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	05-001-09966	Seltzer LD 21-032HNX	PDC ENERGY INC 69175	PR 4/1/2022	WATTENBERG 90750	ADAMS 001 NWNE 4 1S67W 6	320515

COGIS - Conditions of Approval Results

Type	Source Document	Conditions of Approval
Engineer	Form: (02) 400924024 08/01/2016	1) Bradenhead test shall be performed within 60 days of rig release and prior to stimulation. Test results shall be submitted on Form 17 within 10 days of test. 2) Bradenhead test shall be performed between 6 and 7 months after rig release and shall be submitted on Form 17 within 10 days of test. 3) Bradenhead test shall be performed within 30 days of First Production as reported on Form 5A and shall be submitted on Form 17 within 10 days of test.
Engineer	Form: (02) 400924024 08/01/2016	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 Sussex to 200’ above Sussex. Verify coverage with cement bond log.
Permit	Form: (02) 400924024 08/16/2016	This Permit to Drill is approved subject to all the BMPs and COAs on the most recently approved Form 2A and any subsequently approved Form 4 for the Oil and Gas Location (Location ID #320515). The most recently approved Form 2A and any subsequent Form 4s containing applicable COAs for this location shall be posted onsite during construction, drilling, and completions operations.
Engineer	Form: (02) 401491099 09/15/2018	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 Sussex to 200’ above Sussex. Verify coverage with cement bond log. 3) Oil-based drilling fluid is to be used only after setting surface casing. 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. If any pressure greater than 200 psi, must contact COGCC engineer prior to stimulation. 2) 6 months after rig release, prior to stimulation (delayed completions). 3) Within 30 days of first production, as reported on Form 5A.
Permit	Form: (02) 401491099 09/24/2018	If conductors are preset, Operator shall comply with Notice to Operators: Procedures for Preset Conductors (dated September 1, 2016, revised October 6, 2016).
Permit	Form: (02) 401491099 09/24/2018	Operator shall comply with Notice to Operators: Interim Reclamation Procedures for Delayed Operation (dated January 5, 2017).
Engineer	Form: (04) 402022955 04/13/2020	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. 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, 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.
Engineer	Form: (04) 402022955 04/13/2020	Shut in bradenhead pressure shall not exceed 50 psig.
Engineer	Form: (04) 402422603 07/28/2020	Prior to considering annual testing, perform a Bradenhead test in 6 months (10/22/2020) and report the results on a Form 17 in 10 days.
Engineer	Form: (04) 402742571 07/12/2021	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. Bradenhead gas is not to be vented to the atmosphere; any gas from the Bradenhead will be routed to the specified abatement system. Shut in bradenhead pressure shall not exceed 50 psig. Operator shall implement measures to get an estimate of the gas flow rate and/or volume from the bradenhead. 3. Within thirty days of 11/30/2021, submit a Form 4 Sundry that summarizes current well condition. The sundry should include details of the future plans, sample analysis interpretation, bradenhead test description, and the flow rate information and pressure data. 4. Shut well in for at least seven days to monitor build up pressures then conduct a new bradenhead test and submit the Form 17 within ten days of the test. 5. If a sample has not been collected from surface casing within the last twelve months collect bradenhead 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.
Engineer	Form: (04) 403294943 01/19/2023	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. Bradenhead gas is not to be vented to the atmosphere; any gas from the Bradenhead will be routed to the specified abatement system. Shut in bradenhead pressure shall not exceed 50 psig. Operator shall implement measures to get an estimate of the gas flow rate and/or volume from the bradenhead. 3. Within thirty days of 07/19/2023, submit a Form 4 Sundry that summarizes current well condition. The sundry should include details of the future plans, sample analysis interpretation, bradenhead test description, and the flow rate information and pressure data. 4. Shut well in for at least seven days to monitor build up pressures then conduct a new bradenhead test and submit the Form 17 within ten days of the test. 5. If a sample has not been collected from surface casing within the last twelve months collect bradenhead 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.
Engineer	Form: (04) 403791344 05/16/2024	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. Bradenhead gas is not to be vented to the atmosphere; any gas from the Bradenhead will be routed to the specified abatement system. Shut in bradenhead pressure shall not exceed 50 psig. Operator shall implement measures to get an estimate of the gas flow rate and/or volume from the bradenhead. 3. Within thirty days of 12/08/2024, submit a Form 4 Sundry that summarizes current well condition. The sundry should include details of the future plans, sample analysis interpretation, bradenhead test description, and the flow rate information and pressure data. 4. Shut well in for at least seven days to monitor build up pressures then conduct a new bradenhead test and submit the Form 17 within ten days of the test. 5. If a sample has not been collected from surface casing within the last twelve months collect bradenhead 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 ECMC within three months of collecting the samples.
Engineer	Form: (04) 403994022 11/14/2024	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. Bradenhead gas is not to be vented to the atmosphere; any gas from the Bradenhead will be routed to the specified abatement system. Shut in bradenhead pressure shall not exceed 50 psig. Operator shall implement measures to get an estimate of the gas flow rate and/or volume from the bradenhead. 3. Within thirty days of 10/31/2025, submit a Form 4 Sundry that summarizes current well condition. The sundry should include details of the future plans, sample analysis interpretation, bradenhead test description, and the flow rate information and pressure data. 4. Shut well in for at least seven days to monitor build up pressures then conduct a new bradenhead test and submit the Form 17 within ten days of the test. 5. If a sample has not been collected from surface casing within the last twelve months collect bradenhead 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 ECMC within three months of collecting the samples.
Engineer	Form: (04) 404385888 10/13/2025	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. Bradenhead gas is not to be vented to the atmosphere; any gas from the Bradenhead will be routed to the specified abatement system. Shut in bradenhead pressure shall not exceed 50 psig. Operator shall implement measures to get an estimate of the gas flow rate and/or volume from the bradenhead. 3. Within thirty days of 10/13/2026, submit a Form 4 Sundry that summarizes current well condition. The sundry should include details of the future plans, sample analysis interpretation, bradenhead test description, and the flow rate information and pressure data. 4. Shut well in for at least seven days to monitor build up pressures then conduct a new bradenhead test and submit the Form 17 within ten days of the test. 5. If a sample has not been collected from surface casing within the last twelve months collect bradenhead 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 ECMC within three months of collecting the samples.

COGIS - Best Management Practice Results

BMP Type	Source Document	Best Management Practices
Planning	Form: (02 ) 400924024 8/22/2016	604.c.(2)J.i Blowout Prevention Equipment (“BOPE”): A double ram and annular preventer will be used during drilling. Stabbing valves shall be installed in the event of reverse circulation and shall be prior tested with low and high pressure fluid.
Planning	Form: (02 ) 400924024 8/22/2016	604.c.(2)J.ii Backup stabbing valves will be required on well servicing operations during reverse circulation. Valves shall be pressure tested before each well servicing operation using both low-pressure air and high-pressure fluid.
Construction	Form: (02 ) 400924024 8/22/2016	604.c.(2).Q. All guy line anchors left buried for future use shall be identified by a marker of bright color not less than four (4) feet in height and not greater than one (1) foot east of the guy line anchor.
Drilling/Completion Operations	Form: (02 ) 400924024 8/22/2016	Anti-collision: Operator 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 prior to drilling.
Drilling/Completion Operations	Form: (02 ) 400924024 8/22/2016	604.c.(2)L. Closed chamber drill stem tests shall be allowed. All other drill stem tests shall require approval by the Director.
Drilling/Completion Operations	Form: (02 ) 400924024 8/22/2016	Operator acknowledges and will comply with COGCC policy for Bradenhead Monitoring during Hydraulic Fracturing treatments in the Greater Wattenberg Area dated May 29, 2012.
Drilling/Completion Operations	Form: (02 ) 400924024 8/22/2016	317.p 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 ) 401491099 9/25/2018	Conventional drill stem tests will not be conducted on DJ Basin horizontal wells currently being executed or planned by GWOC. If plans change in the future a well specific drill stem testing plan will be prepared for that particular well. Note that GWOC may elect to use one of several available wireline deployed tools for the purpose of measuring down hole formation pressures and/or collecting down hole fluid samples from the target formation(s) of a particular well.
Drilling/Completion Operations	Form: (02 ) 401491099 9/25/2018	GWOC shall identify the location of the P&A wellbore with a permanent monument as specified in Rule 319.a.(5). The operator shall also inscribe or imbed the well number and date of plugging upon the permanent monument. P&A wellbores shall be cutoff well below ground surface in agricultural areas to provide for landowners to safely farm the reclaimed well area.
Drilling/Completion Operations	Form: (02 ) 401491099 9/25/2018	Prior to drilling operations, GWOG 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 well path with its respective error of uncertainty. If current surveys do not exist for the offset wells, Operator may have gyro surveys conducted to verify bottom hole 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.
Drilling/Completion Operations	Form: (02 ) 401491099 9/25/2018	GWOG shall obtain signed written consent for any portion of the proposed wellbore’s treated interval within 150’ of an existing (producing, Shut-in, or temporarily abandoned) or permitted oil and gas well’s treated interval belonging to another operator prior to completion of the well.
Drilling/Completion Operations	Form: (02 ) 401491099 9/25/2018	A BOPE with a minimum pressure rating of 3,000 psi will be utilized. At a minimum it will consist of 2 ram preventers and 1 annular preventer. The blind rams will be positioned below the pipe rams. A backup system of pressure control will be onsite consisting of at a minimum 1,000 psi accumulator (backup pressure). Accumulator is tested to 1,000 psi. Operator may use fixed sized pipe rams matching the tubular size. The annular preventer will be pressure tested to 250 psi low and 2,000 psi high for 10 minutes each. The ram preventers will be tested to 250 psi low and 2,500 psi high for 10 minutes each. All remaining well control equipment will be tested to 250 psi low and 2,500 psi high for 10 minutes each. The pressure tests will be conducted when the equipment is first installed and every 30 days thereafter. Pipe rams and blind rams will be function tested before every well service operation. Annual BOP inspections and pressure tests will be performed by the service company and will be charted & retained for 1 year. Backup stabbing valves shall be used on operations that require reverse circulation. Valves will be pressure tested before each well service operation in low pressure and high pressure range. The GWOC onsite representative will be certified in Well Control Operations by a Well-Cap certified training service.
Drilling/Completion Operations	Form: (02 ) 401491099 9/25/2018	GWOC 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 ) 401491099 9/25/2018	One of the first wells drilled on the pad will be logged with an open-hole Resistivity 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 (intermediate casing or production liner if run) to the surface casing. The horizontal portion of every well will be logged with a MWD/GR 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 an open hole log shall clearly state “No open-hole logs were run” and shall clearly identify (by API#, well name and number) the well in which open-hole logs were run.