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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	05-103-12081	FEDERAL RGU 533-24-198	TEP ROCKY MOUNTAIN LLC 96850	SI 9/1/2024	SULPHUR CREEK 80090	RIO BLANCO 103 LOT 10 24 1S98W 6	335724

COGIS - Conditions of Approval Results

Type	Source Document	Conditions of Approval
Engineer	Form: (02 ) 400459667 9/30/2013	(1) COMPLIANCE WITH THE MOST CURRENT REVISION OF THE NORTHWEST COLORADO NOTIFICATION POLICY IS REQUIRED.
Engineer	Form: (04 ) 403747176 8/1/2024	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. Well to be repaired or plugged no later than 8/22/2024. Pressure is to be managed and mitigated until plugging is complete.
Engineer	Form: (04 ) 403879003 8/7/2024	1. Well to be repaired no later than 8/22/2024. Pressure is to be managed and mitigated until repair is complete. 2. For applicable operations , report work completed with a Form 4 Sundry REPORT OF WORK DONE - Repair Well noting final pressure test results and include any operational or job summaries. If the wellbore geometry changes or there is not an updated WBD in the well file submit an updated WBD. 3. Complete a bradenhead test within 30 days of completing the repair and submit results on a Form 17
Permit	Form: (06 ) 403949693 10/10/2024	Submit Operator's Monthly Production Reports (Form 7) required for compliance with Rule 413 within 30 days Form 7 reporting needs to reflect dates of TA plugging.
OGLA	Form: (06 ) 403949693 10/25/2024	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 ) 403949693 12/5/2024	Prior to starting plugging operations a bradenhead test shall be performed if there has not been a reported bradenhead test within the 60 days immediately preceding the start of plugging operations. 1) If, before opening the bradenhead valve, the beginning pressure is greater than 25 psi, sampling is required. 2) If pressure remains at the conclusion of the test, or if any liquids were present during the test, sampling is required. The Form 17 shall be submitted within 10 days of the test. Sampling shall comply with Operator Guidance - Bradenhead Testing and Reporting Instructions. If samples are collected, copies of all final laboratory analytical results shall be provided to the ECMC within three (3) months of collecting the samples. If there is a need for sampling, contact ECMC engineering for verification of plugging procedure.
Engineer	Form: (06 ) 403949693 12/5/2024	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 ) 403949693 12/5/2024	NOTE: Plugging procedure has been changed via discussion with operator. Operator submitted updated WBD and procedure 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) After placing plug at casing leak assure that all fluid migration has been eliminated by monitoring the well for a minimum of 8 hours before proceeding to the next plug. If at any time after placing this plug there is evidence of pressure or of fluid migration, contact ECMC engineering before continuing operations. 3) Pump surface casing shoe plug only after isolation has been verified. 4) Leave at least 100’ of cement in the wellbore for each plug without mechanical isolation. 5) 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. 6) With the Form 6 SRA operator must provide written documentation which positively affirms each COA listed above has been addressed.
Engineer	Form: (06 ) 403949693 12/5/2024	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 ) 400459667 12/27/2013	* Share/consolidate corridors for pipeline ROWs to the maximum extent possible. * Minimize newly planned activities and operations within 300 feet of the ordinary high water mark of any reservoir, lake, wetland, or natural perennial or seasonally flowing stream or river. * Locate roads outside of drainages where possible and outside of riparian habitat. * Avoid constructing any road segment in the channel of an intermittent or perennial stream * Minimize the number, length, and footprint of oil and gas development roads * Use existing roads where possible * Combine utility infrastructure (gas, electric, and water) planning with roadway planning to avoid separate utility corridors * Combine and share roads to minimize habitat fragmentation * Maximize the use of directional drilling to minimize habitat loss/fragmentation * Maximize use of remote completion/frac operations to minimize traffic * Maximize use of remote telemetry for well monitoring to minimize traffic
Drilling/Completion Operations	Form: (02 ) 400459667 12/27/2013	* Use centralized hydraulic fracturing operations. * Install and maintain adequate measures to exclude all types of wildlife (e.g., big game, birds, and small rodents) from all fluid pits (e.g., fencing, netting, and other appropriate exclusion measures). * Conduct well completions with drilling operations to limit the number of rig moves and traffic
Interim Reclamation	Form: (02 ) 400459667 12/27/2013	* Use only certified weed-free native seed in seed mixes, except for non-native plants that benefit wildlife * WPX Energy will use certified, weed free grass hay, straw, hay or other mulch materials used for the reseeding and reclamation of disturbed areas. * Install exclusionary devices to prevent bird and other wildlife access to equipment stacks, vents and openings. * Reduce visits to well-sites through remote monitoring (i.e. SCADA) and the use of multi-function contractors. * Avoid dust suppression activities within 300 feet of the ordinary high water mark of any reservoir, lake, wetland, or natural perennial or seasonally flowing stream or river where possible.
Wildlife	Form: (04 ) 403879003 8/7/2024	To minimize the potential for wildlife related traffic accidents, TEP has implemented speed restrictions for all lease roads and requires that all TEP employees and contractors adhere to these posted speed restrictions.
Wildlife	Form: (04 ) 403879003 8/7/2024	TEP will minimize vehicle numbers and traffic by carpooling to the site whenever possible.
Wildlife	Form: (04 ) 403879003 8/7/2024	TEP will make best efforts to minimize operations at these location during winter months by conducting operations, when possible, between 9:00am to 4:00pm when wildlife activity minimal.