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Facility Type	Facility ID/ API	Facility Name/ Number	Operator Name/ Number	Status	Field Name/ Number	Location	Location ID	Related Facilities
WELL	05-123-35365	DAVIS 1A-9H	CRESTONE PEAK RESOURCES OPERATING LLC 10633	PR 4/26/2019	WATTENBERG 90750	WELD 123 SWNE 9 2N66W 6	428454

COGIS - Conditions of Approval Results

Type	Source Document	Conditions of Approval
Engineer	Form: (02 ) 400257940 3/12/2012	1)Provide 48 hour notice of MIRU via an electronic Form 42. 2)Comply with Rule 317.i and provide cement coverage from the end of the production casing to a minimum of 200' above the Niobrara and from 200’ below Sussex to 200’ above Sussex. Verify coverage with a cement bond log. 3)Comply with Rule 321. Run and submit Directional Survey from the TD to surface. Ensure that the wellbore complies with setback requirements in commission orders or rules prior to producing the well.
Permit	Form: (02 ) 400257940 3/14/2012	Operator must meet Water Well Testing requirements as per amended Rule 318A.
Engineer	Form: (04 ) 401766804 9/27/2018	Operator acknowledges the proximity of the listed non-operated well. Operator assures that this offset will be remediated per the DJ Basin Horizontal Offset Policy (option 3). Operator will submit a Form 42 (“OFFSET MITIGATION COMPLETED”) stating what appropriate mitigation occurred and that it has been completed, prior to the hydraulic stimulation of this well. 05-123-15194, KUGEL W 4-8
Engineer	Form: (04 ) 401766804 9/27/2018	Operator acknowledges the proximity of the non-operated listed wells. Operator agrees to: provide mitigation option 1 or 2 (per the DJ Basin Horizontal Offset Policy) to mitigate the situation, ensure all applicable documentation is submitted based on the selected mitigation option chosen, and submit a Form 42 (“OFFSET MITIGATION COMPLETED”) stating that appropriate mitigation occurred and that it has been completed, prior to the hydraulic stimulation of this well. 05-123-09963, UPRR 38 PAN AM E 2 05-123-07555, KUGEL "B" 1 05-123-15186, KUGEL W 4-7 05-123-15331, KUGEL W4-6 05-123-17575, HERMAN 32-16K 05-123-14306, HSR-HOSTEK 14-33A 05-123-14365, HSR - STEER 15-33A
Engineer	Form: (04 ) 401766804 9/27/2018	Operator acknowledges the proximity of the listed wells. Operator agrees to: provide mitigation option 1 or 2 (per the DJ Basin Horizontal Offset Policy) to mitigate the situation, ensure all applicable documentation is submitted based on the selected mitigation option chosen, and submit a Form 42 (“OFFSET MITIGATION COMPLETED”) stating that appropriate mitigation occurred and that it has been completed, prior to the hydraulic stimulation of this well. 05-123-07433, IONE 1 05-123-19639, IONE 34-4 05-123-19947, IONE 33-4 05-123-20189, IONE 24-4 05-123-08926, DAVIS GAS UNIT 1 05-123-18900, CANNON 9-3 05-123-18901, CANNON 9-4 05-123-19751, DAVIS 12-9 05-123-19752, DAVIS GAS UNIT 32-9
Engineer	Form: (04 ) 401766804 9/27/2018	Bradenhead tests shall be performed according to the following schedule and the Form 17 submitted within 10 days of each test: 1) Prior to stimulation and 2) Within 30 days after first production following the refrac, as reported on Form 5A.
Engineer	Form: (04 ) 401766804 9/27/2018	Operator will comply with the COGCC Policy for Bradenhead Monitoring during Hydraulic Fracturing Treatments in the Greater Wattenberg Area dated May 29, 2012.
Engineer	Form: (04 ) 402308806 8/21/2020	Operator shall continue to monitor pressure, and report to COGCC through annual test reporting.

COGIS - Best Management Practice Results

BMP Type	Source Document	Best Management Practices
Drilling/Completion Operations	Form: (02 ) 400257940 4/5/2012	Best Management Practice for a Horizontal Wellbore Fracturing Stimulation 1. At least seven (7) days prior to fracture stimulation, the operator is to notify all operators of non-operated wells within 300 feet of the wellbore to be fracture stimulated of the anticipated date stimulation date and the recommended best management practice to shut-in all wells within 300’ of the stimulated wellbore completed in the same formation. 2. The operator will monitor the bradenhead pressure of all wells within 300 feet of the well to be fracture stimulated. 3. Bradenhead pressure gauges are to be installed 24 hours prior to stimulation. The gauges are to read at least once during every 24-hour period until 24-hours after stimulation is completed (post flowback). The gauges are to be of the type able to read current pressure and record the maximum encountered pressure in a 24-hour period. The gauge is to be reset between each 24-hour period. The pressures are to be recorded and saved. 4. If at any time during stimulation or the 24-hour post-stimulation period, the bradenhead annulus pressure of the treatment well or offset wells increases more than 200 psig, as per Rule 341, the operator of the well being stimulated shall verbally notify the Director as soon as practicable, but no later than twenty-four (24) hours following the incident. Within fifteen (15) days after the occurrence, the operator shall submit a Sundry Notice, Form 4, giving all details, including corrective actions taken.
Drilling/Completion Operations	Form: (02 ) 400257940 4/5/2012	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 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 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.