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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	335035	PA 14-6 Pad	TEP ROCKY MOUNTAIN LLC 96850	AC 10/7/2016	PARACHUTE 67350	GARFIELD 045 SWSW 6 7S95W 6	335035

COGIS - Conditions of Approval Results

Type	Source Document	Conditions of Approval
OGLA	Form: (02A) 400445219 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) 400445219 10/15/2013	Operator must implement best management practices to contain any unintentional release of fluids, including any fluids conveyed via temporary surface pipelines or buried permanent pipelines. Operator must ensure secondary containment for any volume of fluids contained at well site during drilling and completion 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 maintained in good condition. 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) 400445219 10/15/2013	The moisture content of any 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, if the drill cuttings are to be left onsite, they must also meet the applicable standards of table 910-1. 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.
Agency	Form: (02A) 400445219 10/25/2013	Requested operator review the distance from completed portion of wellbore to nearest lease line, says 376' looks to be closer to 720'. Also, the distance to the nearest railroad, says 364' looks closer to 1650'.

COGIS - Best Management Practice Results

BMP Type	Source Document	Best Management Practices
Planning	Form: (02A ) 400445219 11/23/2013	* 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. * 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
General Housekeeping	Form: (02A ) 400445219 11/23/2013	Although this location is located within 500 ft. of perennial, ephemeral, or intermittent surface water according to USGS mapped surface waters, the attached Sensitive Area Determination concludes that the location is not within a sensitive area due to the low potential for impacts to surface water in the case of a facility release. However, in order to satisfy COGCC guidance requiring that all locations within 500 ft. of mapped surface water incorporate BMPs to protect that surface water, Williams will employ the following BMPs at this location: • Williams will ensure 110 percent secondary containment for any volume of fluids contained at well site during drilling and completion operations. • Williams will implement best management practices to contain any unintentional release of fluids. • Either a lined drilling pit or closed loop system will be implemented.
Drilling/Completion Operations	Form: (02A ) 400445219 11/23/2013	* Conduct well completions with drilling operations to limit the number of rig moves and traffic.
Interim Reclamation	Form: (02A ) 400445219 11/23/2013	* 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.