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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	05-123-43298	Morgan Hills 1A-7H-A168	CRESTONE PEAK RESOURCES OPERATING LLC 10633	PR 1/1/2024	WATTENBERG 90750	ERIE/WELD 123 NENE 7 1N68W 6	446290

COGIS - Conditions of Approval Results

Type	Source Document	Conditions of Approval
Engineer	Form: (02 ) 400651401 10/3/2015	1) Submit Form 42 electronically to COGCC 48 hours prior to MIRU. 2) Comply with Rule 317.j and provide cement coverage from end of 7” casing to a minimum of 200' above Niobrara and from 200’ below the Shannon to 200’ above Sussex. Verify coverage with cement bond log. 3) Comply with Rule 321. Run and submit Directional Survey from TD to base of surface casing. Ensure that the wellbore complies with setback requirements in commission orders or rules prior to producing the well.
Engineer	Form: (02 ) 400651401 10/3/2015	Operator acknowledges the proximity of the listed wells. Operator agrees to provide mitigation Option 1 or 2 (per the DJ Basin Horizontal Offset Policy), ensure all applicable documentation is submitted, and submit Form 42(s) “OFFSET MITIGATION COMPLETED” for the remediated wells, referencing the API Number of the proposed horizontal well(s) stating what appropriate mitigation occurred and that it has been completed, prior to the hydraulic stimulation of this well. Woolley B 1-8 (API 123-09528) Erie Champlin B Unit 1 (API 123-12377)
Permit	Form: (02 ) 400651401 6/6/2016	The approved Form 2A for this location will be posted onsite during construction, drilling, and completions operations.
Engineer	Form: (02 ) 400651401 6/13/2016	Bradenhead tests shall be performed and reported according to the following schedule and Form 17 submitted within 10 days of each test.: 1) Within 60 days of rig release, prior to stimulation. 2) 6 months after rig release, prior to stimulation. 3) Within 30 days of first production, as reported on Form 5A.
Engineer	Form: (04 ) 401134513 11/4/2016	1) This Form 4 makes changes to the casing and cementing program approved on the Form 2 and must be displayed with the Form 2 while drilling. 2) Submit Form 42 electronically to COGCC 48 hours prior to MIRU (spud notice) for the first well activity with a rig on the pad and provide 48 hour spud notice via Form 42 for all subsequent wells drilled on the pad. 3) Comply with Rule 317.j. and provide cement coverage from TD to a minimum of 200' above Niobrara and from 200’ below Shannon to 200’ above Sussex. Verify coverage with cement bond log.
Engineer	Form: (04 ) 401134513 11/4/2016	Operator acknowledges the proximity of the listed wells. Operator agrees to provide mitigation Option 1 or 2 (per the DJ Basin Horizontal Offset Policy), ensure all applicable documentation is submitted, and submit Form 42(s) “OFFSET MITIGATION COMPLETED” for the remediated wells, referencing the API Number of the proposed horizontal well(s) stating what appropriate mitigation occurred and that it has been completed, prior to the hydraulic stimulation of this well. Woolley B 1-8 (API 123-09528) Erie Champlin B Unit 1 (API 123-12377) Thomas E Unit 1 (API 123-10710)

COGIS - Best Management Practice Results

BMP Type	Source Document	Best Management Practices
Community Outreach and Notification	Form: (02 ) 400651401 6/22/2016	Prior to any new operations, provide notification to landowners within 1/2 mile
Community Outreach and Notification	Form: (02 ) 400651401 6/22/2016	Prior to any new operations, provide designated staff member the following: A site plan for site preparation, mobilization, and demobilization; A plan for interim reclamation and re-vegetation and final reclamation of the site; A plan for noise, light, and dust mitigation, to the extent feasible and where applicable; A traffic management plan; Update of this information if any plans change during operations
Material Handling and Spill Prevention	Form: (02 ) 400651401 6/22/2016	Utilize steel-rim berms around tanks and separators instead of sand or soil
Construction	Form: (02 ) 400651401 6/22/2016	Maximize equipment and wellhead setbacks from occupied buildings and residences
Drilling/Completion Operations	Form: (02 ) 400651401 6/22/2016	Closed-top tanks will utilize backpressure systems that exert a minimum of four (4) ounces of backpressure and a maximum that does not exceed the pressure rating of the tank to facilitate gathering and combustion of tank.
Drilling/Completion Operations	Form: (02 ) 400651401 6/22/2016	Upon initial rig-up and at least once every thirty (30) days during drilling operations thereafter, pressure testing of the casing string and each component of the blowout prevention equipment including flange connections will be performed to seventy percent (70%) of working pressure or seventy percent (70%) of the internal yield of casing, whichever is less. Pressure testing shall be conducted and the documented results will be retained by the operator for inspection by the Director for a period of one (1) year. Activation of the pipe rams for function testing shall be conducted on a daily basis when practicable.
Drilling/Completion Operations	Form: (02 ) 400651401 6/22/2016	Adequate blowout prevention equipment will be used on all well servicing operations.
Drilling/Completion Operations	Form: (02 ) 400651401 6/22/2016	Backup stabbing valves shall be required on well servicing operations during reverse circulation. Valves shall be pressure tested before each well servicing operation using both low-pressure air and high-pressure fluid.
Drilling/Completion Operations	Form: (02 ) 400651401 6/22/2016	Prior to drilling operations, Operator will perform an anti-collision scan of existing offset wells that have the potential of being within close proximity of the proposed well. This anti-collision scan will include definitive MWD or gyro surveys of the offset wells with included error of uncertainty per survey instrument, and compared against the proposed wellpath with its respective error of uncertainty. If current surveys do not exist for the offset wells, Operator may have gyro surveys conducted to verify bottomhole location. The proposed well will only be drilled if the anti-collision scan results indicate that there is not a risk for collision, or harm to people or the environment. For the proposed well, upon conclusion of drilling operations, an as-constructed gyro survey will be submitted to COGCC with the Form 5.
Drilling/Completion Operations	Form: (02 ) 400651401 6/22/2016	Encana will comply with the “COGCC Policy for Bradenhead Monitoring During Hydraulic Fracturing Treatments in the Greater Wattenberg Area”, dated May 29, 2012.
Drilling/Completion Operations	Form: (02 ) 400651401 6/22/2016	Utilize multistage pressure separation in conjunction with a vapor recover unit for new wells
Drilling/Completion Operations	Form: (02 ) 400651401 6/22/2016	Utilize close-loop system for drilling and completion operations
Drilling/Completion Operations	Form: (02 ) 400651401 6/22/2016	One of the first wells drilled on the pad will be logged with Cased hole Pulsed Neutron Log with Gamma Ray Log from the kick-off point to into the surface casing. All wells on the pad will have a cement bond log with gamma-ray run on production casing (or on intermediate casing if production liner is run) into the surface casing. The horizontal portion of every well will be logged with a measured while-drilling gamma-ray log. The Form 5, Completion Report, for each well on the pad will list all logs run in that well and have those logs attached. The Form 5 for each well shall clearly state “No open-hole logs were run” and shall reference the Rule 317.p Exception granted for the well.