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COGIS DB

 
Facility TypeFacility ID/
API
Facility Name/
Number
Operator Name/
Number
StatusField Name/
Number
LocationLocation IDRelated Facilities
WELL05-001-10065Prairie LE
17-019HC
PDC ENERGY INC
69175
PR
8/26/2021
WATTENBERG
90750
BRIGHTON/ADAMS  001
SWSW 20 1S66W 6
450942View Related
 
COGIS - Conditions of Approval Results
TypeSource DocumentConditions of Approval
EngineerForm: (02 )
401179884
3/12/2017
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.
EngineerForm: (02 )
401179884
3/12/2017
1) Submit Form 42 electronically to COGCC 48 hours prior to MIRU 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.i. and provide cement coverage from TD to a minimum of 200' above Niobrara. Verify coverage with cement bond log.
EngineerForm: (02 )
402297023
10/30/2020
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.
EngineerForm: (02 )
402297023
10/30/2020
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 500’ 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.
PermitForm: (02 )
402297023
1/7/2021
If location is not built by 2A expiration 08/19/2023, Operator must Refile Form 2A for approval prior to location construction.
PermitForm: (02 )
402297023
1/7/2021
Drilling Beyond the Unit Boundary Setback: 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.
EngineerForm: (04 )
403239888
11/28/2022
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 10/10//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.
EngineerForm: (04 )
403882423
8/9/2024
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 8/09/2025, 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.
 
COGIS - Best Management Practice Results
BMP TypeSource DocumentBest Management Practices
ConstructionForm: (02 )
401179884
6/2/2017
Fencing: The wellsite will be fenced if requested by the Surface Owner.
Noise mitigationForm: (02 )
401179884
6/2/2017
Noise Mitigation: A background noise study will be done prior to drilling and the appropriate sound wall design will be chosen to meet or exceed COGCC noise requirements.
Odor mitigationForm: (02 )
401179884
6/2/2017
Odor Control: Ward will comply with Rule 805 and Department of Public Health and Environment, Air Quality Control Commission, Regulation No. 2 Odor Emission, 5 C.C.R. 1001-4, Regulation No. 3 (5 C.C.R. 1001-5), and Regulation No. 7 Section XVII.B.1 (a-c) and Section XII. Ward will utilize Emission Control Devices to reduce odor emissions during production.
Drilling/Completion OperationsForm: (02 )
401179884
6/2/2017
Visual Mitigation: Pursuant to Rule 804, the tank battery shall be painted in uniform, non-contrasting, non-reflective color tones with the colors matched to but slightly darker than the surrounding landscape. Light sources during all phases of operations will be directed downwards and away from occupied structures. Permanent lighting will be installed around the facility to allow both the operator and haulers to conduct safe operations at night. All lights will be directed down toward the location or shielded so no light pollution leaves the facility.
Drilling/Completion OperationsForm: (02 )
401179884
6/2/2017
Closed Loop System: Closed Loop System will be used for drilling and fluid management. No reserve pit will be used.
Drilling/Completion OperationsForm: (02 )
401179884
6/2/2017
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 OperationsForm: (02 )
401179884
6/2/2017
Green Completions: Emission Control Systems. Green Completions: Test separators and associated flow lines and sand traps shall be installed on-site to accommodate Green completion techniques pursuant to COGCC Rules. Ward will utilize ECDswith adequate capacity, will be flanged to route gas to other or permanent oxidizing equipment and shall be provided with the equipment needed to maintain combustions where noncombustible gases are present.
Drilling/Completion OperationsForm: (02 )
401179884
6/2/2017
BOPE Testing: Upon initial rig-up and once every 30 days during drilling operations, pressure testing of the casing string and each component of the BOPE will be performed to 70% of working pressure or 70% of the internal yield of the casing, whichever is less.
Drilling/Completion OperationsForm: (02 )
401179884
6/2/2017
BOPE for well servicing operations: Adequate blowout prevention equipment will be used on any servicing operations associated with this well. Backup stabbing valves shall be required on well servicing operations during reverse circulation. Valves will be pressure tested before each well servicing operation using both low-pressure and high-pressure fluid.
Drilling/Completion OperationsForm: (02 )
401179884
6/2/2017
BOPE: Ward will utilize drilling rigs with a minimum of a double ram and annular preventer
Drilling/Completion OperationsForm: (02 )
401179884
6/2/2017
Drill Stem Tests: Drill Stem Tests are not anticipated for this location.
Drilling/Completion OperationsForm: (02 )
401179884
6/2/2017
Pit Level Indicators: Pit Level Indicators will not be needed as no pits will be used on location
Drilling/Completion OperationsForm: (02 )
401179884
6/2/2017
Anti-Collision: Ward 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 will be given to all offset operators within 150 feet prior to drilling.
Drilling/Completion OperationsForm: (02 )
402297023
1/10/2021
Closed Loop Drilling – Pit Restrictions Rule 604.c.(2)B. Great Western Operating Company, LLC (GWOC) will be utilizing a closed loop drilling system.
Drilling/Completion OperationsForm: (02 )
402297023
1/10/2021
Drill stem tests (Rule 604.c.(2)L Conventional drill stem tests will not be conducted on DJ Basin horizontal wells currently being executed or planned by Great Western. If plans change in the future a well specific drill stem testing plan will be prepared for that particular well. Note that GREAT WESTERN 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 OperationsForm: (02 )
402297023
1/10/2021
Wellbore Collision Prevention – Rule 317.r Prior to drilling operations, Great Western 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 OperationsForm: (02 )
402297023
1/10/2021
Stimulation Setback – Rule 317.s Great Western 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 OperationsForm: (02 )
402297023
1/10/2021
Bradenhead Monitoring Great Western 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 )
402297023
1/10/2021
Multi Well Open-Hole Logging – Rule 317.p 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 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 state “Alternative Logging Program - 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.