COAs

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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	05-103-12621	ELU A18 FED 14B-7-495	QB ENERGY OPERATING LLC 10844	DG 8/10/2024	GRAND VALLEY 31290	RIO BLANCO 103 3 18 4S95W 6	483521

COGIS - Conditions of Approval Results

Type	Source Document	Conditions of Approval
Engineer	Form: (02) 402595746 02/16/2023	1)Operator shall comply with the most current revision of the Northwest Notification Policy. 2) During stimulation, operator shall monitor the bradenhead, casing, and tubing pressure of the proposed well and all offset wells under Operator’s control which penetrate the stimulated formation and have a treated interval separation of 300 feet or less. Operator shall notify COGCC Engineering staff if bradenhead pressures increase by more than 200 psig.
Engineer	Form: (04) 403565907 12/06/2023	1)Operator shall comply with the most current revision of the Northwest Notification Policy. 2) During stimulation, operator shall monitor the bradenhead, casing, and tubing pressure of the proposed well and all offset wells under Operator’s control which penetrate the stimulated formation and have a treated interval separation of 300 feet or less. Operator shall notify COGCC Engineering staff if bradenhead pressures increase by more than 200 psig.
Engineer	Form: (04) 403798015 06/26/2024	1) Operator shall comply with the most current revision of the Northwest Notification Policy. 2) During stimulation, operator shall monitor the bradenhead, casing, and tubing pressure of the proposed well and all offset wells under Operator’s control which penetrate the stimulated formation and have a treated interval separation of 300 feet or less. Operator shall notify COGCC Engineering staff if bradenhead pressures increase by more than 200 psig. 3) Operator shall provide cement coverage from the production casing shoe 4 ½” FIRST STRING to a minimum of 200' above all Mesaverde Group (and Ohio Creek Formation, if present) oil, gas, and water-bearing sandstone and coalbed formations. Verify production casing cement coverage with a cement bond log.
Permit	Form: (06) 403894669 08/28/2024	Submit form 5 Final drilling completion report
OGLA	Form: (06) 403894669 08/29/2024	Due to proximity to surface water, Operator will review the stormwater program and implement stormwater BMPs and erosion control measures as needed to prevent fine-grained sediment and impacted stormwater runoff from entering surface water. LAS Review Complete.
Engineer	Form: (06) 403894669 09/10/2024	Operator shall implement measures to control venting, to protect health and safety, and to ensure that vapors and odors from well plugging operations do not constitute a nuisance or hazard to public welfare.
Engineer	Form: (06) 403894669 09/10/2024	1) Provide electronic Form 42 Notice of MIRU 2 business days ahead of operations and electronic Form 42 Notice of Plugging Operations 48 hours prior to mobilizing for plugging operations. These are two separate notifications, required by Rules 405.e and 405.l. 2) Leave at least 100’ of cement in the wellbore for each plug without mechanical isolation. 3) After surface plug and prior to cap, verify isolation by either a 15 minute bubble test or 15 minute optical gas imaging. If there is indication of flow contact ECMC Engineering. Provide a statement on the 6SRA which method was used and what was observed. Retain records of final isolation test for 5 years. 4) With the Form 6 SRA operator must provide written documentation which positively affirms each COA listed above has been addressed. 5) This well has federal minerals. Operator shall notify ECMC engineering staff of any plugging changes required by the BLM or unexpected conditions in the field prior to continuing operations.
Engineer	Form: (06) 403894669 09/10/2024	Consistent with Rule 911.a, a Form 27 must be approved prior to cut and cap, conducting flowline abandonment, or removing production equipment. Allow 30 days for Director review of the Form 27; include the Form 27 document number on the Form 44 for offsite flowline abandonment (if applicable) and on the Form 6 Subsequent. Properly abandon flowlines per Rule 1105. If flowlines will be abandoned in place, include with the Form 27: pressure test results conducted in the prior 12 months as well as identification of any document numbers for a ECMC Spill/Release Report, Form 19, associated with the abandoned line.

COGIS - Best Management Practice Results

BMP Type	Source Document	Best Management Practices
Planning	Form: (02 ) 402595746 3/21/2023	Alternative Logging Program: One of the first wells drilled on the pad will be logged with open-hole resistivity log with gamma-ray log from TD into the surface casing. All wells on the pad will have a cement bond log with gamma-ray run on production casing (or on intermediate casing if production liner is run) into the surface casing. The Form 5, Completion Report, for each well on the pad will list all logs run and have those logs attached. The Form 5 for a well without open-hole logs will state, “Alternative Logging Program - No open-hole logs were run” and will clearly identify the type of log and the well (by API#) in which open-hole logs were run.
Planning	Form: (02 ) 402595746 3/21/2023	The associated well pad Location ID: 479185 was approved on January 11, 2021 by the COGCC. The BLM White River Field Office (WRFO) approved the Application for Permit to Drill (APD) for this well on December 2, 2020 under the land use planning review of the WRFO Record of Decision and Approved Resource Management Plan (ROD/RMP), as amended by the WRFO Oil and Gas Development Plan Approved Resource Management Plan Amendment and the Northwest Colorado Greater Sage-Grouse Approved RMPA. Please reference the attached WRFO Environmental Assessment from November 2020 and the Decision Record approved by the WRFO BLM on November 25, 2020, which specifically addresses the criteria in which the associated well pad was evaluated and approved.
Drilling/Completion Operations	Form: (02 ) 402595746 3/21/2023	Closed loop system will be used. DRILL CUTTINGS: The moisture content of all drill cuttings managed onsite shall be kept as low as practicable to prevent accumulation of liquids greater than de minimis amounts. All cuttings generated during drilling will be placed in a bermed portion of the well pad prior to onsite beneficial reuse. Drill cuttings will be put through shakers to minimize moisture and analyzed for Table 915-1 constituents. Cuttings that meet 915-1 levels will be backfilled into the cuttings management area along the northwestern portion of the pad. CONTAINMENT: During drilling activities, Caerus utilizes a portable containment liner under the substructure of the drilling rig during drilling activities to protect shallow groundwater from any potential spills surrounding the rig during drilling. A liquid release would simply be vacuumed up from the liner. When drilling activity is completed, the liner is removed and transferred to the next drilling location. For permanent containment at the oil and gas location Caerus will ensure 150% secondary containment of volume in the single largest tank on the oil and gas location in compliance with Rule 603.o. During completions, Caerus may utilize 15-20 temporary tanks to hold frac fluid and flowback water. Tanks would be housed in a compacted earthen bermed area and secondary containment. FLOWBACK & STIMULATION: As wells progress from the drilling stage to the completions stage temporary working tanks will be situated on the ELU A18-495 Well Pad. Caerus estimates that there could be 15-20 500-bbl tanks on location for roughly 18-months as the wells progress from the drilling to completions stage during Sim-Ops. The contents of the tanks will contain produced water. The temporary tanks will be placed on a certain portion of the ELU A18-495 Well Pad and laid upon an impervious synthetic or engineered liner which would be underlaid by road base. The liners will be sufficient to hold up to 150% of the largest tank on the location. Note, the entire Oil and Gas Location for the ELU A18-495 will include a compacted earthen berm perimeter around the operational area for ELU A18-495 Well Pad. Once the working tanks are no longer necessary for operations both the tanks and the impervious liner will be removed.
Drilling/Completion Operations	Form: (04 ) 403875920 9/10/2024	A closed loop system will be used. DRILL CUTTINGS: Drill cuttings will be stored in steel bins. Cuttings samples may be collected when drilling is initiated for waste characterization. Based on the analytical results, drill cuttings will be managed and disposed of pursuant to ECMC rule 905.e. CONTAINMENT: During completions, Caerus may utilize 15-20 temporary tanks to hold frac fluid and flowback water. FLOWBACK & STIMULATION: As wells progress from the drilling stage to the completions stage temporary working tanks will be situated on the ELU A18-495 Well and Frac Pad. Caerus estimates that there could be 15-20 500-bbl tanks on location for roughly 18-months as the wells progress from the drilling to completions stage during Sim- Ops. The contents of the tanks will contain produced water. The entire Oil and Gas Location for the ELU A18-495 will include a compacted earthen berm perimeter around the operational area for ELU A18-495 Well Pad. Once the working tanks are no longer necessary for operations the tanks will be removed.