COAs

Skip to Main Content

Facility Type	Facility ID/ API	Facility Name/ Number	Operator Name/ Number	Status	Field Name/ Number	Location	Location ID	Related Facilities
WELL	05-123-46374	Harvesters State 32N-16A-M	PDC ENERGY INC 69175	PR 12/5/2018	WATTENBERG 90750	WELD 123 SWNE 15 6N66W 6	453978

COGIS - Conditions of Approval Results

Type	Source Document	Conditions of Approval
Engineer	Form: (02 ) 401462700 2/8/2018	Attached is a signed consent from Noble for the Burbach 15-23 (API #123-25080) and Burbach 15-22 (API #123-24936).
Engineer	Form: (02 ) 401462700 2/8/2018	In the operator comment box of the Form 5A, operator must certify that the operator did not stimulate within 150’ of an existing wellbore operated by a different operator without a signed waiver from that operator and documentation exists to demonstrate this fact. This will include any existing wellbores from a different operator that were not originally within 150’ of the planned wellbore, but did end up within 150’ of the as-drilled wellbore. Operator agrees to provide this documentation within two business days via email if requested by COGCC staff. Additionally for the well(s) below, operator must provide in that same operator comment box, the name and API of each well, nearest perforation to that well, and final separation (wellbore to wellbore distance) from that well; State-Hoppe 16-3 (API #123-12521)
Engineer	Form: (02 ) 401462700 2/8/2018	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 and prior to stimulation and 2) If a delayed completion, 6-7 months after rig release and prior to stimulation. 3) Within 30 days after first production, as reported on Form 5A.
Engineer	Form: (02 ) 401462700 2/8/2018	Operator acknowledges the proximity of the listed non-producing well(s). Operator agrees to provide mitigation Option 3 (per the DJ Basin Horizontal Offset Policy, ensure all applicable documentation is submitted , and submit Form 42(s) “OFFSET MITIGATION COMPLETED” for the remediated well(s), referencing the API Number of the proposed horizontal wells stating what appropriate mitigation occurred and that it has been completed, prior to the hydraulic stimulation of the proposed wells. State 1 (API #123-05233)
Engineer	Form: (02 ) 401462700 2/8/2018	1) Submit Form 42 electronically to COGCC 48 hours prior to MIRU for the first well activity with a rig on the pad and provide 48 hour spud notice for each subsequent well drilled on the pad. 2) Comply with Rule 317.j and provide cement coverage from TD to a minimum of 200' above the Niobrara. Verify coverage with cement bond log. 3) Oil-based drilling fluid is to be used only after all aquifers are covered.
Permit	Form: (04 ) 401600897 5/4/2018	This Sundry Notice Form 4 authorizes changes in the drilling/casing/cementing program as shown on the Drilling Permit Form 2 and must be visibly posted with the permit during drilling.

COGIS - Best Management Practice Results

BMP Type	Source Document	Best Management Practices
Planning	Form: (02 ) 401462700 2/8/2018	604.c.(2)J.i Blowout Prevention Equipment (“BOPE”): A double ram and annular preventer will be used during drilling. Stabbing valves shall be installed in the event of reverse circulation and shall be prior tested with low and high pressure fluid.
Planning	Form: (02 ) 401462700 2/8/2018	604.c.(2)J.ii Backup stabbing valves 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 ) 401462700 2/8/2018	RULE 604.c.I: 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 shall 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 shall 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 ) 401462700 2/8/2018	604.c.(2)L. Closed chamber drill stem tests shall be allowed. All other drill stem tests shall require approval by the Director. None planned for this well.
Drilling/Completion Operations	Form: (02 ) 401462700 2/8/2018	Operator will comply with COGCC policy for Bradenhead Monitoring During Hydraulic Fracturing Treatments in the Greater Wattenberg area dated May 29, 2012.
Drilling/Completion Operations	Form: (02 ) 401462700 2/8/2018	Anti-collision: Operator will perform an anti-collision evaluation of all active (producing, shut in, or temporarily abandoned) offset wellbores that have the potential of being within 150 feet of a proposed well prior to drilling operations for the proposed well. Notice shall be given to all offset operators prior to drilling.
Drilling/Completion Operations	Form: (02 ) 401462700 2/8/2018	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.
Planning	Form: (04 ) 401600897 5/9/2018	604.c.(2)J.ii Backup stabbing valves 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.
Planning	Form: (04 ) 401600897 5/9/2018	604.c.(2)J.i Blowout Prevention Equipment (“BOPE”): A double ram and annular preventer will be used during drilling. Stabbing valves shall be installed in the event of reverse circulation and shall be prior tested with low and high pressure fluid.
Drilling/Completion Operations	Form: (04 ) 401600897 5/9/2018	Operator will comply with COGCC policy for Bradenhead Monitoring During Hydraulic Fracturing Treatments in the Greater Wattenberg area dated May 29, 2012.
Drilling/Completion Operations	Form: (04 ) 401600897 5/9/2018	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.
Drilling/Completion Operations	Form: (04 ) 401600897 5/9/2018	604.c.(2)L. Closed chamber drill stem tests shall be allowed. All other drill stem tests shall require approval by the Director. None planned for this well.
Drilling/Completion Operations	Form: (04 ) 401600897 5/9/2018	Operator will perform an anti-collision evaluation of all active (producing, shut in, or temporarily abandoned) offset wellbores that have the potential of being within 150 feet of a proposed well prior to drilling operations for the proposed well. Notice shall be given to all offset operators prior to drilling.
Drilling/Completion Operations	Form: (04 ) 401600897 5/9/2018	RULE 604.c.I: 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 shall 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 shall 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.