COAs

Facility Type	Facility ID/ API	Facility Name/ Number	Operator Name/ Number	Status	Field Name/ Number	Location	Location ID	Related Facilities
WELL	05-123-40328	GP-Dairy 1-20-19	EXTRACTION OIL & GAS INC 10459	PR 5/1/2024	WATTENBERG 90750	GREELEY/WELD 123 NENE 20 5N65W 6	332837

COGIS - Conditions of Approval Results

Type	Source Document	Conditions of Approval
Engineer	Form: (02) 400407705 06/17/2014	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) Run and submit Directional Survey from TD to base of surface casing. The operator shall comply with Rule 321, and it shall be the operator’s responsibility to ensure that the wellbore complies with setback requirements in commission orders or rules prior to producing the well.
Permit	Form: (02) 400407705 07/08/2014	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.
Permit	Form: (02) 400407705 07/08/2014	Operator shall comply with Buffer Zone Move-In, Rig-Up Notice Policy dated 12-16-2013.
OGLA	Form: (02) 400407705 09/29/2014	Conditional approval of this APD as a Rule 604.b.(1) Exeption Location is based on the operator adhering to the Mitigation Measures listed in related Location ID #332837.
Engineer	Form: (02) 400779236 01/23/2015	1) 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. 2) Run and submit Directional Survey from TD to base of surface casing. The operator shall comply with Rule 321, and it shall be the operator’s responsibility to ensure that the wellbore complies with setback requirements in commission orders or rules prior to producing the well.
Engineer	Form: (04) 402290705 03/05/2020	This approval is good for one year and a new application must be made before January 21, 2021. Updates for the planned utilization of the well should be included with the application. The Form 7 reporting must reflect the well status dates reported on the Form 4-TA request.
Engineer	Form: (04) 402573439 07/09/2021	1) This approval is good for one year and a new application must be made before 1/13/2022. Updates for the planned utilization of the well should be included with the application.
Engineer	Form: (04) 402930050 02/18/2022	1. Operator will 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 will comply with Operator Guidance - Bradenhead Testing and Reporting Instructions, Appendix A: Liquid and Gas Sampling. Copies of all final laboratory analytical results will be provided to the COGCC within three months of collecting the samples. 3. Operator will 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 (5/29/22), 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, sample analysis interpretation, and the flow rate information and pressure data. Shut in bradenhead pressure shall not exceed 50 psig.
Engineer	Form: (04) 403056371 06/21/2022	This well may be returned to annual testing and monthly monitoring. If at any point in the future bradenhead conditions meet thresholds defined by Order 1-232 a new bradenhead mitigation sundry must be filed.

COGIS - Best Management Practice Results

BMP Type	Source Document	Best Management Practices
Planning	Form: (02 ) 400407705 9/30/2014	Multi-well Pads. It is a multi-well pad located in a manner which allows for resource extraction while maintaining the highest distances possible from the offsetting residential areas.
Traffic control	Form: (02 ) 400407705 9/30/2014	Access roads. The access road will be constructed to accommodate local emergency vehicles. This road will be maintained for access at all times.
General Housekeeping	Form: (02 ) 400407705 9/30/2014	Fencing requirements. A permanent fencing plan will be reviewed by the surface owner, & the applicant.
General Housekeeping	Form: (02 ) 400407705 9/30/2014	Removal of surface 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 is applicable.
Material Handling and Spill Prevention	Form: (02 ) 400407705 9/30/2014	Leak Detection 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.
Material Handling and Spill Prevention	Form: (02 ) 400407705 9/30/2014	Berm construction. Tank 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.
Material Handling and Spill Prevention	Form: (02 ) 400407705 9/30/2014	Load-lines. All load-lines shall be bull-plugged or capped.
Material Handling and Spill Prevention	Form: (02 ) 400407705 9/30/2014	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.
Noise mitigation	Form: (02 ) 400407705 9/30/2014	Lighting abatement measures shall be implemented, including the installation lighting shield devices on all of the more conspicuous lights, & low density sodium lighting where practicable. At its election the operator may install temporary engineering controls consisting of perimeter sound walls shall be used on the location during drilling and completion activities to provide noise relief. Permanent equipment on location shall be muffled to reduce noise, or shall be appropriately buffered.
Drilling/Completion Operations	Form: (02 ) 400407705 9/30/2014	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. 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 ) 400407705 9/30/2014	Closed Loop Drilling Systems – Pit Restrictions. Not applicable; a closed-loop system will be used for drilling.
Drilling/Completion Operations	Form: (02 ) 400407705 9/30/2014	Green Completions – Emission Control Systems. 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 flow-back 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 flow-back 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 combustion where noncombustible gases are present.
Drilling/Completion Operations	Form: (02 ) 400407705 9/30/2014	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 prevention certifications.
Drilling/Completion Operations	Form: (02 ) 400407705 9/30/2014	BOPE for 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.
Drilling/Completion Operations	Form: (02 ) 400407705 9/30/2014	Pit level indicators. Not applicable; a closed-loop system will be used and no pits shall be dug.
Drilling/Completion Operations	Form: (02 ) 400407705 9/30/2014	Drill stem tests. Not applicable; no Drill Stem tests are planned.
Drilling/Completion Operations	Form: (02 ) 400407705 9/30/2014	Control of fire hazards. All materials which are considered fire hazards shall be a minimum of 25’ from the wellhead tanks or separators. Electrical equipment shall comply with API RP 500 and will comply with the current national electrical code. An emergency response plan has been generated for this site.
Drilling/Completion Operations	Form: (02 ) 400407705 9/30/2014	Guy line anchors. All guy line anchors shall be brightly marked pursuant to Rule 604.c (2)Q
Drilling/Completion Operations	Form: (02 ) 400407705 9/30/2014	Bradenhead Monitoring BMP: Operator will comply with COGCC Policy for Bradenhead Monitoring During Hydraulic Fracturing Treatments in the Greater Wattenberg Area dated May 29, 2012.
Final Reclamation	Form: (02 ) 400407705 9/30/2014	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.
Final Reclamation	Form: (02 ) 400407705 9/30/2014	Identification of plugged and abandoned wells. P&A’d wells shall be identified pursuant to 319.a.(5).

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