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	05-123-39267	Sprague 3A-9H-N267	CRESTONE PEAK RESOURCES OPERATING LLC 10633	PA 8/18/2025	WATTENBERG 90750	WELD 123 SESW 9 2N67W 6	302199

COGIS - Conditions of Approval Results

Type	Source Document	Conditions of Approval
Permit	Form: (02) 400533988 02/20/2014	Operator will comply with COGCC Policy for Bradenhead Monitoring During Hydraulic Fracturing Treatments in the Greater Wattenberg Area dated May 29, 2012. (attached)
Engineer	Form: (02) 400533988 03/13/2014	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 and from 200’ below the Shannon to 200’ above Sussex. Verify coverage with cement bond log. 3) Comply with Rule 321. Run and submit Directional Survey from TD to base of surface casing. Ensure that the wellbore complies with setback requirements in commission orders or rules prior to producing the well.
Engineer	Form: (02) 400533988 03/13/2014	Operator acknowledges the proximity of the listed non-operated wells. Operator agrees to provide mitigation Option 1 or 2 (per the DJ Basin Horizontal Offset Policy), ensure all applicable documentation is submitted, and submit Form 42(s) (“OFFSET MITIGATION COMPLETED”) for the remediated wells, referencing the API Number of the proposed horizontal well(s) stating what appropriate mitigation occurred and that it has been completed, prior to the hydraulic stimulation of this well. Sprague 1 (API 123-07257) Unit A #1 (API 123-07286)
Engineer	Form: (02) 400533988 03/13/2014	Operator acknowledges the proximity of the listed wells. Operator agrees to provide mitigation Option 1 or 2 (per the DJ Basin Horizontal Offset Policy, ensure all applicable documentation is submitted based on the selected mitigation option chosen, and submit a Form 42(s) (“OFFSET MITIGATION COMPLETED”) for the remediated wells, referencing the API Number of the proposed horizontal well(s) stating what appropriate mitigation occurred and that it has been completed, prior to the hydraulic stimulation of this well. Sprague 1-9 (API 123-14823) Sprague 3-9 (API 123-15403) Sprague 42-9 (API 123-19873) Sprague 1 (API 123-09359)
OGLA	Form: (06) 404191553 06/25/2025	Operator committed to the following Best Management Practices under the Technical Detail/ Comments section on the Submit Tab: Operator will use secondary containment for all tanks and other liquid containment.
OGLA	Form: (06) 404191553 06/25/2025	Due to proximity to a wetland, surface water and expected shallow groundwater, operator will use secondary containment for all tanks and other liquid containers. Operator will implement stormwater BMPs and erosion control measures as needed to prevent sediment and stormwater runoff from entering the wetland and surface water.
Engineer	Form: (06) 404191553 07/01/2025	Verify existing cement coverage on the 2nd String with a CBL - submit to ECMC for verification of plugging orders prior to continuing plugging operations.
Engineer	Form: (06) 404191553 07/01/2025	Prior to starting plugging operations a Bradenhead test shall be performed if there has not been a reported Bradenhead test within the 60 days immediately preceding the start of plugging operations. 1) If, before opening the Bradenhead valve, the beginning pressure is greater than 25 psi, sampling is required. 2) If pressure remains at the conclusion of the test, or if any liquids were present during the test, sampling is required. The Form 17 shall be submitted within 10 days of the test. Sampling shall comply with Operator Guidance - Bradenhead Testing and Reporting Instructions. If samples are collected, copies of all final laboratory analytical results shall be provided to the ECMC within three (3) months of collecting the samples.
Engineer	Form: (06) 404191553 07/01/2025	Operator shall implement measures to control venting, to protect health and safety, and to ensure that vapors and odors from well plugging operations do not constitute a nuisance or hazard to public welfare.
Engineer	Form: (06) 404191553 07/01/2025	1) Provide 2 business day notice of plugging MIRU via electronic Form 42, and provide 48 hours Notice of Plugging Operations, prior to mobilizing for plugging operations via electronic Form 42. These are 2 separate notifications, required by Rules 405.e and 405.I. 2) Prior to placing the 950’ plug: verify that all fluid migration (liquid and gas) has been eliminated. If evidence of fluid migration or pressure remains, contact ECMC Engineer for an update to plugging orders. 3) After isolation has been verified, pump surface casing shoe plug. If cement is not circulated to surface, shut-in, WOC 4 hours then tag plug – must be at 793’ or shallower and provide 10 sx plug at the surface. 4) Leave at least 100’ of cement in the wellbore for each plug without mechanical isolation. 5) After surface plug and prior to cap, verify isolation by either a 15 minute bubble test or 15 minute optical gas imaging recording. If there is indication of flow contact ECMC Engineering. Provide a statement on the 6SRA which method was used and what was observed. Retain records of final isolation test for 5 years. 6) With the Form 6 SRA operator must provide written documentation which positively affirms each COA listed above has been addressed.
Engineer	Form: (06) 404191553 07/01/2025	FLOWLINE AND SITE CLOSURE 1) Consistent with Rule 911.a, a Form 27 must be approved prior to cut and cap, conducting flowline abandonment, or removing production equipment. Allow 30 days for Director review of the Form 27; include the Form 27 document number on the Form 44 for offsite flowline abandonment (if applicable) and on the Form 6 Subsequent. 2) Properly abandon flowlines per Rule 1105. If flowlines will be abandoned in place, include with the Form 27: pressure test results conducted in the prior 12 months as well as identification of any document numbers for a ECMC Spill/Release Report, Form 19, associated with the abandoned line.

COGIS - Best Management Practice Results

BMP Type	Source Document	Best Management Practices
General Housekeeping	Form: (02 ) 400533988 4/14/2014	Backup stabbing valves will be used on well servicing operations during reverse circulation. Valves will be pressure tested before each well servicing operation using both low-pressure air and high-pressure fluid.
General Housekeeping	Form: (02 ) 400533988 4/14/2014	Encana will maintain the site so that all surface trash, debris, scrap or discarded material connected with the operations of the property will be removed from the premises or disposed of in a legal manner.
General Housekeeping	Form: (02 ) 400533988 4/14/2014	The well site will be cleared of all non-essential equipment, trash and debris after ninety days of a well P&A.
Material Handling and Spill Prevention	Form: (02 ) 400533988 4/14/2014	"Encana's Leak Detection Program: • annual hydrostatic test on the oil dump line from the separator to the tank battery. • annual hydrostatic “static” tests on our oil tanks. • Annual hydrostatic “static” tests on our produced water tank and water dump line from the separator to the produced water tank. • Lease Operator inspections of all equipment not to exceed 48 hours. • Monthly documented inspections (EU). • Annual environmental inspections of all battery and well equipment and pads. • Annual UT inspections of the pressure vessels and input into Encana’s RIPL Predictive Integrity Maintenance Program. (HLP separators and fuel gas separators)
Material Handling and Spill Prevention	Form: (02 ) 400533988 4/14/2014	Encana will utilize 48” tall corrugated galvanized metal berm walls with a capacity in excess of 150% of the largest tank contained within the wall. In addition, Encana's Best Practices mandates the use of impervious liners that extends under each storage tank and up the walls, permanently affixed to the top of the metal berm wall. Protrusions of piping that come through the liner include a fully sealed “boot” to prevent leakage.
Material Handling and Spill Prevention	Form: (02 ) 400533988 4/14/2014	Adequate blowout prevention equipment will be used on all well servicing operations.
Material Handling and Spill Prevention	Form: (02 ) 400533988 4/14/2014	Any material not in use that might constitute a fire hazard will be removed a minimum of twenty-five (25) feet from the wellhead, tanks and separator. Any electrical equipment installations inside the bermed area will comply with API RP 500 classifications and comply with the current national electrical code as adopted by the State of Colorado.
Construction	Form: (02 ) 400533988 4/14/2014	At the time of construction, all leasehold roads will be constructed to accommodate local emergency vehicle access requirements, and will be maintained in a reasonable condition.
Noise mitigation	Form: (02 ) 400533988 4/14/2014	Encana will perform a baseline noise survey prior to any operational activity measuring dBA at a distance 350 feet from the noise source (unless there is an occupied structure closer than that – then we measure 25 feet from the structure). If low frequency noise is a concern, we will measure dBC at 25 feet from the occupied structure towards the noise source. As necessary based on the survey, we will install temporary sound walls to minimize noise and light impacts during drilling and completions and will install permanent noise mitigation at the facility location as necessary to meet all COGCC regulations. **Additional site specific verbiage may need to be added if a designated setback location.
Drilling/Completion Operations	Form: (02 ) 400533988 4/14/2014	Flow lines, separators, and sand traps capable of supporting green completions as described in Rule 805 will be installed on subject location at which commercial quantities of gas are reasonably expected to be produced based on existing adjacent wells within 1 mile.
Drilling/Completion Operations	Form: (02 ) 400533988 4/14/2014	Temporary flowback flaring an doxidizing equipment will include: adequeately sized equipment to handle 1.5 times the largest flowback volume of gas experienced in a ten mile radius. If there is overrun, Encana will shut in the well versus freely venting
Drilling/Completion Operations	Form: (02 ) 400533988 4/14/2014	Upon initial rig-up and at least once every thirty (30) days during drilling operations thereafter, 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 operator 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.
Drilling/Completion Operations	Form: (02 ) 400533988 4/14/2014	Encana will use an engineered base beam that we guy wire anchor the derricks to.
Drilling/Completion Operations	Form: (02 ) 400533988 4/14/2014	All newly installed or replaced crude oil and condensate storage tanks will be designed, constructed, and maintained in accordance with National Fire Protection Association (NFPA) Code 30 (2008 version). Encana will maintain written records verifying proper design, construction, and maintenance, and will make these records available for inspection by the Director. In addition, onsite inspections are conducted internally to insure guidelines are met.
Drilling/Completion Operations	Form: (02 ) 400533988 4/14/2014	Encana will identify pluged and abandoned wellbores according to Rule 319.a.(5). including the location of the wellbore with a permanent monument as specified in Rule 319.a.(5). Encana will also inscribe or imbed the well number and date of plugging upon the permanent monument.
Drilling/Completion Operations	Form: (02 ) 400533988 4/14/2014	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 well. 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.