COAs

Facility Type	Facility ID/ API	Facility Name/ Number	Operator Name/ Number	Status	Field Name/ Number	Location	Location ID	Related Facilities
WELL	05-123-39891	SWS Stark 1A	SELECT WATER SOLUTIONS LLC 10508	IJ 3/11/2022	CLAY BASKET 11340	WELD 123 NENW 26 8N60W 6	438160

COGIS - Conditions of Approval Results

Type	Source Document	Conditions of Approval
Engineer	Form: (02 ) 400600474 7/1/2014	1) Provide 48 hour notice prior to spud via electronic Form 42. 2) Provide cement coverage to a minimum of 200' above Niobrara. 3) Injection is not authorized until approval of forms 31 and 33. 4) Prior approval of Form 4 is required for step rate and injectivity tests. 5) Retrieve water samples before stimulating formation.
UIC	Form: (02 ) 400600474 7/18/2014	1) Operator is required to run a full suite of open hole logs including Resistivity, Gamma Ray, Density, Neutron, with standard accessory curves. 2) Operator is required to perform activities needed to create MUDLOG including at a minimum: Rate of Penetration, and Drilling Break/Lost Circulation information. 3) Operator is further required to run a Cement Bond Log from the bottom of the 1st (Long) String up to a minimum of 200' above Surface Casing shoe. 4) Operator is required to measure static water level in the well after liner has been set prior to any other downhole activities.
Engineer	Form: (02 ) 401059246 7/25/2016	1. Provide 48 hour notice prior to spud via electronic Form 42. 2. For 7" intermediate casing, top of primary cement (proposed 8441'-5169') must be 200' above Niobrara and top of stage cement (proposed 5169'-0') must be at least 50' above surface casing shoe. Stage cement must extend from 50' below to 50' above following sandy intervals: 3740'-3270', 1500'-860', based on offsets (123-10707, Stanley #14-23) and (123-14414, Federal J #15-23). Verify with cement bond log. 3. Submit cement job summary on all casing strings.
Engineer	Form: (02 ) 401059246 7/25/2016	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, prior to stimulation. 2) 6-7 months after rig release, prior to stimulation. 3) Within 30 days of first production, as reported on Form 5A.
UIC	Form: (02 ) 401059246 10/4/2016	1.Injection is not authorized until approval of Subsequent Forms 31 and 33. 2.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 is required for step rate and injectivity tests. 3.Prior to performing operations approval of Form 4 is required for acid and fracturing jobs. (New as of 4/13/2016). 4.Retrieve water sample(s) from injection zone(s) before stimulating formation. Samples must be analyzed for Total Dissolved Solids at a minimum. 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 DILS 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.
UIC	Form: (04 ) 402196689 5/20/2021	Operator has permission to inject at rates of up to, but not more than 12,500 barrels per day. Maximum Surface Injection Pressure not to exceed 2,000 psi.
Engineer	Form: (04 ) 403824941 6/18/2024	Submit a 42(MIRU) notice 2 business days prior to commencing operations. Submit a Form 5A with details of the acid matrix treatment.

COGIS - Best Management Practice Results

BMP Type	Source Document	Best Management Practices
Material Handling and Spill Prevention	Form: (02 ) 400600474 7/18/2014	Load-lines. All load-lines shall be bull-plugged or capped.
Drilling/Completion Operations	Form: (02 ) 400600474 7/18/2014	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 non-combustible gases are present.
Drilling/Completion Operations	Form: (02 ) 400600474 7/18/2014	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 ) 400600474 7/18/2014	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 ) 400600474 7/18/2014	Drill stem tests. Not applicable; no Drill Stem tests are planned.
Drilling/Completion Operations	Form: (02 ) 400600474 7/18/2014	Well will be logged with an open hole logging tool with gamma ray. A CBL will be run on all production casing or, in the case of a production liner, the intermediate casing, when these casing strings are run.
Drilling/Completion Operations	Form: (02 ) 400600474 7/18/2014	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.
Drilling/Completion Operations	Form: (02 ) 400600474 7/18/2014	Guy line anchors. All guy line anchors shall be brightly marked pursuant to Rule 604.c (2)Q.
Final Reclamation	Form: (02 ) 400600474 7/18/2014	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 ) 400600474 7/18/2014	Identification of plugged and abandoned wells. P&A’d wells shall be identified pursuant to 319.a.(5).
Material Handling and Spill Prevention	Form: (02 ) 401059246 10/10/2016	Load-lines. All load-lines shall be bull-plugged or capped.
Drilling/Completion Operations	Form: (02 ) 401059246 10/10/2016	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 non-combustible gases are present.
Drilling/Completion Operations	Form: (02 ) 401059246 10/10/2016	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 ) 401059246 10/10/2016	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 ) 401059246 10/10/2016	Drill stem tests. Not applicable; no Drill Stem tests are planned.
Drilling/Completion Operations	Form: (02 ) 401059246 10/10/2016	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 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 ) 401059246 10/10/2016	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 ) 401059246 10/10/2016	Guy line anchors. All guy line anchors shall be brightly marked pursuant to Rule 604.c (2)Q.
Final Reclamation	Form: (02 ) 401059246 10/10/2016	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 ) 401059246 10/10/2016	Identification of plugged and abandoned wells. P&A’d wells shall be identified pursuant to 319.a.(5).

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