Skip to Main Content

COGIS DB
 
Facility TypeFacility ID/
API		Facility Name/
Number		Operator Name/
Number		StatusField Name/
Number		LocationLocation IDRelated Facilities
WELL05-123-39578Winder
10 		EXTRACTION OIL & GAS INC
10459		PR
5/4/2017		WATTENBERG
90750		WELD  123
NENE 9 6N67W 6		430438View Related
 
COGIS - Conditions of Approval Results
TypeSource DocumentConditions of Approval
EngineerForm: (02 )
400588715
5/14/2014		Operator acknowledges the proximity of the listed non-producing wells. Operator agrees to provide mitigation Option 3 (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. Hill 6-1 (API #123-11081) Brunner 1 (API #123-10871)
EngineerForm: (02 )
400588715
5/14/2014		1) Submit Form 42 electronically to COGCC 48 hours prior to MIRU. 2) Comply with Rule 317.i and provide cement coverage from end of 7” casing to a minimum of 200' above Niobrara. Verify coverage with cement bond log. 3) Comply with Rule 321. Run and submit Directional Survey from TD to base of surface casing. Ensure that the wellbore complies with setback requirements in commission orders or rules prior to producing the well.
PermitForm: (02 )
400588715
5/28/2014		Open hole resistivity and gamma logs shall be run to describe the stratigraphy of the entire well bore and to adequately verify the setting depth of surface casing and aquifer coverage. On a multi-well pad, these open hole logs are only required on one of the first wells drilled on the pad and the Drilling Completion Report - Form 5 for every well on the pad shall identify which well was logged.
PermitForm: (02 )
400588715
5/28/2014		Operator shall comply with Buffer Zone Move-In, Rig-Up Notice Policy dated 12-16-2013.
EngineerForm: (04 )
400866982
8/6/2015		1) Submit Form 42 electronically to COGCC 48 hours prior to MIRU. 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. 3) Comply with Rule 321. Run and submit Directional Survey from TD to base of surface casing. Ensure that the wellbore complies with setback requirements in commission orders or rules prior to producing the well.
EngineerForm: (02 )
401002718
5/20/2016		Operator acknowledges the proximity of the listed non-producing well(s). Operator agrees to provide mitigation Option 3 (per the DJ Basin Horizontal Offset Policy), ensure all applicable documentation is submitted, and submit Form 42(s) (“OFFSET MITIGATION COMPLETED”) for the remediated well(s), 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. Hill #6-1 (API #123-11081) Brunner 1 (API #123-10871)
EngineerForm: (02 )
401002718
5/20/2016		Bradenhead tests shall be performed on all wells on this pad on the following schedule: 1) Within 60 days of rig release and prior to stimulation (wells already stimulated excepted). 2) Between 6 and 7 months after rig release or prior to stimulation. 3) Within 30 days of First Production as reported on Form 5A (wells already producing shall be tested within 30 days). Test results shall be submitted on Form 17 within 10 days of test.
EngineerForm: (02 )
401002718
5/20/2016		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 for each subsequent well drilled on the pad. 2) Comply with Rule 317.j and provide cement coverage from TD to a minimum of 200' above the Niobrara. Verify coverage with cement bond log. 3) Oil based drilling fluid is to be used only after all aquifers are covered.
PermitForm: (02 )
401002718
5/23/2016		Approval of this refile APD does not provide relief from compliance with the COGCC Reclamation Rules.
EngineerForm: (04 )
402043855
6/17/2019		1. Operator shall implement measures 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 abatement, 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. Bradenhead gas is not to be vented to atmosphere; any gas from the Bradenhead will be routed to an enclosed tank and/or combustor. Operator should measure the gas flow to get an estimate of the gas flow from the bradenhead. The abatement program may be used for six months. At the conclusion of the six months, submit a Sundry that summarizes current well condition and includes the flow rate information and pressure data.
EngineerForm: (04 )
402447362
7/22/2020		Bradenhead test on 6/15/2020 had 0 psig and is now in compliance with Order 1-232. This well was never put on an official blowdown program, it was approved but Extraction never did the work. Return well to annual testing.
 
COGIS - Best Management Practice Results
BMP TypeSource DocumentBest Management Practices
PlanningForm: (02 )
400588715
6/8/2014		Multi-well Pads are located in a manner which allows for resource extraction while maintaining the highest distances possible from the offsetting residential areas and complies with the wishes of the surface owner.
PlanningForm: (02 )
400588715
6/8/2014		Site-Specific Measures - This location has been designed to mitigate the visual impacts to the surrounding properties.
PlanningForm: (02 )
400588715
6/8/2014		Fencing - A meeting with the surface owner will determine the fencing plan
PlanningForm: (02 )
400588715
6/8/2014		Tank Specifications- Tanks will be designed, constructed and maintained in accordance with NFPA Code 30. The tanks are visually inspected once a day for issues, and recorded inspections are conducted once a month.
PlanningForm: (02 )
400588715
6/8/2014		Closed Loop Drilling Systems- Pit restrictions, not applicable; a closed-loop system will be used for drilling.
PlanningForm: (02 )
400588715
6/8/2014		Blowout Preventer Equipment (“BOPE”). A double ram and annular preventer will be used during drilling. At least the drilling company shall have a valid well blowout.
PlanningForm: (02 )
400588715
6/8/2014		BOPE- Well servicing operations. Adequate BOP equipment shall be used. Stabbing valves shall be installed in the event of reverse circulation and shall be prior tested with low and high pressure fluid.
PlanningForm: (02 )
400588715
6/8/2014		Drill stem test. Not applicable; no drill Stem tests are planned.
PlanningForm: (02 )
400588715
6/8/2014		Control of fire hazards- All material which is considered fire hazards shall be a minimum of 25’ from the wellhead tanks or separators. Electrical equipment shall comply with API IRP 500 and will comply with the current national electrical code.
PlanningForm: (02 )
400588715
6/8/2014		Bradenhead Monitoring BMP: Operator acknowledges and will comply with COGCC Policy for Bradenhead Monitoring during Hydraulic Fracturing Treatments in the Greater Wattenberg Area dated May 29, 2012.
PlanningForm: (02 )
400588715
6/8/2014		Anti-Collision BMP: 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 wells. The anti-collision scan may 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, operators may have gyro surveys conducted to verify bottomhole location. The proposed well may only be drilled if the anti-collision review results indicate that the risk of collision is sufficiently low as defined by the anti-collision plan, with separation factors greater than 1.5, or if the risk of collision has been mitigated through other means including shutting in wells, plugging wells, increased drilling fluid in the event of lost returns or as is appropriate for the specific situation. In the event of an increased risk of collision, that risk will be mitigated to prevent harm to people, the environment or property. For the proposed well, upon conclusion of drilling operations, an as-constructed directional survey will be submitted to the COGCC with the Form 5.
PlanningForm: (02 )
400588715
6/8/2014		Light sources during all phases of operations will be directed downwards and away from occupied structures where possible. Once the drilling and completion rigs leave the site, there will be no permanently installed lighting on site.
Traffic controlForm: (02 )
400588715
6/8/2014		Access Roads - The access road will be constructed to accommodate local emergency vehicles. This road will be maintained for access at all times.
Traffic controlForm: (02 )
400588715
6/8/2014		Traffic Plan - Traffic will be routed to minimize local interruption.
General HousekeepingForm: (02 )
400588715
6/8/2014		Removal of trash- All trash, debris and material not intrinsic to the operation of the oil and gas facility shall be removed and legally disposed of as applicable.
Material Handling and Spill PreventionForm: (02 )
400588715
6/8/2014		Material Handling and Spill Prevention Leak Detention Plan- Pumper will visit the location daily and visually inspect all tanks and fittings for leaks. Additionally, monthly documented SPCCP inspections are conducted pursuant to 40 CFR 112.
Dust controlForm: (02 )
400588715
6/8/2014		Traffic dust control will be done utilizing water on all County Roads leading up to the pad site.
ConstructionForm: (02 )
400588715
6/8/2014		Construction Berm Construction- Tanks berms shall be constructed of steel rings with a synthetic or engineered liner and designed to contain 150% of the capacity of the largest tank. All berms will be visually checked periodically to ensure proper working condition.
Noise mitigationForm: (02 )
400588715
6/8/2014		Noise Mitigation (revised to apply to Hiner Pad) The drilling site will be powered by electricity, mitigating the majority of noise from drilling operations. Sound walls and/or hay bales will be used to surround the well site during drilling operations.
Emissions mitigationForm: (02 )
400588715
6/8/2014		Green Completions; Emission Control System. Test separators and associated flow lines and sand traps shall be installed on-site to accommodate green completions techniques pursuant to COGCC Rules. In the anticipated absence of a viable gas sales line, the flowback gas shall be thermally oxidized in an emissions control device (ECD), which will be installed and kept in operable condition for least the first 90-days of production pursuant to CDPHE rules. This ECD shall have an adequate capacity for 1.5 times the largest flowback within a 10 mile radius, will be flanged to route gas to other or permanent oxidizing equipment and shall be provided with the equipment needed to maintain combustions where non-combustible gases are present.
Drilling/Completion OperationsForm: (02 )
400588715
6/8/2014		Drilling/Completion Operations Pit level indicators- Not applicable; a closed –loop system will be used and no pits shall be dug.
Final ReclamationForm: (02 )
400588715
6/8/2014		Final Reclamation Well site cleared- Within 90-day subsequent to the time of plugging and abandonment of the entire site, superfluous debris and equipment shall be removed from the site. Identification of plugged and abandoned wells will be identified pursuant to 319.a (5)
PlanningForm: (02 )
401002718
6/10/2016		Multi-well Pads are located in a manner which allows for resource extraction while maintaining the highest distances possible from the offsetting residential areas and complies with the wishes of the surface owner. A meeting with the surface owner will determine the fencing plan.
Pre-ConstructionForm: (02 )
401002718
6/10/2016		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. Identification of plugged and abandoned wells will be identified pursuant to 319.a.(5).
Traffic controlForm: (02 )
401002718
6/10/2016		Access Roads: The access road will be constructed to accommodate local emergency vehicles. This road will be maintained for access at all times.
12