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Facility Type	Facility ID/ API	Facility Name/ Number	Operator Name/ Number	Status	Field Name/ Number	Location	Location ID	Related Facilities
LOCATION	335724	FEDERAL RGU 33-24-198	TEP ROCKY MOUNTAIN LLC 96850	AC 10/1/2024	SULPHUR CREEK 80090	RIO BLANCO 103 Lot 10 24 1S98W 6	335724

COGIS - Conditions of Approval Results

Type	Source Document	Conditions of Approval
Agency	Form: (02A ) 2095264 3/26/2010	Location is in a sensitive area because of close proximity to surface water, therefore, operator must ensure 110 percent secondary containment for any volume of fluids contained at well site during drilling and completion operations. If fluids are conveyed via pipeline, operator must implement best management practices to contain any unintentional release of fluids.
Agency	Form: (02A ) 2095264 3/26/2010	No portion of any pit that will be used to hold liquids shall be constructed on fill material, unless the pit and fill slope are designed and certified by a professional engineer, subject to review and approval by the director prior to construction of the pit. The construction and lining of the pit shall be supervised by a professional engineer or their agent. The entire base of the pit must be in cut.
Agency	Form: (02A ) 2095264 3/26/2010	Operator must implement best management practices to contain any unintentional release of fluids.
Agency	Form: (02A ) 2095264 3/26/2010	The moisture content of any drill cuttings in a cuttings pit, trench, or pile shall be as low as practicable to prevent accumulation of liquids greater than de minimis amounts. At the time of closure, the drill cuttings must also meet the applicable standards of table 910-1.
Agency	Form: (02A ) 2095264 3/26/2010	Reserve pit must be lined.
OGLA	Form: (02A ) 400459102 10/15/2013	Notify the COGCC 48 hours prior to start of pad construction (if existing pad needs to be expanded or brought out to the original footprint), rig mobilization, spud, and start of hydraulic stimulation operations using Form 42 (the appropriate COGCC individuals will automatically be email notified, including the LGD for hydraulic stimulation operations).
OGLA	Form: (02A ) 400459102 10/15/2013	The access road will be maintained as to not allow any sediment to migrate from the access road to nearby surface water or any drainages leading to surface water. Strategically apply fugitive dust control measures, including enforcing established speed limits on private roads, to reduce fugitive dust and coating of vegetation and deposition in water sources. Berms or other containment devices shall be constructed to be sufficiently impervious (preferably corrugated steel with poly liner) to contain any spilled or released material around crude oil, condensate, and produced water storage tanks.
OGLA	Form: (02A ) 400459102 10/15/2013	Flowback and stimulation fluids must be sent to tanks, separators, or other containment/filtering equipment before the fluids can be placed into any pipeline, storage vessel, or lined pit (only if an amended Form 2A has been submitted/approved and a Form 15 Earthen Pit Permitted has been submitted/approved) located on the well pad; or into tanker trucks for offsite disposal. The flowback and stimulation fluid tanks, separators, or other containment/filtering equipment must be placed on the well pad in an area with additional downgradient perimeter berming. The area where flowback fluids will be stored/reused must be constructed to be sufficiently impervious to contain any spilled or released material. Operator shall pressure test pipelines in accordance with Rule 1101.e.(1) prior to putting into initial service any temporary surface or permanent buried pipelines and following any reconfiguration of the pipeline network. Operator shall notify the COGCC Oil and Gas Location Assessment (OGLA) Specialist for Western Colorado (Dave Kubeczko; email dave.kubeczko@state.co.us) and the COGCC Field Inspection Supervisor for Northwest Colorado (Shaun Kellerby; email shaun.kellerby@state.co.us) 48 hours prior to testing surface poly or buried steel pipelines. Operator must implement best management practices to contain any unintentional release of fluids along all portions of the surface pipeline route where temporary pumps and other necessary equipment are located. Operator must routinely inspect the entire length of the surface pipeline to ensure integrity. Operator shall conduct daily inspections of surface poly pipeline routes for leaks during active transfer of fluids. Inspections shall be conducted by viewing the length of the pipeline; operator will endeavor to minimize surface disturbance during pipeline monitoring. The operator shall maintain records of inspections, findings and repairs, if necessary, for the life of the pipelines. Operator must ensure appropriate secondary containment for volume of fluids that may be released before pump shut down from the surface pipeline at all stream, intermittent stream, ditch, and drainage crossings. Catchment basins, if needed, should be sized to contain the volume between pump stations or between the nearest pump station and the frac pad being used for this well pad location. Pump stations along the surface poly or steel pipeline route will be continuously monitored when operating in order to swiftly respond to such a failure. Operator will utilize, to the extent practical, all existing access and other public roads, and/or existing pipeline right-of-ways, when placing/routing the surface pipelines. This will reduce surface disturbance and fragmentation of wildlife habitat in the area.
OGLA	Form: (04 ) 402155597 9/19/2019	Within 30 days of beginning of compressor use, submit a copy of the noise survey demonstrating compliance with COGCC Rule 802.

COGIS - Best Management Practice Results

BMP Type	Source Document	Best Management Practices
Planning	Form: (02A ) 400459102 12/27/2013	PLANNING BMP's * 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: (02A ) 400459102 12/27/2013	DRILLING/COMPLETIONS BMP's * 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: (02A ) 400459102 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.