COGIS - Conditions of Approval Results

   CONFLUENCE DJ LLC    Buford 33-2-2L   WELL#: 453112   Status:XX as of 12/28/2020 5:10:02 PM   SWSW 34 1N 65W WELD COUNTY
Search Results - 10 record(s) returned.
Type Source Conditions of Approval
Best Management Practices
Permit
02
402437890
12/3/2020
If conductors are preset, Operator shall comply with Notice to Operators: Procedures for Preset Conductors (dated September 1, 2016, revised October 6, 2016).

Permit
02
402437890
12/3/2020
Operator shall comply with Notice to Operators: Interim Reclamation Procedures for Delayed Operation (dated January 5, 2017).

Engineer
02
402437890
12/2/2020
Per COGCC Order 1-232, Bradenhead tests shall be performed 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. If any pressure greater than 200 psi, must contact COGCC engineer prior to stimulation.
2) If a delayed completion, 6 months after rig release and prior to stimulation. If any pressure greater than 200 psi, must contact COGCC engineer prior to stimulation.
3) A post-production test within 60 days after first sales, as reported on the Form 10, Certificate of Clearance.

Engineer
02
402437890
9/4/2020
In a comment on the Form 5A submit tab, operator will provide the following information for any other wells belonging to 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. Operator will provide the certification that they are in compliance with 317.s

Engineer
02
402437890
9/4/2020
Operator acknowledges the proximity of the non-operated listed wells. 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 (“OFFSET MITIGATION COMPLETED”) stating that appropriate mitigation occurred and that it has been completed, prior to the hydraulic stimulation of these wells.
API#123-10497, STRAWDER 1
API#123-10540, NECKIEN 1 
API#123-12567, JORDAN 34-3

Engineer
02
402437890
9/4/2020
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 these wells.
API#123-10319, GLEN YOUNG 1 
API#123-10449, GLEN YOUNG 2
API#123-10181, CHAMPLIN 365 AMOCO UNIT A 2 
API#123-19677, HSR-CHERRY KNOLLS 9-33 
API#123-12937, JORDAN 34-9
API#123-14809, JORDAN-LOUSTAUNAU 34-10

Engineer
02
402437890
9/4/2020
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 500' above Niobrara. Verify coverage with cement bond log. 
3) Oil-based drilling fluid is to be used only after all fresh water aquifers are covered.

Engineer
02
401305424
9/13/2017
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. 

Engineer
02
401305424
9/13/2017
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
02
401305424
9/13/2017
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)
Jordan 34-9 (API 05-123-12937)
Jordan-Loustaunau 34-10 (API 123-14809)

COGIS - Best Management Practices COGIS - Best Management Practices Results

Search Results - 8 record(s) returned.
BMP TypeSource BMP
Drilling/Completion Operations
02
401305424
6/13/2017
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
02
402437890
10/12/2020
Logging: The Judy 3-4, API No. 05-123-50294, well drilled on the pad was logged with an 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. The Judy 3-4, API No. 05-123-50294, is the well in which open-hole logs were run.
Drilling/Completion Operations
02
402437890
10/12/2020
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
02
401305424
6/13/2017
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
02
401305424
6/13/2017
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
02
402437890
10/12/2020
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.
Drilling/Completion Operations
02
401305424
6/13/2017
Confluence 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 will be given to all offset operators within 150 feet prior to drilling.
Drilling/Completion Operations
02
401305424
6/13/2017
Operator acknowledges and will comply with COGCC policy for Bradenhead Monitoring during Hydraulic fracturing treatments in the Greater Wattenberg Area dated May 29, 2012.