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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	05-123-35595	SARCHET 15N-32HZ	KERR MCGEE OIL & GAS ONSHORE LP 47120	PR 5/1/2023	WATTENBERG 90750	WELD 123 NWNE 32 3N66W 6	428939

COGIS - Conditions of Approval Results

Type	Source Document	Conditions of Approval
Engineer	Form: (02) 400256887 04/23/2012	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) 400256887 04/26/2012	Operator shall run an open hole log across the surface casing shoe on the first well drilled from this pad.
Permit	Form: (02) 400256887 04/26/2012	Operator must meet Water Well Testing requirements as per amended Rule 318Ae(4)
Engineer	Form: (04) 402303812 05/15/2020	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. 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 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. Operator shall 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. 4. This mitigation plan may be used for six consecutive months from the approved sundry date. At the conclusion of the six months, 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 and the flow rate information and pressure data.
Engineer	Form: (04) 402480704 09/03/2020	Operator shall continue to monitor pressure, and report to COGCC through annual test reporting.
Engineer	Form: (04) 402860475 11/10/2021	Operator shall continue to monitor pressure, and report to COGCC through annual testing. If monitored well conditions meet the thresholds defined by Order 1-232 a new bradenhead test and sundry must be filed.
Engineer	Form: (04) 403017626 04/26/2022	Operator shall continue to monitor pressure, and report to COGCC through annual testing. If monitored well conditions meet the thresholds defined by Order 1-232 a new bradenhead test and sundry must be filed.
Engineer	Form: (04) 403214338 11/08/2022	Operator shall continue to monitor pressure, and report to COGCC through annual testing. If monitored well conditions meet the thresholds defined by Order 1-232 a new bradenhead test and sundry must be filed.
Engineer	Form: (04) 403775428 05/06/2024	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
Drilling/Completion Operations	Form: (02 ) 400256887 5/17/2012	“Prior to drilling operations, Operator may perform an anti-collision review of existing offset wells that have the potential of being within close proximity of the proposed well. This anti-collision review may include MWD or gyro surveys and surface locations 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 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 COGCC with the Form 5.” At the time of permitting, the operator has identified the following well(s) as being within close proximity of the proposed well: SARCHET 15N-32HZ: - NO WELLS WITHIN 150' OF THIS WELL
Drilling/Completion Operations	Form: (02 ) 400256887 5/17/2012	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 operated by the operator within 300 feet of the well to be fracture stimulated. Noble Energy has agreed to comply with the BMPs respecting horizontal well fracturing stimulation (Letter attached) 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. Alternate electronic measurement may be used to record the prescribed pressures. 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.