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	05-123-50618	Timbro 1717 11H	VERDAD RESOURCES LLC 10651	PR 9/1/2022	WILDCAT 99999	WELD 123 NENE 17 9N59W 6	468967

COGIS - Conditions of Approval Results

Type	Source Document	Conditions of Approval
Engineer	Form: (02 ) 402089834 10/24/2019	1) Submit Form 42 online 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) Provide cement coverage 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 fresh water aquifers are covered. Bradenhead Bradenhead tests shall be performed and reported according to the following schedule and Form 17 submitted within 10 days of each test.: 1) All: Within 60 days of rig release, prior to stimulation. If any pressure greater than 200 psi, must contact COGCC engineer prior to stimulation. 2) Delayed completion: 6 months after rig release, prior to stimulation. If any pressure greater than 200 psi, must contact COGCC engineer prior to stimulation. 3) A post-production test within 60 days after first sales, as reported on the Form 10, Certificate of Clearance.
Permit	Form: (04 ) 402752433 7/26/2021	Operator will ensure 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: (04 ) 402752433 8/24/2021	This sundry makes changes to the approved APD and shall be displayed along with the APD in the doghouse while this well is being drilled.
Permit	Form: (02 ) 402684505 10/21/2021	Operator will ensure 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.
OGLA	Form: (02 ) 402684505 10/28/2021	COA: This oil and gas location is within Mule Deer Winter Concentration Area and Mule Deer Severe Winter Range High Priority Habitats. If drilling operations must take place from December 1 to April 30, Operator will consult with CPW to determine site-specific measures to avoid, minimize, and mitigate adverse impacts to wildlife and the environment.
Engineer	Form: (02 ) 402684505 11/1/2021	Bradenhead Testing 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, must contact COGCC engineer prior to stimulation. 2) If a delayed completion, 6 months after rig release and prior to stimulation. If any pressure greater than 200 psi, must contact COGCC engineer 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 ) 402684505 11/1/2021	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) Provide cement coverage from TD to a minimum of 500' above Niobrara. Verify coverage with cement bond log. Confirm rule and cement coverage with COGCC Area Engineer prior to drilling this well. 3) Oil-based drilling fluid is to be used only after all fresh water aquifers are covered.

COGIS - Best Management Practice Results

BMP Type	Source Document	Best Management Practices
Drilling/Completion Operations	Form: (02 ) 402089834 11/2/2019	Operator will perform anti-collision evaluation of all active (producing, shut-in, of temporarily abandoned) offset wellbores that have the potential of being within 150' feet of the proposed well prior to drilling operations. Notice shall be given to all offset operators prior to drilling.
Drilling/Completion Operations	Form: (02 ) 402089834 11/2/2019	Rule 604.c.I: 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 shall 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 shall 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 ) 402089834 11/2/2019	Alternative Logging Program - 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 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 without open-hole logs shall clearly state "Alternative Logging Program - 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 ) 402684505 11/2/2021	Operator will person anti collision evaluation of all active (producing, shut-in, or temporarily abandoned) offset wellbores that have the potential of being within 150’ of the proposed well prior to drilling operations. Notice shall be given to all offset operators prior to drilling.
Drilling/Completion Operations	Form: (02 ) 402684505 11/2/2021	Upon initial rig up and at least once every 30 days during drilling operations pressure testing of the casing string and each component of the blowout prevention (equipment including flange connections) shall be performed to 70% of working pressure or 70% of the internal yield of casing, whichever is less. Pressure testing shall be conducted and results shall be documented and retained by the operator, for inspection by the Director for a period of 1 year. Activation of the pipe rams for function testing shall be conducted on a daily basis when practicable.
Drilling/Completion Operations	Form: (02 ) 402684505 11/2/2021	Alternative logging program- One of the first wells drilled on the pad will be logged with an Open Hole Resistivity Log and a Gama 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 (MWD) Gamma Ray Log. The Form 5 for each well on the pas will list all logs run and all logs run will be attached. The Form 5 for a well without Open Hole Logs shall clearly state, “Alternative logging program- no Open Hole Logs were run” as well as identifying the API#, well name, and number of the pad well the Open Hole Log was run on.