COAs

Facility Type	Facility ID/ API	Facility Name/ Number	Operator Name/ Number	Status	Field Name/ Number	Location	Location ID	Related Facilities
WELL	05-123-38821	CS-Scott 1-1-12	EXTRACTION OIL & GAS INC 10459	PR 8/1/2024	WATTENBERG 90750	WELD 123 SWSE 36 6N66W 6	430474

COGIS - Conditions of Approval Results

Type	Source Document	Conditions of Approval
Engineer	Form: (02 ) 400406883 11/28/2013	1) Submit Form 42 electronically to COGCC 48 hours prior to MIRU. 2) Comply with Rule 317.i and provide cement coverage from the end of the 7" casing to a minimum of 200' above the Niobrara. Verify coverage with a 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. 4) At least two weeks prior to spud notice, the centralizer and cementing plans shall be submitted to the COGCC for review on a Form 4, Sundry Notice. 5) At least one well on the pad must have a complete set of open hole logs (Compensated Neutron, Dual Induction, Resistivity, etc.) run and submitted to the COGCC. 6) Four hours prior to running any casing, notification shall be provided to Mike Hickey, COGCC Engineer at 303-894-2100 x5105. 7) Bradenhead pressures shall be taken 6, 12, 24 and 48 hours after cementing production casing and prior to stimulation of the well. Once stimulation is complete, the bradenhead pressure shall be recorded at 24 hours, at 48 hours and at one week post-stimulation. Bradenhead pressures greater than 100 psi must be immediately reported on a Form 17 to the COGCC, sent to the attention of Mike Hickey. 8) All bradenhead pressures shall be monitored with a gauge that has a maximum reading of one thousand pounds per square inch (psi). 9) Circulation prior to cementing shall be done to accepted industry standards.
Permit	Form: (02 ) 400406883 1/2/2014	Operator shall comply with Buffer Zone Move-In, Rig-Up Notice Policy dated 12-16-2013.
Permit	Form: (02 ) 400406883 1/2/2014	Open hole resistivity and gamma ray 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 Form 5 for every well shall identify which well was logged.

COGIS - Best Management Practice Results

BMP Type	Source Document	Best Management Practices
Planning	Form: (02 ) 400406883 1/17/2014	Multi-well Pads. It is a multi-well pad located in a manner which allows for resource extraction while maintaining the highest distances passible from the offsetting residential areas.
Planning	Form: (02 ) 400406883 1/17/2014	Development from existing well pads. These additional wells are located on an already approved location assessment and have been clustered in two lines to minimize surface disturbance area and cut and fill volumes.
Planning	Form: (02 ) 400406883 1/17/2014	Site-specific measures. This location has been designed to mitigate the visual impacts to the surrounding properties.
Traffic control	Form: (02 ) 400406883 1/17/2014	Traffic Plan. Traffic plans will be reviewed with the Town of Greeley.
General Housekeeping	Form: (02 ) 400406883 1/17/2014	Fencing requirements. A permanent fencing plan will be submitted to the surface owner.
General Housekeeping	Form: (02 ) 400406883 1/17/2014	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 applicable.
Material Handling and Spill Prevention	Form: (02 ) 400406883 1/17/2014	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 ) 400406883 1/17/2014	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. No more than two tanks shall be located within a single berm. All berms will be visually checked periodically to ensure proper working condition.
Material Handling and Spill Prevention	Form: (02 ) 400406883 1/17/2014	Loadlines. All loadlines shall be bullplugged or capped.
Material Handling and Spill Prevention	Form: (02 ) 400406883 1/17/2014	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.
Construction	Form: (02 ) 400406883 1/17/2014	Access roads. The access road will be constructed pursuant to the attached long-term development plan and has been, along with the pad, designed to accommodate local emergency vehicles. This road will be maintained for access at all times.
Noise mitigation	Form: (02 ) 400406883 1/17/2014	Noise. A 8’ high hay bale wall will be constructed around the drilling location for temporary noise screening.
Emissions mitigation	Form: (02 ) 400406883 1/17/2014	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 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 combustion where non-combustible gases are present.
Drilling/Completion Operations	Form: (02 ) 400406883 1/17/2014	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 ) 400406883 1/17/2014	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.
Drilling/Completion Operations	Form: (02 ) 400406883 1/17/2014	Closed Loop Drilling Systems – Pit Restrictions. Not applicable; a closed-loop system will be used for drilling.
Drilling/Completion Operations	Form: (02 ) 400406883 1/17/2014	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 ) 400406883 1/17/2014	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 ) 400406883 1/17/2014	Pit level indicators. Not applicable; a closed-loop system will be used and no pits shall be dug.
Drilling/Completion Operations	Form: (02 ) 400406883 1/17/2014	Drill stem tests. Not applicable; no Drill Stem tests are planned.
Drilling/Completion Operations	Form: (02 ) 400406883 1/17/2014	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.
Drilling/Completion Operations	Form: (02 ) 400406883 1/17/2014	Guy line anchors. All guy line anchors shall be brightly marked pursuant to Rule 604.c(2)Q.
Final Reclamation	Form: (02 ) 400406883 1/17/2014	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 ) 400406883 1/17/2014	Identification of plugged and abandoned wells. P&A’d wells shall be inditified persuant to 319.a.(5).

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