COAs

Facility Type	Facility ID/ API	Facility Name/ Number	Operator Name/ Number	Status	Field Name/ Number	Location	Location ID	Related Facilities
WELL	05-123-45877	Pierce DE 26-054	PDC ENERGY INC 69175	TA 8/2/2019	PIERCE 69000	WELD 123 SESW 23 8N66W 6	453032

COGIS - Conditions of Approval Results

Type	Source Document	Conditions of Approval
Permit	Form: (02) 401426428 11/13/2017	The Drilling Completion Report (Form 5) for this well will be submitted with a surveyed well location plat to correctly identify the Quarter/Quarter section for this well's built location.
Engineer	Form: (02) 401426428 11/14/2017	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 and prior to stimulation and 2) If a delayed completion, 6-7 months after rig release and prior to stimulation. 3) Within 30 days after first production, as reported on Form 5A.
Engineer	Form: (02) 401426428 11/14/2017	1) Submit Form 42 electronically to COGCC 48 hours prior to MIRU for the first well activity with a rig on the pad and provide 48 hour spud notice for each subsequent well drilled on the pad. 2) Comply with Rule 317.j and provide cement coverage from TD to a minimum of 200' above the Niobrara. Verify coverage with cement bond log. 3) Oil-based drilling fluid is to be used only after all aquifers are covered.
Engineer	Form: (04) 401494265 01/10/2018	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) 401494265 01/10/2018	This approval is good for one year and new application must be made before February 1, 2018.
Engineer	Form: (04) 401494265 01/10/2018	Gas analysis, including H2S, should be submitted concurrent with the Form 5A, Completed Interval Report for this well. Submit via Form 4, Sundry Notice.
Engineer	Form: (04) 402331102 03/24/2020	This approval is good for one year and a new application must be made before March 3, 2021. Updates for the planned utilization of the well should be included with the application.
Engineer	Form: (04) 402331102 03/24/2020	The Form 7 reporting must reflect the well status dates reported on the Form 4-TA request.
Engineer	Form: (04) 402407221 06/04/2020	This approval is good for one year and a new application must be made before May 27, 2021. Updates for the planned utilization of the well should be included with the application.
Engineer	Form: (04) 402407221 06/04/2020	The Form 7 reporting must reflect the well status dates reported on the Form 4-TA request.
Engineer	Form: (04) 402606796 02/23/2021	This approval is good for one year and a new application must be made before February 22, 2022. Updates for the planned utilization of the well should be included with the application.
Engineer	Form: (04) 402606796 02/23/2021	The Form 7 reporting must reflect the well status dates reported on the Form 4-TA request.
Engineer	Form: (04) 402693137 05/24/2021	This approval is good for one year and a new application must be made before May 18, 2022. Updates for the planned utilization of the well should be included with the application.
Engineer	Form: (04) 402693137 05/24/2021	The Form 7 reporting must reflect the well status dates reported on the Form 4-TA request.
Engineer	Form: (04) 402919031 01/06/2022	This approval is good for one year and a new application must be made before January 6, 2023. Updates for the planned utilization of the well should be included with the application.
Engineer	Form: (04) 402919031 01/06/2022	The Form 7 reporting must reflect the well status dates reported on the Form 4-TA request.
Engineer	Form: (06) 404620148 04/17/2026	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. If there is a need for sampling, contact ECMC engineering for verification of plugging procedure.
Engineer	Form: (06) 404620148 04/17/2026	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) 404620148 04/17/2026	For Wells with known Bradenhead pressures: 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 408.e and 408.I. 2) After placing the shallowest hydrocarbon isolating plug (2592'), operator must wait a sufficient time to confirm static conditions. 3) After placing plug at 2592’ 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 ECMC engineering before continuing operations. 4) Prior to placing the 1589’ plug: verify that all fluid migration (liquid or gas) has been eliminated. If evidence of fluid migration or pressure remains, contact ECMC 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 1489’ or shallower and provide at least 10 sx plug at the surface. 6) 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. 7) With the Form 6 SRA operator must provide written documentation which positively affirms each COA has been addressed.
Engineer	Form: (06) 404620148 04/17/2026	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
Drilling/Completion Operations	Form: (02 ) 401426428 11/15/2017	Conventional drill stem tests will not be conducted on Pierce DE 26-054 well currently being executed or planned by GWOC. If plans change in the future a well specific drill stem testing plan will be prepared for that particular well. Note that GWOC may elect to use one of several available wireline deployed tools for the purpose of measuring down hole formation pressures and/or collecting down hole fluid samples from the target formation(s) of a particular well.
Drilling/Completion Operations	Form: (02 ) 401426428 11/15/2017	Prior to drilling operations, GWOG 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 well path with its respective error of uncertainty. If current surveys do not exist for the offset wells, Operator may have gyro surveys conducted to verify bottom hole 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.
Drilling/Completion Operations	Form: (02 ) 401426428 11/15/2017	A BOPE with a minimum pressure rating of 3,000 psi will be utilized. At a minimum it will consist of 2 ram preventers and 1 annular preventer. The blind rams will be positioned below the pipe rams. A backup system of pressure control will be onsite consisting of at a minimum 1,000 psi accumulator (backup pressure). Accumulator is tested to 1,000 psi. Operator may use fixed sized pipe rams matching the tubular size. The annular preventer will be pressure tested to 250 psi low and 2,000 psi high for 10 minutes each. The ram preventers will be tested to 250 psi low and 2,500 psi high for 10 minutes each. All remaining well control equipment will be tested to 250 psi low and 2,500 psi high for 10 minutes each. The pressure tests will be conducted when the equipment is first installed and every 30 days thereafter. Pipe rams and blind rams will be function tested before every well service operation. Annual BOP inspections and pressure tests will be performed by the service company and will be charted & retained for 1 year. Backup stabbing valves shall be used on operations that require reverse circulation. Valves will be pressure tested before each well service operation in low pressure and high pressure range. The GWOC onsite representative will be certified in Well Control Operations by a Well-Cap certified training service.
Drilling/Completion Operations	Form: (02 ) 401426428 11/15/2017	Open-hole Resistivity Log with Gamma Ray Log will be run from TD into the surface casing. A Cement Bond Log 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.

COGIS DB