COAs

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Facility Type	Facility ID/ API	Facility Name/ Number	Operator Name/ Number	Status	Field Name/ Number	Location	Location ID	Related Facilities
WELL	05-123-41049	Blackburn 01N-64W-08-8N	VERDAD RESOURCES LLC 10651	SI 8/1/2024	WATTENBERG 90750	WELD 123 NENE 8 1N64W 6	159800

COGIS - Conditions of Approval Results

Type	Source Document	Conditions of Approval
Permit	Form: (02 ) 400697770 1/9/2015	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.
Engineer	Form: (02 ) 400697770 1/16/2015	1) Submit Form 42 electronically to COGCC 48 hours prior to MIRU. 2) Comply with Rule 317.j and provide cement coverage from end of 7” casing to a minimum of 200' above Niobrara. 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: (04 ) 400966289 3/1/2016	1) Flaring of natural gas shall comply with COGCC Rule 912. 2) Report flaring volumes on Form 7, Operator’s Monthly Report of Operations. 3 )The operator is required to obtain and maintain any required air permits from CDPHE. 4) The expectation for permanent flares controlling separators will be an enclosed combustion device with a 98% design destruction efficiency for hydrocarbons. 5) Notify the local emergency dispatch or the local governmental designee of natural gas flaring.
OGLA	Form: (06 ) 403783261 5/10/2024	Due to close proximity to Residential Building Units (RBUs), prior to commencing operations, at a minimum, the operator will provide an informational sheet to the owners/occupants of the RBUs nearby and adjacent to the parcel with the well. The sheet will include the operator's contact information and the nature, timing, and expected duration of the P&A operations. Operator will implement measures to capture, combust, or control emissions to protect health and safety, and to ensure that vapors, odors and noise from plugging operations do not constitute a nuisance or hazard to public health, welfare and the environment.
OGLA	Form: (06 ) 403783261 5/10/2024	Due to proximity to a mapped 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 ) 403783261 5/13/2024	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 ) 403783261 5/13/2024	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 1323’ 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 1223’ 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 cut 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 ) 403783261 5/13/2024	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
Planning	Form: (02 ) 400697770 1/21/2015	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.
Traffic control	Form: (02 ) 400697770 1/21/2015	Access roads. The access road will be constructed to accommodate local emergency vehicles. This road will be maintained for access at all times.
Material Handling and Spill Prevention	Form: (02 ) 400697770 1/21/2015	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.
Material Handling and Spill Prevention	Form: (02 ) 400697770 1/21/2015	Load-lines. All load-lines shall be bull-plugged or capped.
Material Handling and Spill Prevention	Form: (02 ) 400697770 1/21/2015	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.
Noise mitigation	Form: (02 ) 400697770 1/21/2015	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; and rig shrouding is not believed necessary as this is an industrial area and the only building unit within 1,000' is owned by the operator, however, 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.
Drilling/Completion Operations	Form: (02 ) 400697770 1/21/2015	Closed Loop Drilling Systems – Pit Restrictions. Not applicable; a closed-loop system will be used for drilling.
Drilling/Completion Operations	Form: (02 ) 400697770 1/21/2015	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 ) 400697770 1/21/2015	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 ) 400697770 1/21/2015	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 ) 400697770 1/21/2015	Pit level indicators. Not applicable; a closed-loop system will be used and no pits shall be dug.
Drilling/Completion Operations	Form: (02 ) 400697770 1/21/2015	Drill stem tests. Not applicable; no Drill Stem tests are planned.
Drilling/Completion Operations	Form: (02 ) 400697770 1/21/2015	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 ) 400697770 1/21/2015	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 ) 400697770 1/21/2015	Guy line anchors. All guy line anchors shall be brightly marked pursuant to Rule 604.c (2)Q.
Drilling/Completion Operations	Form: (02 ) 400697770 1/21/2015	Operator acknowledges and will comply with the COGCC Policy for Bradenhead Monitoring during Hydraulic Fracturing Treatments in the Greater Wattenberg Area dated May 29, 2012.
Drilling/Completion Operations	Form: (02 ) 400697770 1/21/2015	Prior to drilling operations, Operator may perform an anti-collision review of existing offset wells that have the potential of being within close proximity of the proposed well. This anti-collision review may include MWD or gyro surveys and surface locations 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 may only be drilled if the anti-collision review results indicate that the risk of collision is sufficiently low as defined by the anticollision plan, with separation factors greater than 1.5, or if the risk of collision has been mitigated through other means including shutting in wells, plugging wells, increased drilling fluid in the event of lost returns or as is appropriate for the specific situation. In the event of an increased risk of collision, that risk will be mitigated to prevent harm to people, the environment or property. For the proposed well, upon conclusion of drilling operations, an as-constructed directional survey will be submitted to COGCC with the Form 5. Please see the attached 318A.m letter for a list of well(s) identified by the operator as being within 150 feet of the proposed well(s). If no letter is attached, the operator has not identified any wells as being within 150 feet of the proposed well(s) at the time of permitting.
Final Reclamation	Form: (02 ) 400697770 1/21/2015	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 ) 400697770 1/21/2015	Identification of plugged and abandoned wells. P&A’d wells shall be identified pursuant to 319.a.(5).