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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	422286	Monument Ridge Pad	TEP ROCKY MOUNTAIN LLC 96850	AC 1/1/2024	PARACHUTE 67350	GARFIELD 045 SESE 18 7S95W 6	422286

COGIS - Conditions of Approval Results

Type	Source Document	Conditions of Approval
OGLA	Form: (02A) 400097171 11/01/2010	SENSITIVE AREA (CLOSE PROXIMITY TO SURFACE WATER AND SHALLOW GROUNDWATER) COAs: Location is in a sensitive area because of its 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; 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., BMPs associated with stormwater management) sufficiently protective of nearby surface water. Location is in a sensitive area because of proximity to a domestic water well and potential for shallow groundwater; therefore either the reserve pit (if constructed) must be lined or a closed loop system (which has already been indicated by Antero on the Form 2A) must be implemented during drilling; Antero will be using a closed loop drilling system, therefore, a reserve pit will not be constructed. WATER RESOURCES (WATER QUALITY TESTING PROGRAM) COA: Water Testing: Prior to drilling operator shall sample the two (2) closest domestic water wells, springs, or surface water features within a one (1) mile radius of the proposed oil and gas location. Testing preference shall be given to domestic water wells and springs over surface water. Testing of surface water features shall only be conducted if two (2) water wells or springs do not exist within a one (1) mile radius of the selected oil and gas location. If possible, the water wells or springs selected should be on opposite sides of the oil and gas location not exceeding a one (1) mile radius. If water wells or springs on opposite sides of the oil and gas location cannot be identified, then the two (2) closest wells or springs within a one (1) mile radius of the oil and gas location shall be sampled. The sample location shall be surveyed in accordance with Rule 215. Initial baseline testing shall include laboratory analysis of all major cations and anions, total dissolved solids, iron and manganese, nutrients (nitrates, nitrites, selenium), dissolved methane, pH, specific conductance, and benzene, toluene, ethylbenzene, and xylenes (“BTEX”). Sampling shall be performed by qualified individuals using methods consistent with commonly accepted environmental sampling procedures. Field observations such as pH, temperature, specific conductance, odor, water color, sediment, bubbles, and effervescence shall also be included. After 90 days, but less than 180 days of completion of the first proposed well a “post-completion” test shall be performed for the same analytical parameters listed above and repeated one (1), three (3) and six (6) years thereafter. If no significant changes from the baseline have been identified after the third test (i.e. the six-year test), no further testing shall be required. Additional “post-completion” test(s) may be required if changes in water quality are identified during follow-up testing. The Director may require further water well sampling at any time in response to complaints from water well owners. If free gas or a methane concentration level greater than 1 mg/l is detected in a water quality testing well, gas compositional analysis, and stable isotopes of both the carbon and hydrogen isotopes of methane shall be performed to determine gas type (thermogenic, biogenic or a mixture). Copies of all analytical data described above shall be provided to the Director and the landowner where the water quality testing well is located within three (3) months of collecting the samples used for the test. The analytical data and surveyed well locations shall also be submitted to the Director in an electronic data deliverable format. Operator will furnish to the Director any analytical results from groundwater or surface water monitoring activities conducted associated with this location in a timely manner.
OGLA	Form: (02A) 400097171 12/20/2010	GENERAL SITE COAs: Notify COGCC Oil and Gas Location Assessment (OGLA) Specialist for Western Colorado (Dave Kubeczko; email dave.kubeczko@state.co.us; phone 970-309-2514) 48 hours prior to start of construction. Flowback and stimulation fluids must be sent to tanks to allow the sand to settle out before the fluids can be placed into any pipeline or pit located on the well pad. The flowback and stimulation fluid tanks 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 (per Rule 604.a.(4)). In addition, operator must implement odor controls during fracing operations. Notify COGCC Oil and Gas Location Assessment (OGLA) Specialist for Western Colorado (Dave Kubeczko; email dave.kubeczko@state.co.us; phone 970-309-2514) 48 hours prior to start of fracing operations. 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. 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. If fluids are conveyed via pipeline, operator must implement best management practices to contain any unintentional release of fluids. The surface soils and materials are fine-grained and highly unconsolidated; therefore the pad shall be constructed as quickly as possible and appropriate BMPs need to be in place both during, after well pad construction completion, as well as during all drilling and well completion operations. Standard stormwater BMPs must be implemented at this location to insure compliance with CDPHE and COGCC requirements and to prevent any stormwater run-on and /or stormwater runoff.
OGLA	Form: (02A) 400097171 12/20/2010	RESIDENTIAL AND HIGH DENSITY AREA COAs: COA R1 - Operator will implement sufficient public notification of proposed oil and gas activities, including: (1) provide 30 day advance notice and community awareness to neighborhood that the monthly Battlement Mesa Oil and Gas Committee meetings will be the forum for communications regarding schedule and activities; (2) schedule changes will be communicated to the community at aforementioned meetings via attendance or emails to the Committee (3) notify local emergency response agencies (Fire/Police) of schedule changes; and (4) notify all homes within a ¼-mile radius and local emergency responders (Fire/Police) 7 days prior to mobilization in, rig up (MIRU). COA R2 - Notify the local emergency responders (Fire/Police), 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 location construction and 24 hours prior to MIRU. COA R3 - Operator will review local governmental requirements for access from public roads. At a minimum the following traffic requirements will apply: (1) operator will work with the Garfield County Road and Bridge Department to develop and implement a traffic control plan that, at a minimum: a) establishes designated haul routes, b) designates haul routes to avoid school zones and schedules heavy equipment movement to avoid school bus operation hours, c) provides for additional signage on major and/or local roads to be employed during heavy activity periods warning of increased truck traffic, d) restricts all oil and gas related construction, drilling, and operational traffic to access the location from a single point, e) provides for flaggers and/or pilot vehicles as necessary, and f) schedules work to avoid peak traffic flow. In addition, the operator will require safe driving training for employees and contractors. COA R4 - Operator will prepare a job specific Emergency Management/Response Plan that will be developed with input from the local emergency responders (Fire/Police). Operator will provide temporary engineering controls to prevent uncontrolled public access during drilling and completion activities. Site security shall include, but not be limited to, appointing a Health and Safety Officer that will insure the Emergency Management/Response Plan is adhered to and who is authorized to shut down operations at any time when health and safety risk is present. COA R5 - Temporary perimeter sound walls (consisting of earthen berms, stacked hay bales, and/or metal, synthetic, or wood sheeting) shall be used on the west, north, and east perimeters of the location during drilling and completion activities to provide noise relief to nearby residents. Operator shall conduct noise monitoring as described in 802.c. at a minimum once during each phase of activity (pad construction, drilling, completion and production), and submit the results to the COGCC. The COGCC may require additional noise mitigation if measures taken are deemed insufficient. COA R6 - Operator will take aggressive action to establish vegetation on cut and fill slopes to prevent storm water erosion and the generation of fugitive dust. Operator shall install and maintain native vegetative visual buffering on the west and east sides in conjunction with site stabilization. Visual mitigation shall also include the use of low profile tanks. COA R7 - Lighting abatement measures beyond the requirements of Rule 803. shall be implemented, including the following, at a minimum: (1) rig oriented to direct light away from nearby residents; (2) install lighting shield devices on all of the more conspicuous lights; (3) low density sodium lighting; and (4) rig shrouded on the west and east sides. COA R9 - For purposes of reducing impacts to nearby residents, flares (such as TCI's partable flare with high combustion rate, low noise, and low visibility flare) will be utilized. COA R10 - Emissions from condensate, crude oil, and produced water tanks and from glycol dehydrators shall be controlled as described in Rule 805.b.(2), not-withstanding the exceptions for production facilities emitting less than five tons per year (TPY) of volatile organic compounds (VOC). COA R11 - Access roads to well sites, completion staging sites and production facilities shall be constructed to meet the requirements of emergency responders, including all weather surface. COA R12 - Land-farming of E&P waste is prohibited on the location. This shall not preclude onsite disposal of E&P waste in accordance with COGCC Rules and permit conditions.
OGLA	Form: (04) 401062469 06/14/2016	Operator shall incorporate drill cuttings brought from the nearby Tompkins Pad (OGCC ID#438312) and beneficially reuse them for the interim reclamation of cut and fill slopes, as well as for base and buildup material for berms to be constructed for noise and visual mitigation. Drill cuttings will be covered or capped with a minimum of 3’ of native soil.
Engineer	Form: (04) 401217551 12/28/2017	1) Operator shall submit an Application for Permit to Drill, Form 2 for each preset conductor by June 1, 2018. Operator shall maintain a valid permit for each preset conductor until the well has been drilled or the conductor has been plugged.

COGIS - Best Management Practice Results

BMP Type	Source Document	Best Management Practices
Site Specific	Form: (02A ) 400097171 3/25/2011	BMP WQ2 - Water Quality Testing: a. Prior to drilling, operator shall test all water wells within ½ mile radius of the surface-hole location from each well on a well pad location and will consider testing springs within ½ mile radius upon landowner request. Within one year or after all wells have been drilled and completed on a well pad location, a post/follow-up test will be performed on all water wells/springs that were tested prior to drilling. b. Initial baseline testing shall include laboratory analysis of all major cations and anions, total dissolved solids, iron and manganese, nutrients (nitrates, nitrites, selenium), dissolved methane, pH, specific conductance, and benzene, toluene, ethylbenzene, and xylenes (“BTEX”). Sampling shall be performed by qualified individuals using methods consistent with commonly accepted environmental sampling procedures. Field observations such as pH, temperature, specific conductance, odor, water color, sediment, bubbles, and effervescence shall also be included. Copies of all analytical data described above shall be provided to the landowner where the water quality testing well is located. In addition, the analytical data and surveyed well locations will be available to the COGCC upon request in an electronic data deliverable format.
Drilling/Completion Operations	Form: (02A ) 400097171 3/25/2011	BMP R8 - Air quality and odor controls will be implemented and will include the following: (1) Emissions from production tank venting will be routed to a VOC combustor and VOC combustors will operate with an auto-igniter; (2) a low emissions flowback process will be used which includes routing the flowback stream to a separator (green completion skid); from this vessel, salable gas will be routed to a gas sales line and the non-salable gas, when practicable, will be routed to a flare equipped with an automatic igniter; (3) frac/flowback storage tank hatches will be closed and latched until the tanks are prepared to receive flowback water, then the hatches will be closed but unlatched when receiving flowback fluids; (4) frac/flowback storage tanks will be equipped with hydrocarbon absorbing blankets when full to control odors; and (5) maintain a portable meteorological weather station during well drilling and completion operations, that includes a data logger to archive wind speed, wind direction, and temperature, and make related data available to the COGCC upon request.
Community Outreach and Notification	Form: (04 ) 400821524 4/9/2015	• Ursa routinely communicates proposed plans and operations schedules with Community Counts and the GARCO Energy Advisory Board. In addition, periodic stakeholder meetings are held with landowners and affected parties. • Communication with Kirby Wynn and municipal LGDs are also held routinely in addition to communication required by COGCC regulations. • Pre-application notifications were not required prior to the submission of the Form 2 submittals as the pad has already been built and an amended Form 2A is not required. • Statutory Notice to Surface Owner and MIRU Notice will be provided in accordance with COGCC rules.
Traffic control	Form: (04 ) 400821524 4/9/2015	• Rule 604.c.(2).D - Ursa has developed a site-specific Emergency Response Plan and Haul Route Map which is communicated to local emergency response agencies and stakeholders, as well as contractors performing work at the location.
General Housekeeping	Form: (04 ) 400821524 4/9/2015	• Rule 604.c.(2).P- Trash containers will be maintained on site. Trash will be hauled to and disposed at a commercial landfill. • Rule 604.c.(2).T- Any and all non-essential equipment, trash, and debris will be removed within 90 days if a proposed well is plugged and abandoned.
Material Handling and Spill Prevention	Form: (04 ) 400821524 4/9/2015	• All materials and chemicals will be managed to minimize environmental contamination. It should be noted that materials and chemicals that are not a waste may be reused or recycled. • Rule 604.c.(2).G - Spill containment will be managed in accordance with Ursa’s EPA SPCC Plan under 40 CFR 112 and in accordance with COGCC Section 600 containment regulations. • Rule 604.c.(2)F - Spill prevention is addressed in Ursa’s Spill Prevention and Management Plan. This includes training of employees and contractors personnel. Spills response includes notifications, reporting, response actions, remediation and corrective actions. The spill criteria in Ursa’s plan requires that waste be properly classified as E&P or non-E&P wastes. For E&P waste, all spills greater than 1 barrel will be reported to the COGCC using a Form 19. Should remediation be required, a Form 27 will be submitted as well. Spills related to non-E&P waste will be managed in accordance with CDPHE and EPA regulations depending on the volume spilled.
Dust control	Form: (04 ) 400821524 4/9/2015	• The pad and access road will be graveled to reduce fugitive dust. In addition, water and other dust suppressants will be applied as needed, dependent upon the level of activity, moisture conditions, etc.
Construction	Form: (04 ) 400821524 4/9/2015	• Rule 604.c.(2).N - The location and site layout has been designed to accommodate all operations, including drilling and completions, within the limits of disturbance while meeting Federal and state safety regulations, including required buffers and distances between operating components and combustion sources in accordance with COGCC Section 600 Rules. • Rule 604.c.(2).M - Fencing will be constructed as required per COGCC regulations. • Rule 604.c.(2)R.- All new and replaced permanent crude oil and condensate storage tanks will meet the current API and NFPA standards. • Rule 604.c.(2).E & V - Existing well pad and access road will be utilized for this well. No new disturbance is anticipated. • Rule 604.c.(2).S - Existing well access road will be used and maintained for all weather use and will meet safety requirements. • Rule 604.c.(2).U – Operator will install a permanent marker per Rule 319.2.(5) when this wellbore is plugged and abandoned.
Noise mitigation	Form: (04 ) 400821524 4/9/2015	• Rule 604.c.(2).A - Noise levels will be in accordance with COGCC Section 800 Rules and any well-specific COAs. • Lighting will be directed down and away from building units.
Drilling/Completion Operations	Form: (04 ) 400821524 4/9/2015	• All NTOs applicable to the Piceance Basin or areas within the Piceance Basin (e.g. Bradenhead testing, well cementing, drilling, chemical disclosure, etc.) will be complied with. • If conductors are set, post drilling water well testing will be performed for permitted water wells in accordance with COGCC Sec 609 as implemented by Ursa’s COGCC Section 609 water sampling plan. • Rule 604.c.(2).B - A closed-loop (pitless) drilling system will be used; No cuttings pit will be constructed; cuttings will be hauled to an approved waste. All waste generated (e.g. cuttings) will be managed in accordance with Ursa’s Waste Management. Cuttings or other wastes that do not meet COGCC Table 910.1 criteria will be disposed of at a facility authorized to accept Exploration and Production (E&P) wastes, in accordance with COGCC Section 900 Rules. • All chemicals used will be tracked and reported in accordance with COGCC rules and submitted through FracFocus within 120 days of initiating well stimulation. • Rule 604.c.(2).C - Well completions will utilize flowback completion technologies and/or flares to reduce odors from plug drillout, and venting of salable and non-salable gas. No stimulation or flowback pits will be constructed. Green completions will be used for this well. • Completions will be conducted during daylight hours to the maximum extent possible. • Combustor controls and related odor reducing measures will be used to mitigate odors from production tanks. • Produced water used for well completions will be recycled and treated to the maximum extent practical. Water that can’t be recycled will be injected through the use of wells approved by COGCC and Garfield County. • Rule 604.c.(2).H - Operator will utilize blowout prevention equipment (BOPE) per COGCC rules. • Rule 604.c.(2).I - Blowout prevention equipment (BOPE) pressure testing will be performed in accordance with COGCC rules. • Rule 604.c.(2).J - All well servicing operations will implement sufficient blowout prevention equipment (BOPE) especially during reverse circulation conditions. • Rule 604.c.(2).K - Pit level indicators will be used. • Rule 604.c.(2).L - Drill stem tests are not anticipated. If drill stem tests are required, they will be conducted in accordance with COGCC rules. • Rule 604.c.(2).O - Load lines will be bullplugged. • Rule 604.c.(2).Q - Guy line anchors will be identified per COGCC rules.