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	05-123-44943	Regnier Farms 1A-19H-B268	CRESTONE PEAK RESOURCES OPERATING LLC 10633	PR 3/10/2020	WATTENBERG 90750	WELD 123 NWNE 19 2N68W 6	451044

COGIS - Conditions of Approval Results

Type	Source Document	Conditions of Approval
Permit	Form: (02 ) 400798105 5/13/2015	Operator shall comply with Buffer Zone Move-In, Rig-Up Notice Rule 305.h (effective 9/30/2014)
Engineer	Form: (02 ) 400798105 5/20/2015	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 end of 7” casing to a minimum of 200' above Niobrara and from 200’ below the Shannon to 200’ above Sussex. Verify coverage with cement bond log.
Engineer	Form: (02 ) 400798105 5/20/2015	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 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. Regnier Farms B Unit 1 (API 123-11570) Regnier Farms 2 (API 123-11687)
Engineer	Form: (02 ) 400798105 5/26/2016	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 ) 400798105 6/12/2017	The Approved Form 2A permit will be posted at the location during construction, drilling, and completions operations.
Permit	Form: (02 ) 401606136 12/31/2018	If location is not built by 2A expiration 6/12/20, Operator must Refile Form 2A for approval prior to location construction.
Engineer	Form: (02 ) 401606136 1/22/2019	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 Shannon to 200’ above Sussex. Verify coverage with cement bond log. 3) Oil-based drilling fluid is to be used only after all fresh water aquifers are covered.
Engineer	Form: (02 ) 401606136 1/22/2019	Bradenhead tests shall be performed according to the following schedule and the Form 17 submitted within 10 days of each test: 1) Within 60 days of rig release and prior to stimulation and 2) If a delayed completion, 6 months after rig release and prior to stimulation. 3) Within 30 days after first production, as reported on Form 5A. If a bradenhead test reports a surface casing pressure greater than 200 psig stimulation is not allowed until the Engineering Supervisor has been consulted.
Permit	Form: (02 ) 401606136 1/23/2019	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. 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.

COGIS - Best Management Practice Results

BMP Type	Source Document	Best Management Practices
Drilling/Completion Operations	Form: (02 ) 400798105 6/13/2017	Closed-top tanks will utilize backpressure systems that exert a minimum of four (4) ounces of backpressure and a maximum that does not exceed the pressure rating of the tank to facilitate gathering and combustion of tank.
Drilling/Completion Operations	Form: (02 ) 400798105 6/13/2017	Adequate blowout prevention equipment will be used on all well servicing operations.
Drilling/Completion Operations	Form: (02 ) 400798105 6/13/2017	Backup stabbing valves shall 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.
Drilling/Completion Operations	Form: (02 ) 400798105 6/13/2017	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 ) 400798105 6/13/2017	Encana 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 ) 400798105 6/13/2017	Upon initial rig-up and at least once every thirty (30) days during drilling operations thereafter, pressure testing of the casing string and each component of the blowout prevention equipment including flange connections will be performed to seventy percent (70%) of working pressure or seventy percent (70%) of the internal yield of casing, whichever is less. Pressure testing shall be conducted and the documented results will be retained by the operator for inspection by the Director for a period of one (1) year. Activation of the pipe rams for function testing shall be conducted on a daily basis when practicable.
Drilling/Completion Operations	Form: (02 ) 400798105 6/13/2017	One of the first wells drilled on the pad will be logged with cased-hole pulsed neutron log with gamma ray log from TD to 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 shall clearly state "No open-hole logs were run" and shall reference the Rule 317.p Exception granted for the well.
Drilling/Completion Operations	Form: (02 ) 401606136 2/14/2019	Upon initial rig-up and at least once every thirty (30) days during drilling operations thereafter, pressure testing of the casing string and each component of the blowout prevention equipment including flange connections will be performed to seventy percent (70%) of working pressure or seventy percent (70%) of the internal yield of casing, whichever is less. Pressure testing shall be conducted and the documented results will be retained by the operator for inspection by the Director for a period of one (1) year. Activation of the pipe rams for function testing shall be conducted on a daily basis when practicable.
Drilling/Completion Operations	Form: (02 ) 401606136 2/14/2019	Adequate blowout prevention equipment will be used on all well servicing operations.
Drilling/Completion Operations	Form: (02 ) 401606136 2/14/2019	Backup stabbing valves shall 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.
Drilling/Completion Operations	Form: (02 ) 401606136 2/14/2019	No drill stem tests will be performed.
Drilling/Completion Operations	Form: (02 ) 401606136 2/14/2019	Prior to drilling operations, Crestone 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, the 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 ) 401606136 2/14/2019	Crestone 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 ) 401606136 2/14/2019	One of the first wells drilled on the pad will be logged with Cased hole Pulsed Neutron Log with Gamma Ray Log from the kick-off point to 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 in that well and have those logs attached. The Form 5 for each well shall clearly state “No open-hole logs were run” and shall reference the Rule 317.p Exception granted for the well.