGIS - Conditions of Approval Results

Type	Source Document	Conditions of Approval
Engineer	Form: (02) 401795625 11/12/2018	Operator acknowledges the proximity of the listed 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 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. Hanscome C 28-1 (API NO 123-11310)Klein 1 (API NO 123-11828) Thompson 3 (API NO 123-11830)Hanscome C 2 (API NO 123-11925) Thompson 4 (API NO 123-12271)Novacek 1 (API NO 123-12347) Lindsay C 33-2 (API NO 123-13155)Lindsay 33-3 (API NO 123-13156) Lindsay 33-4 (API NO 123-13157)Lindsay 33-8 (API NO 123-13161) Lindsay 33-5 (API NO 123-13165)Lindsay 33-6 (API NO 123-13166) Lindsay 33-7 (API NO 123-13167)Balboa 20-1 (API NO 123-13235) Victor C 29-9 (API NO 123-13359)Victor C 29-16 (API NO 123-13360) Johnson PM C 29-8 (API NO 123-14213)Lindsay C 33-10 (API NO 123-14698) PTF C 32-1 (API NO 123-14878)PTF C 32-8 (API NO 123-14879) Marie D 4-3 (API NO 123-15122)Karch Blue D 4-02 (API NO 123-16137) PTF C 32-9 (API NO 123-14892)
Engineer	Form: (02) 401795625 11/12/2018	1) Submit Form 42 electronically to COGCC 48 hours prior to MIRU (Spud Notice), for the first well/activity on the pad and provide 48 hour spud notice for all subsequent wells drilled on the pad. 2) Comply with Rule 317.j and provide cement coverage from the end of production casing to a minimum of 200' above Niobrara. Verify coverage with cement bond log. 3) Oil-based drilling fluid is to be used only after all aquifers are covered.
Engineer	Form: (02) 401795625 11/12/2018	Bradenhead tests shall be performed and reported 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. 2) 6 months after rig release, prior to stimulation. 3) Within 30 days of first production, as reported on Form 5A.
Permit	Form: (02) 401795625 12/03/2018	COGCC COA: Operator will insure the wellbore beyond the unit boundary setback is physically isolated and is not completed. In the Operator Comments on the Form 5A the operator will (1) report the footages from the section lines of the bottom of the completed interval (2) describe how the wellbore beyond the unit boundary setback is physically isolated and (3) certify that none of the wellbore beyond the setback was completed.
Permit	Form: (02) 403163326 09/14/2022	Operator will insure the wellbore beyond the unit boundary setback is physically isolated and is not completed. In the Operator Comments on the Form 5A the operator will (1) report the footages from the section lines of the bottom of the completed interval (2) describe how the wellbore beyond the unit boundary setback is physically isolated and (3) certify that none of the wellbore beyond the setback was completed.
Engineer	Form: (02) 403163326 09/14/2022	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.
Engineer	Form: (02) 403163326 09/14/2022	1) Comply with Rule 408.j. and provide cement coverage from TD to a minimum of 500' above Niobrara. Verify coverage with a cement bond log. 2) Oil based drilling fluid can only be used after all groundwater has been isolated.
Engineer	Form: (02) 403163326 09/14/2022	Operator acknowledges the proximity of the listed 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 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. Hanscome C 28-1 (API NO 123-11310) Klein 1 (API NO 123-11828) Thompson 3 (API NO 123-11830) Hanscome C 2 (API NO 123-11925) Thompson 4 (API NO 123-12271) Novacek 1 (API NO 123-12347) Lindsay C 33-2 (API NO 123-13155) Lindsay 33-3 (API NO 123-13156) Lindsay 33-4 (API NO 123-13157) Lindsay 33-8 (API NO 123-13161) Lindsay 33-5 (API NO 123-13165) Lindsay 33-6 (API NO 123-13166) Lindsay 33-7 (API NO 123-13167) Balboa 20-1 (API NO 123-13235) Victor C 29-9 (API NO 123-13359) Victor C 29-16 (API NO 123-13360) Johnson PM C 29-8 (API NO 123-14213) Lindsay C 33-10 (API NO 123-14698) PTF C 32-1 (API NO 123-14878) PTF C 32-8 (API NO 123-14879) Marie D 4-3 (API NO 123-15122) Karch Blue D 4-02 (API NO 123-16137) PTF C 32-9 (API NO 123-14892)
Engineer	Form: (04) 404323769 09/03/2025	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 ECMC 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 (2/20/26), 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.

COGIS - Best Management Practice Results

BMP Type	Source Document	Best Management Practices
PROPOSED BMPs	Form: (07 ) 0 1/23/2012	(Approved via sundry 402455877 on 8/19/2020) Open Hole Logging Exception: A cased-hole neutron log with gamma-ray log will be run from the kick-off point into the surface casing. A cement bond log with gamma-ray will be run on the production casing (or intermediate casing if production liner is run). The horizontal portion of the wellbore will be logged with a measured-while-drilling log with gamma-ray. The Form 5, Completion Report, for this well will list all logs run and have those logs attached. The Form 5 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#) in which open-hole logs were run.
Drilling/Completion Operations	Form: (02 ) 401795625 12/4/2018	Anti-collision: Prior to drilling operations, Operator will perform an anti-collision scan of existing offset wells that have the potential of being within close proximity of the proposed well. This anti-collision scan will include definitive MWD or gyro surveys 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 will only be drilled if the anti-collision scan results indicate that there is not a risk for collision, or harm to people or the environment. For the proposed well, upon conclusion of drilling operations, an as constructed gyro survey will be submitted to COGCC with the Form 5.
Drilling/Completion Operations	Form: (02 ) 401795625 12/4/2018	During and Post stimulation: Noble Energy will comply with the COGCC Policy for Bradenhead Monitoring During Hydraulic Fracturing Treatments in the Greater Wattenberg Area dated 5/29/12.
Drilling/Completion Operations	Form: (02 ) 401795625 12/4/2018	One of the first wells drilled on the pad will be logged with open hole Resistivity Log and 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 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 and have those logs attached. The Form 5 for a well without open-hole logs shall clearly state “No open-hole logs were run” and shall clearly identify (by API#, well name & number) the well in which open hole logs were run.
Drilling/Completion Operations	Form: (02 ) 403163326 9/16/2022	Anti-collision: Prior to drilling operations, Operator will perform an anti-collision scan of existing offset wells that have the potential of being within close proximity of the proposed well. This anti-collision scan will include definitive MWD or gyro surveys 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 will only be drilled if the anti-collision scan results indicate that there is not a risk for collision, or harm to people or the environment. For the proposed well, upon conclusion of drilling operations, an as constructed gyro survey will be submitted to COGCC with the Form 5.
Drilling/Completion Operations	Form: (02 ) 403163326 9/16/2022	During and Post stimulation: Noble Energy will comply with the COGCC Policy for Bradenhead Monitoring During Hydraulic Fracturing Treatments in the Greater Wattenberg Area dated 5/29/12.
Drilling/Completion Operations	Form: (02 ) 403163326 9/16/2022	One of the first wells drilled on the pad will be logged with open hole Resistivity Log and 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 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 and have those logs attached. The Form 5 for a well without open-hole logs shall clearly state “No open-hole logs were run” and shall clearly identify (by API#, well name & number) the well in which open hole logs were run.