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	05-123-48766	EWS 4B	EWS 4 DJ BASIN LLC 10649	IJ 6/6/2023	WATTENBERG 90750	KEENESBURG/WELD 123 NESE 18 2N63W 6	449137

COGIS - Conditions of Approval Results

Type	Source Document	Conditions of Approval
UIC	Form: (02 ) 401716051 11/14/2018	1. Injection is not authorized until approval of Subsequent Forms 31 and 33. 2. Retrieve water sample(s) from injection zone(s) before stimulating formation. Samples must be analyzed for Total Dissolved Solids at a minimum. 3. PRIOR TO PERFORMING OPERATIONS: Operator is required to contact COGCC to discuss acid and fracturing jobs. Approval of Form 4 may be required for acid and fracturing jobs. (As of 4/13/2016) 4. PRIOR TO PERFORMING OPERATIONS: Operator is required to contact COGCC to discuss Step Rate Test or Injectivity Test criteria for Maximum Surface Injection Pressure determination. Prior approval of Form 4 may be required for step rate and injectivity tests. 5. For ALL NEW DRILL UNDERGROUND INJECTION WELLS a suite of open-hole Resistivity/Gamma Ray and Density/Neutron logs IS REQUIRED from Surface Casing shoe to TD. A PDF, TIFF, or PDS visual image and a LAS or DLIS file version of each log is required. 6. For all new and converted Underground Injection Control wells a Cement Bond Log (CBL) is required on the cased portions of the hole from the bottom of the casing to the top of the next shallower casing string for all casing strings other than the Surface Casing. Only a PDF, TIFF, or PDS visual image is required. 7. Operator must provide all tops of formations encountered from surface to TD on the Form 5 when submitted. (See Ensign Directional Plan Page 8 Attachment Doc # 401745081 for potential list of Formations.) 8. Well must pass MIT witnessed by COGCC before Subsequent Forms 31 and 33 will be approved. Well in must be in injection configuration.
Engineer	Form: (02 ) 401716051 11/15/2018	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. 2) Comply with Rule 317.j. and provide cement coverage from end of 7-inch casing to a minimum of 200' above Niobrara and from 200’ below Shannon to 200’ above Sussex. Verify coverage with cement bond log. 3) Bradenhead test shall be performed within 60 days of rig release and the Form 17 submitted within 10 days of the test. 4) Oil-based drilling fluid is to be used only after all fresh water aquifers are covered.
UIC	Form: (04 ) 402065303 6/5/2019	Operator is approved to conduct a 30-day injectivity test in the EWS 4B well. The test shall run a maximum of 30 days. The Maximum Daily Injection Rate for the test shall be less than 10,000 bbl/day, therefore the maximum injected volume is 300.000 barrels. The Maximum Surface Injection Pressure shall not exceed 2,250 psi.
UIC	Form: (04 ) 402196837 8/2/2021	The maximum daily injection rate for the EWS 4B is approved at 12,500 bbl/day. The tubing-casing annulus pressure shall be monitored, and if found to exceed 100 psi, Operator must contact the COGCC UIC program lead.
UIC	Form: (04 ) 403406175 5/18/2023	This Sundry requests a packer placement depth greater than 100' from the uppermost completed interval per Rule 417.a.(1).A. 1) Packer placement is approved at a shallowest depth of 9180' MD. No shallower placement of packer is allowed without a variance from the Commission. 2) Injection is not authorized until well passes an MIT witnessed by COGCC after packer placement. 3) Operator will submit a Form 5A reporting new tubing/packer placement in conjunction with submitting Form 21 after the witnessed MIT. Include a Wellbore Diagram and wireline tickets on the 5A.

COGIS - Best Management Practice Results

BMP Type	Source Document	Best Management Practices
Material Handling and Spill Prevention	Form: (02 ) 401716051 11/23/2018	Load-lines. All load-lines shall be bull-plugged or capped.
Drilling/Completion Operations	Form: (02 ) 401716051 11/23/2018	Green Completions – No hydrocarbons are anticipated in this well.
Drilling/Completion Operations	Form: (02 ) 401716051 11/23/2018	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
Drilling/Completion Operations	Form: (02 ) 401716051 11/23/2018	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.
Drilling/Completion Operations	Form: (02 ) 401716051 11/23/2018	Drill stem tests. Not applicable; no Drill Stem tests are planned.
Drilling/Completion Operations	Form: (02 ) 401716051 11/23/2018	Rule 317.p Open Hole Logging Requirement: Open-hole Resistivity Log with Gamma Ray Log will be run from TD into the surface casing. A neutron porosity log will be run from td to the surface casing shoe, logging through the 7-inch casing where applicable. A Cement Bond Long with Gamma Ray will be run on production casing, or on intermediate casing if a production liner is run. The Form 5, Completion Report, will list all logs run and have those logs attached.
Drilling/Completion Operations	Form: (02 ) 401716051 11/23/2018	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 will be generated for this site.
Drilling/Completion Operations	Form: (02 ) 401716051 11/23/2018	Guy line anchors. All guy line anchors shall be brightly marked pursuant to Rule 604.c(2)Q.
Drilling/Completion Operations	Form: (02 ) 401716051 11/23/2018	A bradenhead test will be performed within 60 days of rig release and prior to any stimulation activities. A Form 17 will be submitted on eForms within 10 days following the test. Bradenhead pressure will be monitored during stimulation activities. In the event of a rise in bradenhead pressure of more than 200 psi during stimulation activities, the COGCC will be notified per Rule 341.
Final Reclamation	Form: (02 ) 401716051 11/23/2018	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.
Final Reclamation	Form: (02 ) 401716051 11/23/2018	Identification of plugged and abandoned wells. P&A’d wells shall be identified pursuant to 319.a.(5).