COGIS - COA/BMP Information

EXTRACTION OIL & GAS INC           GP J EVANS FED 20W-20-16           Well API # 05-123-41134           Status: XX        Status Date: 12/06/2018           Location ID #:332837       NENE 20 5N 65W WELD

COGIS - Conditions of Approval
COA Search Results - 14 record(s) returned.
Source
Document
Conditions of Approval
Form: (02 )
400407756
02/10/2015
1) Submit Form 42 electronically to COGCC 48 hours prior to MIRU. 2) Comply with Rule 317.i and provide cement coverage from end of 7” casing 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.
Form: (02 )
400407756
02/10/2015
Open hole resistivity and gamma logs shall be run to describe the stratigraphy of the entire well bore and to adequately verify the setting depth of surface casing and aquifer coverage. On a multi-well pad, these open hole logs are only required on one of the first wells drilled on the pad and the Drilling Completion Report - Form 5 for every well on the pad shall identify which well was logged.
Form: (02 )
400407756
02/10/2015
Operator shall comply with Buffer Zone Move-In, Rig-Up Notice Policy dated 12-16-2013.
Form: (02 )
401048553
03/17/2017
1) Submit Form 42 electronically to COGCC 48 hours prior to MIRU (Spud Notice), for the first well/activity on the pad and provide 48 hour spud notice for all subsequent wells drilled on the pad. 2) Comply with Rule 317.j and provide cement coverage from the end of production casing to a minimum of 200' above Niobrara. Verify coverage with cement bond log.
Form: (02 )
401048553
03/17/2017
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 or 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.
Form: (02 )
401048553
03/17/2017
Revised “1st Liner”, on the Casing Tab, to “1st String”, since the string starts at the surface, it is considered a String and not a Liner.
Form: (02 )
401048553
03/17/2017
This Permit to Drill is approved subject to all the BMPs and COAs on the most recently approved Form 2A and any subsequently approved Form 4 for the Oil and Gas Location (Location ID #332837). The most recently approved Form 2A and any subsequent Form 4s containing applicable COAs for this location shall be posted onsite during construction, drilling, and completions operations.
Form: (02 )
401704908
03/15/2019
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.
Form: (02 )
401704908
03/15/2019
Operator will submit signed Rule 317.s Stimulation Setback Consents via Sundry Notice, Form 4 prior to stimulation of this well. In the Form 5A comments, operator will (1) certify that this well has no treated interval within 150’ of the treated interval of another operator’s well for which a signed Stimulation Setback Consent was not obtained, (2) provide the following information for all other operator’s offset wells without consent that have a treated interval within 150’ of this as-drilled wellbore: well name and API number, 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, and (3) address the wells listed below as either (a) obtained consent or (b) treated interval more than 150’ away from this as-drilled wellbore. Segl 2-24 (API 123-23841)
Form: (02 )
401704908
03/15/2019
1) Submit Form 42 electronically to COGCC 48 hours prior to MIRU (Spud Notice), for the first well/activity on the pad and provide 48 hour spud notice for all subsequent wells drilled on the pad. 2) Comply with Rule 317.j and provide cement coverage from the end of production casing to a minimum of 200' above Niobrara and from 200’ below Sussex to 200’ above Sussex. Verify coverage with cement bond log. 3) Oil-based drilling fluid is to be used only after all fresh water aquifers are covered.
Form: (02 )
401704908
03/15/2019
Operator shall comply with Notice to Operators: Interim Reclamation Procedures for Delayed Operation (dated January 5, 2017).
Form: (02 )
401704908
03/15/2019
If conductors are preset, Operator shall comply with Notice to Operators: Procedures for Preset Conductors (dated September 1, 2016, revised October 6, 2016).
Form: (02 )
401704908
03/15/2019
This Permit to Drill is approved subject to all the BMPs and COAs on the most recently approved Form 2A and any subsequently approved Form 4 for the Oil and Gas Location (Location ID #332837). The most recently approved Form 2A and any subsequent Form 4s containing applicable COAs for this location shall be posted onsite during construction, drilling, and completions operations.
Form: (04 )
402027572
05/15/2019
COA: 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 Practices
BMPSearch Results - 30 record(s) returned.
Source
Document
BMP TypeBMP
Form: (02 )
400407756
02/10/2015
Planning
Multi-well Pads. It is a multi-well pad located in a manner which allows for resource extraction while maintaining the highest distances possible from the offsetting residential areas.
Form: (02 )
400407756
02/10/2015
Traffic control
Access roads. The access road will be constructed to accommodate local emergency vehicles. This road will be maintained for access at all times.
Form: (02 )
400407756
02/10/2015
General Housekeeping
Fencing requirements. A permanent fencing plan will be reviewed by the surface owner, & the applicant.
Form: (02 )
400407756
02/10/2015
General Housekeeping
Removal of surface trash. All trash, debris and material not intrinsic to the operation of the oil and gas facility shall be removed and legally disposed of as is applicable.
Form: (02 )
400407756
02/10/2015
Material Handling and Spill Prevention
Leak Detection Plan. Pumper will visit the location daily and visually inspect all tanks and fittings for leaks. Additionally, monthly documented SPCC inspections are conducted pursuant to 40 CFR §112.
Form: (02 )
400407756
02/10/2015
Material Handling and Spill Prevention
Berm construction. Tank berms shall be constructed of steel rings with a synthetic or engineered liner and designed to contain 150% of the capacity of the largest tank. All berms will be visually checked periodically to ensure proper working condition.
Form: (02 )
400407756
02/10/2015
Material Handling and Spill Prevention
Load-lines. All load-lines shall be bull-plugged or capped.
Form: (02 )
400407756
02/10/2015
Material Handling and Spill Prevention
Tank specifications. Tanks will be designed, constructed and maintained in accordance with NFPA Code 30. The tanks are visually inspected once a day for issues, and recorded inspections are conducted once a month.
Form: (02 )
400407756
02/10/2015
Noise mitigation
Lighting abatement measures shall be implemented, including the installation lighting shield devices on all of the more conspicuous lights, & low density sodium lighting where practicable. At its election the operator may install temporary engineering controls consisting of perimeter sound walls shall be used on the location during drilling and completion activities to provide noise relief. Permanent equipment on location shall be muffled to reduce noise, or shall be appropriately buffered.
Form: (02 )
400407756
02/10/2015
Drilling/Completion Operations
Closed Loop Drilling Systems – Pit Restrictions. Not applicable; a closed-loop system will be used for drilling.
Form: (02 )
400407756
02/10/2015
Drilling/Completion Operations
Green Completions – Emission Control Systems. Test separators and associated flow lines and sand traps shall be installed on-site to accommodate Green completions techniques pursuant to COGCC Rules. In the anticipated absence of a viable gas sales line, the flow-back gas shall be thermally oxidized in an emissions control device (ECD), which will be installed and kept in operable condition for least the first 90-days of production pursuant to CDPHE rules. This ECD shall have an adequate capacity for 1.5 times the largest flow-back within a 10 mile radius, will be flanged to route gas to other or permanent oxidizing equipment and shall be provided with the equipment needed to maintain combustion where noncombustible gases are present.
Form: (02 )
400407756
02/10/2015
Drilling/Completion Operations
Blowout preventer equipment (“BOPE”). A double ram and annular preventer will be used during drilling. At least the drilling company shall have a valid well blowout prevention certifications.
Form: (02 )
400407756
02/10/2015
Drilling/Completion Operations
BOPE for well servicing operations. Adequate BOP equipment shall be used. Stabbing valves shall be installed in the event of reverse circulation and shall be prior tested with low and high pressure fluid.
Form: (02 )
400407756
02/10/2015
Drilling/Completion Operations
Pit level indicators. Not applicable; a closed-loop system will be used and no pits shall be dug.
Form: (02 )
400407756
02/10/2015
Drilling/Completion Operations
Drill stem tests. Not applicable; no Drill Stem tests are planned.
Form: (02 )
400407756
02/10/2015
Drilling/Completion Operations
Control of fire hazards. All materials which are considered fire hazards shall be a minimum of 25’ from the wellhead tanks or separators. Electrical equipment shall comply with API RP 500 and will comply with the current national electrical code. An emergency response plan has been generated for this site.
Form: (02 )
400407756
02/10/2015
Drilling/Completion Operations
Guy line anchors. All guy line anchors shall be brightly marked pursuant to Rule 604.c (2)Q
Form: (02 )
400407756
02/10/2015
Drilling/Completion Operations
Bradenhead Monitoring BMP: Operator will comply with COGCC Policy for Bradenhead Monitoring During Hydraulic Fracturing Treatments in the Greater Wattenberg Area dated May 29, 2012.
Form: (02 )
400407756
02/10/2015
Drilling/Completion Operations
Anti-Collision BMP: 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 wells. 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.
Form: (02 )
400407756
02/10/2015
Final Reclamation
Well site cleared. Within 90-day subsequent to the time of plugging and abandonment of the entire site, superfluous debris and equipment shall be removed from the site.
Form: (02 )
400407756
02/10/2015
Final Reclamation
Identification of plugged and abandoned wells. P&A’d wells shall be identified pursuant to 319.a.(5).
Form: (02 )
401048553
03/17/2017
Planning
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.
Form: (02 )
401048553
03/17/2017
Planning
604.c.(2)J.ii Backup stabbing valves will 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.
Form: (02 )
401048553
03/17/2017
Drilling/Completion Operations
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.
Form: (02 )
401048553
03/17/2017
Drilling/Completion Operations
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.
Form: (02 )
401048553
03/17/2017
Drilling/Completion Operations
Operator acknowledges and will comply with COGCC policy for Bradenhead Monitoring during Hydraulic Fracturing treatments in the Greater Wattenberg Area dated May 29, 2012.
Form: (02 )
401048553
03/17/2017
Drilling/Completion Operations
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.
Form: (02 )
401704908
03/15/2019
Drilling/Completion Operations
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.
Form: (02 )
401704908
03/15/2019
Drilling/Completion Operations
Operator acknowledges and will comply with COGCC policy for Bradenhead Monitoring during Hydraulic Fracturing treatments in the Greater Wattenberg Area dated May 29, 2012.
Form: (02 )
401704908
03/15/2019
Drilling/Completion Operations
317.p 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.