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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	05-001-09926	Ward Riverdale 15-2-11HC	PDC ENERGY INC 69175	PA 8/25/2022	WATTENBERG 90750	ADAMS 001 NWSW 14 1S67W 6	441677

COGIS - Conditions of Approval Results

Type	Source Document	Conditions of Approval
Engineer	Form: (02 ) 400879059 11/15/2015	NOTE: Surface casing setting depth change from 1200’ to 1500’. Increase cement coverage accordingly. 1) Submit Form 42 electronically to COGCC 48 hours prior to MIRU for first well on pad, subsequent wells 48 hours prior to spud. 2) Comply with Rule 317.j. and provide cement coverage from TD to a minimum of 200' above Niobrara and from 200’ below Sussex to 200’ above Sussex. Verify coverage with cement bond log.
Engineer	Form: (04 ) 402228344 4/14/2020	1.Operator shall implement measures to control venting, to protect health and safety, and to ensure that vapors and odors from well operations do not constitute a nuisance or hazard to public welfare. 2. Prior to starting bradenhead mitigation, if a sample has not been collected within the last twelve months collect bradenhead and production gas samples for laboratory analysis. Sampling shall comply with Operator Guidance - Bradenhead Testing and Reporting Instructions, Appendix A: Liquid and Gas Sampling. Copies of all final laboratory analytical results shall be provided to the COGCC within three months of collecting the samples. 3. Operator shall implement measures to get an initial estimate of the gas flow rate and/or volume from the bradenhead. During the shut-in period record pressure data to adequately characterize the build-up. This mitigation plan may be used for six consecutive months from the date test reported on the Form 17. 4. At the conclusion of the six months, conduct a new bradenhead test and submit the Form 17 within ten days of the test and submit a Form 4 Sundry that summarizes current well condition. The sundry should include details of the future plans and the flow rate information and pressure data.
OGLA	Form: (06 ) 402866644 11/16/2021	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. Due to proximity of building units (BUs) all blowdown gases will be controlled.
OGLA	Form: (06 ) 402866644 11/16/2021	Due to close proximity to Residential Building Units: prior to commencing operations, at a minimum, the operator will provide an informational sheet to the owners/occupants of BUs that are nearby and adjacent to the parcel on which the well is located. The sheet will include the operator's contact information and the nature, timing, and expected duration of the PA operations.
OGLA	Form: (06 ) 402866644 11/16/2021	Prior to commencing operations, the operator will post signs in conspicuous locations. The signs will indicate plugging and abandonment operations are being conducted, the well name, well, and the applicable contact information. Signs will be placed so as not to create a potential traffic hazard.
Engineer	Form: (06 ) 402866644 12/6/2021	1) Provide 2 business day notice of plugging MIRU via electronic Form 42. 2) After placing the shallowest hydrocarbon isolating plug (8250'), operator must wait a sufficient time to confirm static conditions. If at any time after placing this plug there is evidence of pressure or of fluid migration, contact COGCC engineering before continuing operations. 3) Prior to placing the 1650' plug: verify that all fluid migration (liquid and gas) has been eliminated. If evidence of fluid migration or pressure remains, contact COGCC Engineer for an update to plugging orders. 4) 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 1054' or shallower and provide 10 sx plug at the surface. 5) Leave at least 100’ of cement in the wellbore for each plug. 6) 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 Work plans 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. 7) With the Form 6 SRA operator must provide written documentation, which positively affirms each COA has been addressed.
Engineer	Form: (06 ) 402866644 12/6/2021	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
Material Handling and Spill Prevention	Form: (02 ) 400879059 12/13/2015	Leak Detection Plan: To ensure protection for the surface during fracturing treatment, the location will be specifically constructed to contain any releases or spills. Secondary containment from any chemical spills or leaks will surround any trucks that carry, mix, or add chemicals to the flow stream as well as connections that could possibly leak fluid. Should any spill or release occur, every reasonable step will be taken to quickly remediate the area disturbed.
Material Handling and Spill Prevention	Form: (02 ) 400879059 12/13/2015	Control of Fire Hazards: Ward and its contractor’s employ best management practices during the drilling and production of its wells and facilities. They will comply with appropriate COGCC and any county rules concerning fire and safety. Ward will ensure that any flammable material will remain no less than 25 feet from the wellhead (s), tanks and separator(s).
Material Handling and Spill Prevention	Form: (02 ) 400879059 12/13/2015	Berm Construction: A containment berm will be constructed around the oil and water storage tanks. The berm will be inspected regularly and maintained in good condition.
Material Handling and Spill Prevention	Form: (02 ) 400879059 12/13/2015	Tank specifications: Tanks shall be constructed and maintained in accordance with the National Fire Protection Association Code 30 (2008 version). All tanks will be visually inspected once a day for issues. Recorded inspections will be conducted once a month pursuant to 40 CFR §112.
Dust control	Form: (02 ) 400879059 12/13/2015	Dust Control: Ward will company with Rule 805.c and take all practicable measures to control fugitive dust caused by the operation, including to but not limited to wetting the soil with fresh water via a truck with a spreader bar if deemed necessary.
Noise mitigation	Form: (02 ) 400879059 12/13/2015	Noise Mitigation: Ward is planning on using sound walls to mitigate noise levels during drilling and completion. A background noise study will be done prior to drilling and the appropriate sound wall design will be chosen to meet or exceed COGCC noise requirements.
Drilling/Completion Operations	Form: (02 ) 400879059 12/13/2015	Closed Loop System: Closed Loop System will be used for drilling and fluid management. No reserve pit will be used.
Drilling/Completion Operations	Form: (02 ) 400879059 12/13/2015	One of the first wells drilled on the pad will be logged with open-hole Resistivity Log and Gamma Ray Log from the kick-off point into the surface casing. All wells on the pad will have a cement bond log with gamma-ray run on production casing (or on intermediate casing if production liner is run) into the surface casing. The horizontal portion of every well will be logged with a measured-while-drilling gamma-ray log. The Form 5, Completion Report, for each well on the pad will list all logs run and have those logs attached. The Form 5 for a well without open-hole logs shall clearly state “No open-hole logs were run” and shall clearly identify (by API#, well name & number) the well in which open-hole logs were run.
Drilling/Completion Operations	Form: (02 ) 400879059 12/13/2015	Green Completions: Emission Control Systems. Test separators and associated flow lines and sand traps shall be installed on-site to accommodate Green completion techniques pursuant to COGCC Rules.
Drilling/Completion Operations	Form: (02 ) 400879059 12/13/2015	BOPE Testing: Upon initial rig-up and once every 30 days during drilling operations, pressure testing of the casing string and each component of the BOPE will be performed to 70% of working pressure or 70% of the internal yield of the casing, whichever is less.
Drilling/Completion Operations	Form: (02 ) 400879059 12/13/2015	BOPE for well servicing operations: Adequate blowout prevention equipment will be used on any servicing operations associated with this well. Backup staving valves shall be required on well servicing operations during reverse circulation. Valves will be pressure tested before each well servicing operation using both low-pressure and high-pressure fluid.
Drilling/Completion Operations	Form: (02 ) 400879059 12/13/2015	BOPE: Ward will utilize drilling rigs with a minimum of a double ram and annular preventer.
Drilling/Completion Operations	Form: (02 ) 400879059 12/13/2015	Drill Stem Tests: Drill Stem Tests are not anticipated for this location.
Drilling/Completion Operations	Form: (02 ) 400879059 12/13/2015	Pit Level Indicators: Pit Level Indicators will not be needed as no pits will be used on location.
Drilling/Completion Operations	Form: (02 ) 400879059 12/13/2015	Visual Mitigation: Pursuant to Rule 804, the tank battery shall be painted in uniform, non-contrasting, non-reflective color tones with the colors matched to but slightly darker than the surrounding landscape.
Drilling/Completion Operations	Form: (02 ) 400879059 12/13/2015	All light will be directed downward as much as possible to mitigate light pollution into the adjacent neighborhood. In addition the sound wall will also help to limit light pollution.