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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	159692	RU 21-8	TEP ROCKY MOUNTAIN LLC 96850	AC 4/1/2025	RULISON 75400	GARFIELD 045 NENW 8 7S93W 6	159692

COGIS - Conditions of Approval Results

Type	Source Document	Conditions of Approval
OGLA	Form: (02A) 400645428 12/10/2014	Notify the COGCC 48 hours prior to start of pad reconstruction/regarding, rig mobilization, spud, pipeline testing, start of hydraulic stimulation operations, and start of flowback operations (if different than 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) 400645428 12/10/2014	Operator must ensure secondary containment for any volume of fluids contained at tank site during operations; including, but not limited to, construction of a berm or diversion dike, diversion/collection trenches within and/or outside of berms/dikes, site grading, or other comparable measures (i.e., best management practices (BMPs) associated with stormwater management) sufficiently protective of nearby surface water. Any berm constructed at the well pad location will be stabilized, inspected at regular intervals (at least every 14 days and after precipitation events), and maintained in good condition.
OGLA	Form: (02A) 400645428 12/10/2014	The moisture content of drill cuttings managed onsite shall be kept as low as practicable to prevent accumulation of liquids greater than de minimis amounts. After drilling and completion operations have been completed, the drill cuttings that will remain on the well pad location (cuttings management area, the cut portion of the pad, cuttings trench, dry cuttings drilling pit), must meet the applicable standards of Table 910-1. After the drill cuttings have been amended (if necessary) and placed on the well pad, sampling frequency of the drill cuttings (to be determined by the operator) shall be representative of the material left on location. No offsite disposal of cuttings to another oil and gas location shall occur without prior approval of a Waste Management Plan (submitted via a Form 4 Sundry Notice) specifying disposal location and waste characterization method. Commercial disposal of drill cuttings will only require notification to COGCC via a Form 4 Sundry Notice. If the well(s) is(are) to be hydraulically stimulated, flowback and stimulation fluids must be sent to tanks, separators, or other containment/filtering equipment before the fluids can be placed into any pipeline or storage vessel 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 constructed to be sufficiently impervious to contain any spilled or released material. Potential odors associated with the completions process and/or with long term production operations must be controlled/mitigated.
OGLA	Form: (02A) 400645428 12/10/2014	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 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 and 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. Inspections shall be conducted by viewing the length of the pipeline; operator will endeavor to minimize surface disturbance during pipeline monitoring. In addition, 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 implement BMPs necessary to mitigate a potential for a release of fluids to impact streams, intermittent streams, ditches, and drainage crossings. For these crossings: if poly pipe is used on the surface, operator will ensure appropriate containment by either installing over-sized pipe “sleeves” which extend the length of the crossing and beyond to a distance deemed adequate to capture (catchment basins) and/or divert any possible release of fluids and prevent fluids from reaching the stream or drainage; installing over-sized pipe “sleeves” which extend the length of the crossing and installing shut off valves on either side of crossing instead of catchment basins; or develop an alternative means for containment. For all other pipeline materials, operator will implement BMPs necessary to mitigate a potential for E&P fluids not to reach groundwater or flowing surface water. 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 temporary surface pipelines. This will reduce surface disturbance and fragmentation of wildlife habitat in the area.

COGIS - Best Management Practice Results

BMP Type	Source Document	Best Management Practices
Planning	Form: (02A ) 400645428 1/16/2015	Maximize the utility of surface facilities by developing multiple wells from a single pad (directional drilling), and by co-locating multipurpose facilities (for example, well pads and compressors) to avoid unnecessary habitat fragmentation and disturbance of additional geographic areas. 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. Where possible, consolidate pipeline and existing roadways, or roadways that are planned for development. Place roads to avoid obstructions to migratory routes for wildlife, and to avoid displacement of wildlife from public to private lands. Maximize the use of directional drilling to minimize habitat loss/fragmentation. Maximize use of long-term centralized tank batteries to minimize traffic. 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 ) 400645428 1/16/2015	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 ) 400645428 1/16/2015	Remove well pad and road surface materials that are incompatible with post-production land use and re-vegetation requirements. 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.