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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	05-123-45542	Buford 33-10-4L	PROVIDENCE OPERATING LLC DBA POCO OPERATING 10694	PR 5/1/2024	WATTENBERG 90750	WELD 123 SWSW 33 1N65W 6	452048

COGIS - Conditions of Approval Results

Type	Source Document	Conditions of Approval
Engineer	Form: (02 ) 401299846 9/14/2017	Operator acknowledges the proximity of the listed non-operated wells. Operator assures that this offset list will be remediated per the DJ Basin Horizontal Offset Policy (option 4). Operator will submit a Form 42 (“OTHER – AS SPECIFIED BY PERMIT CONDITION”) stating that appropriate mitigation will be completed, during the hydraulic stimulation of this well. This Form 42 shall be filed 48 hours prior to stimulation. Strawder 1 (API 123-10497) Neckien 1 (API 123-10540) Operator acknowledges the proximity of the listed non-operated wells. Operator assures that this offset list will be remediated per the DJ Basin Horizontal Offset Policy (option 3). Operator will submit a Form 42 (“OFFSET MITIGATION COMPLETED”) stating what appropriate mitigation occurred and that it has been completed, prior to the hydraulic stimulation of this well. Champlin 365 Amoco Unit A 2 (API 05-123-10181)
Engineer	Form: (02 ) 401299846 9/14/2017	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: (02 ) 401299846 9/14/2017	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) Comply with Rule 317.j. and provide cement coverage from TD to a minimum of 200' above Niobrara and from 200’ below Sussex to 200’ above Sussex. Verify coverage with cement bond log.

COGIS - Best Management Practice Results

BMP Type	Source Document	Best Management Practices
Drilling/Completion Operations	Form: (02 ) 401299846 9/26/2017	Rig with Kelly: The BOP will include a minimum of double ram with blind ram pipe ram, annular preventer or a rotating head. At least one (1) person with training for blowout prevention will be on location during all drilling operations. Rig without Kelly. The BOP will include a minimum of double ram with blind ram and pipe ram. At least one (1) person with training for blowout prevention will be on location during all drilling operations. Confluence will utilize drilling rigs with a minimum of a double ram and annular preventer.
Drilling/Completion Operations	Form: (02 ) 401299846 9/26/2017	BOPE tests will be run upon initial rig-up and at least once every thirty (30) days during drilling operations. 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 will be conducted and the documented results will be retained by the Confluence for inspection by the Director for a period of one (1) year. Activation of the pipe rams for function testing will be conducted on a daily basis when practicable. Adequate blowout prevention equipment will be used on all well servicing operations. Adequate blowout prevention equipment will be used on any servicing operations associated with this well. Stabbing valves will be installed in the event of reverse circulation and will be tested prior with low and high pressure fluid. Valves will be pressure tested before each well servicing operation using both low-pressure and high-pressure fluid.
Drilling/Completion Operations	Form: (02 ) 401299846 9/26/2017	Adequate blowout prevention equipment will be used on any servicing operations associated with this well. Backup staving valves shall be required on well servicing operations during reverse circulation. Valves will be pressure tested before each well servicing operation using both low-pressure and high-pressure fluid.
Drilling/Completion Operations	Form: (02 ) 401299846 9/26/2017	Logging: One of the first wells drilled on the pad will be logged with open-hole Resistivity Log and Gamma Ray Log from the kick-off point 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 and have those logs attached. The Form 5 for a well without open-hole logs shall clearly state “No open-hole logs were run” and shall clearly identify (by API#, well name & number) the well in which open-hole logs were run.
Drilling/Completion Operations	Form: (02 ) 401299846 9/26/2017	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 ) 401299846 9/26/2017	Bradenhead Monitoring: Operator acknowledges and will comply with COGCC Policy for Braden-head Monitoring during Hydraulic Fracturing Treatments in the Greater Wattenberg Area dated May 29, 2012.