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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	05-123-40331	Johnson 01N-65W-30-8N	VERDAD RESOURCES LLC 10651	PA 8/26/2021	WATTENBERG 90750	WELD 123 SESW 30 1N65W 6	439158

COGIS - Conditions of Approval Results

Type	Source Document	Conditions of Approval
Engineer	Form: (02) 400653197 09/11/2014	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. 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) 400653197 09/11/2014	Operator acknowledges the proximity of the listed non-producing wells. Operator agrees to provide mitigation Option 4 (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. Gilmore 1-30 (API 123-13588) former operator Joseph M. McCool (P&A'd well) Find surface location, submit GPS coordinates to COGCC, monitor surface location during the hydraulic stimulation of offset horizontals.
Permit	Form: (02) 400653197 09/24/2014	Operator shall comply with Buffer Zone Move-In, Rig-Up Notice Policy dated 12-16-2013.
Engineer	Form: (04) 401018093 05/09/2016	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 months after rig release, prior to stimulation. 3) Within 30 days of first production, as reported on Form 5A.
Engineer	Form: (04) 401018093 05/09/2016	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 and provide 48 hour spud notice via Form 42 for all subsequent wells drilled on the pad. 2) Comply with Rule 317.j. and provide cement coverage from TD to a minimum of 200' above Niobrara. Verify coverage with cement bond log.
Engineer	Form: (04) 401018093 05/09/2016	Operator acknowledges the proximity of the non-operated listed well. Operator agrees to: provide mitigation option 1 or 2 (per the DJ Basin Horizontal Offset Policy) to mitigate the situation, ensure all applicable documentation is submitted based on the selected mitigation option chosen, and submit a Form 42 (“OFFSET MITIGATION COMPLETED”) stating that appropriate mitigation occurred and that it has been completed, prior to the hydraulic stimulation of this well. 05-123-13340, MARGUERITE B LEHL A-1
Engineer	Form: (04) 401090822 08/11/2016	Operator acknowledges the proximity of the listed well. Operator assures that this offset will be remediated per the DJ Basin Horizontal Offset Policy (option 4). Operator will submit a Form 42 (“OTHER – AS SPECIFIED BY PERMIT CONDITION”) stating that appropriate mitigation will be completed, during the hydraulic stimulation of this well. This Form 42 shall be filed 48 hours prior to stimulation. Surface and production casing pressures will be actively monitored during stimulation. Operator will assure that the offset well’s Bradenhead is open and monitored during the entire stimulation treatment – a person will monitor for any evidence of fluid, a Bradenhead test will be performed prior to the beginning of stimulation. If there is indication of communication between the stimulation treatment and the offset well, treatment will be stopped and COGCC Engineering notified. 05-123-13340, MARGUERITE B LEHL A-1
Engineer	Form: (04) 401164143 03/15/2017	1) Flaring of natural gas shall comply with COGCC Rule 912. 2) Submit requests to flare annually to COGCC on Form 4 (Sundry Notice), which discusses timing to connect to sales line, plans to develop infrastructure, and justification for continued venting/flaring. Provide gas analysis including H2S with each Sundry Notice. 3) Report flaring volumes on Form 7, Operator’s Monthly Report of Operations. 4) The operator is required to obtain and maintain any required air permits from CDPHE. 5) The expectation for permanent flares controlling separators will be an enclosed combustion device with a 98% design destruction efficiency for hydrocarbons. 6) Notify the local emergency dispatch or the local governmental designee of natural gas flaring.
Engineer	Form: (04) 401164143 03/15/2017	This approval is good until June 1, 2017, at which point it is expected that the well is connected to infrastructure for gas sales or is shut in.
OGLA	Form: (06) 402765184 08/03/2021	1.) Operator will implement measures to capture, combust, or control emissions 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 health, welfare and the environment. 2.) Prior to commencing operations, at a minimum, the operator will provide notice to the owners/occupants of Building Units (BUs) that are adjacent to the parcel on which the well is located. The notice will include the operator's contact information and the nature, timing, and expected duration of the P&A operations.
Engineer	Form: (06) 402765184 08/03/2021	1) Provide 2 business day notice of plugging MIRU via electronic Form 42. 2) After placing the shallowest hydrocarbon isolating plug (7078'), operator must wait a sufficient time to confirm static conditions. 3) After placing plug at 2600’ assure that all fluid migration has been eliminated by monitoring the well for a minimum of 8 hours before proceeding to the next plug. If at any time after placing this plug there is evidence of pressure or of fluid migration, contact COGCC engineering before continuing operations. 4) Prior to placing the 1554’ plug: verify that all fluid migration (liquid or gas) has been eliminated. If evidence of fluid migration or pressure remains, contact COGCC Engineer for an update to plugging orders. 5) After isolation has been verified, pump plug and displace. If cement is not circulated to surface, shut-in, WOC 4 hours then tag plug – must be at 1454’ or shallower and provide at least 10 sx plug at the surface. 6) Leave at least 100’ of cement in the wellbore for each plug. 7) Properly abandon flowlines as per Rule 1105. Pursuant to Rule 911.a. Closure of Oil and Gas Facilities, Operator will submit Site Investigation and Remediation Workplans via Form 27 for COGCC prior approval before cutting and capping the plugged well, conducting flowline abandonment, and removing production equipment. Pursuant to Rule 1105.f. Abandonment Verification, within 90 days of an operator completing abandonment requirements for a flowline or crude oil transfer line, an operator must submit a Field Operations Notice, Form 42-Abandonment of Flowlines for on-location flowlines, and a Flowline Report, Form 44, for off-location flowlines or crude oil transfer lines. 8) With the Form 6 SRA operator must provide written documentation which positively affirms each COA has been addressed.
Engineer	Form: (06) 402765184 08/03/2021	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 COGCC within three (3) months of collecting the samples. If there is a need for sampling, contact COGCC engineering for verification of plugging procedure.

COGIS - Best Management Practice Results

BMP Type	Source Document	Best Management Practices
Planning	Form: (02 ) 400653197 10/3/2014	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 ) 400653197 10/3/2014	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 ) 400653197 10/3/2014	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 ) 400653197 10/3/2014	Load-lines. All load-lines shall be bull-plugged or capped.
Material Handling and Spill Prevention	Form: (02 ) 400653197 10/3/2014	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 ) 400653197 10/3/2014	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 ) 400653197 10/3/2014	Closed Loop Drilling Systems – Pit Restrictions. Not applicable; a closed-loop system will be used for drilling.
Drilling/Completion Operations	Form: (02 ) 400653197 10/3/2014	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 ) 400653197 10/3/2014	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 ) 400653197 10/3/2014	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 ) 400653197 10/3/2014	Pit level indicators. Not applicable; a closed-loop system will be used and no pits shall be dug.
Drilling/Completion Operations	Form: (02 ) 400653197 10/3/2014	Drill stem tests. Not applicable; no Drill Stem tests are planned.
Drilling/Completion Operations	Form: (02 ) 400653197 10/3/2014	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 ) 400653197 10/3/2014	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 ) 400653197 10/3/2014	Guy line anchors. All guy line anchors shall be brightly marked pursuant to Rule 604.c (2)Q.
Drilling/Completion Operations	Form: (02 ) 400653197 10/3/2014	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 ) 400653197 10/3/2014	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 ) 400653197 10/3/2014	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 ) 400653197 10/3/2014	Identification of plugged and abandoned wells. P&A’d wells shall be identified pursuant to 319.a.(5).