COAs

Facility Type	Facility ID/ API	Facility Name/ Number	Operator Name/ Number	Status	Field Name/ Number	Location	Location ID	Related Facilities
WELL	05-123-38301	Pratt 4C-29H-P168	CRESTONE PEAK RESOURCES OPERATING LLC 10633	PR 11/16/2017	WATTENBERG 90750	ERIE/WELD 123 SESE 29 1N68W 6	434526

COGIS - Conditions of Approval Results

Type	Source Document	Conditions of Approval
Permit	Form: (02 ) 400426687 8/13/2013	Operator must meet water well testing requirements per Rule 318A.
Engineer	Form: (02 ) 400426687 9/20/2013	Operator acknowledges the proximity of the non-operated Carr 1, (API NO 123-10017), and the Pezoldt 1-32, (API NO 123-15040) wells. Operator assures that this offset will be remediated per the DJ Basin Horizontal Offset Policy (options 1 or 2) or operator will address this well with mitigation option 4. Operator will submit a Form 42 (“OTHER – AS SPECIFIED BY PERMIT CONDITION”) stating what appropriate mitigation occurred and that it has been completed, prior to the hydraulic stimulation of this well.
Engineer	Form: (02 ) 400426687 9/20/2013	1) Submit Form 42 electronically to COGCC 48 hours prior to MIRU. 2) Comply with Rule 317.i and provide cement coverage from the end of the 7” casing shoe to a minimum of 200' above Niobrara. Verify coverage with cement bond log. 3) Run and submit Directional Survey from TD to base of surface casing. The operator shall comply with Rule 321, and it shall be the operator’s responsibility to ensure that the wellbore complies with setback requirements in commission orders or rules prior to producing the well.
Engineer	Form: (02 ) 400426687 9/25/2013	Operator acknowledges the proximity of the William H Peltier 2, (API NO 123-12614) well. Operator agrees to: provide mitigation option 1 or 2 (per the DJ Basin Horizontal Offset Policy) to mitigate the situation, ensure all applicable documentation is submitted based on the selected mitigation option chosen, and submit a Form 42 (“OTHER – AS SPECIFIED BY PERMIT CONDITION”) stating what appropriate mitigation occurred and that it has been completed, prior to the hydraulic stimulation of this well.
Engineer	Form: (02 ) 400873935 9/21/2015	1) Note surface casing depth change from 889’ to 950’. Increase cement volumes accordingly. 2) Submit Form 42 electronically to COGCC 48 hours prior to MIRU. 3) Comply with Rule 317.j and provide cement coverage from end of 7” casing to a minimum of 200' above Niobrara. Verify coverage with cement bond log. 4) 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 ) 400873935 9/21/2015	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 a 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. William H Peltier 2 (API NO 123-12614)
Engineer	Form: (02 ) 400873935 9/21/2015	Operator acknowledges the proximity of the listed non-operated 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. Carr 1 (API NO 123-10017) Pezoldt 1-32 (API NO 123-15040)
Engineer	Form: (04 ) 401290134 5/31/2017	Bradenhead tests shall be performed according to the following schedule and the Form 17 submitted within 10 days of each test: 1) Within 60 days of rig release and prior to stimulation and 2) If a delayed completion, 6 months after rig release and prior to stimulation. 3) Within 30 days after first production, as reported on Form 5A.
Engineer	Form: (04 ) 401290134 5/31/2017	1) 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. 2) 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. 3) Comply with Rule 317.j. and provide cement coverage from TD to a minimum of 200' above Niobrara. Verify coverage with cement bond log.
Engineer	Form: (04 ) 401290134 5/31/2017	In a comment on the Form 5A submit tab, operator will provide the following information for any other wells owned by another operator within 150’ of the current as-drilled wellbore: well name and API number, the depth of the perforation in this well nearest to the treated interval of the offset well, and the distance between the wells at that depth to ensure compliance with 317.s Statewide Fracture Stimulation Setback.

COGIS - Best Management Practice Results

BMP Type	Source Document	Best Management Practices
Planning	Form: (02 ) 400426687 10/17/2013	Prior to commencement of any new drilling or completion operations, provide to an Erie designated staff member the following for the well-site for informational purposes only, which Encana may revise from time to time during operations: a) A summary of planned operations, including identified access points and operational timeline, for posting to a local community information web-page b) A site plan for site preparation, mobilization and demobilization c) A plan for interim reclamation and vegetation of the site and final reclamation of the site d) A plan for noise, light and dust mitigation, to the extent feasible e) A traffic management plan f) Updates of this information if any change during operations
Planning	Form: (02 ) 400426687 10/17/2013	Maximize equipment and wellhead setbacks from occupied buildings and residences to the extent feasible and practicable, as determined by Encana.
Community Outreach and Notification	Form: (02 ) 400426687 10/17/2013	Prior to commencement of any new drilling or completion operations, provide notification to landowners within one-half (1/2) mile of the well-site.
Drilling/Completion Operations	Form: (02 ) 400426687 10/17/2013	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 well path 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 ) 400426687 10/17/2013	Utilize closed-loop systems for drilling and completion operations to minimize the need for earthen pits
Drilling/Completion Operations	Form: (02 ) 400426687 10/17/2013	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 ) 400426687 10/17/2013	Utilize a high-low pressure vessel (HLP) and vapor recovery unit (VRU) for new wells drilled. Encana may remove the VRU system at such time Encana determines that the VRU system is no longer necessary due to reduced emission recoveries and/or efficiencies, but no earlier than one (1) year after the new well is drilled
Drilling/Completion Operations	Form: (02 ) 400426687 10/17/2013	Utilize steel-rim berms around tanks and separators instead of sand or soil berms
Planning	Form: (02 ) 400873935 10/5/2015	Maximize equipment and wellhead setbacks from occupied buildings and residences to the extent feasible and practicable, as determined by Encana.
Community Outreach and Notification	Form: (02 ) 400873935 10/5/2015	Prior to commencement of any new drilling or completion operations, provide to an Erie designated staff member the following for the well-site for informational purposes only, which Encana may revise from time to time during operations: a) A summary of planned operations, including identified access points and operational timeline, for posting to a local community information web-page b) A site plan for site preparation, mobilization and demobilization c) A plan for interim reclamation and vegetation of the site and final reclamation of the site d) A plan for noise, light and dust mitigation, to the extent feasible e) A traffic management plan f) Updates of this information if any change during operations
Community Outreach and Notification	Form: (02 ) 400873935 10/5/2015	Prior to commencement of any new drilling or completion operations, provide notification to landowners within one-half (1/2) mile of the well-site.
Material Handling and Spill Prevention	Form: (02 ) 400873935 10/5/2015	Utilize steel-rim berms around tanks and separators instead of sand or soil berms
Drilling/Completion Operations	Form: (02 ) 400873935 10/5/2015	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 ) 400873935 10/5/2015	Adequate blowout prevention equipment will be used on all well servicing operations.
Drilling/Completion Operations	Form: (02 ) 400873935 10/5/2015	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 ) 400873935 10/5/2015	No drill stem tests will be performed.
Drilling/Completion Operations	Form: (02 ) 400873935 10/5/2015	Prior to drilling operations, Encana 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, the 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 ) 400873935 10/5/2015	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 ) 400873935 10/5/2015	Utilize closed-loop systems for drilling and completion operations to minimize the need for earthen pits
Drilling/Completion Operations	Form: (02 ) 400873935 10/5/2015	Utilize a high-low pressure vessel (HLP) and vapor recovery unit (VRU) for new wells drilled. Encana may remove the VRU system at such time Encana determines that the VRU system is no longer necessary due to reduced emission recoveries and/or efficiencies, but no earlier than one (1) year after the new well is drilled
Drilling/Completion Operations	Form: (02 ) 400873935 10/5/2015	One of the first wells drilled on the pad will be logged with Cased-hole Pulsed Neutron Log with Gamma Ray Log from TD 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.

COGIS DB