COAs

Facility Type	Facility ID/ API	Facility Name/ Number	Operator Name/ Number	Status	Field Name/ Number	Location	Location ID	Related Facilities
WELL	05-123-39075	Becker Ranch 5E-403	PDC ENERGY INC 69175	PR 12/6/2015	WATTENBERG 90750	WELD 123 NWNW 5 3N64W 6	436361

COGIS - Conditions of Approval Results

Type	Source Document	Conditions of Approval
Engineer	Form: (02) 400521564 02/03/2014	1) Submit Form 42 electronically to COGCC 48 hours prior to MIRU. 2) Comply with Rule 317.i and provide cement coverage from the bottom of the production casing to a minimum of 200' above Niobrara. Verify coverage with cement bond log. 3) Run and submit Directional Survey from TD to base of surface casing. The operator shall comply with Rule 321, and it shall be the operator’s responsibility to ensure that the wellbore complies with setback requirements in commission orders or rules prior to producing the well.
Engineer	Form: (02) 400521564 02/04/2014	Operator acknowledges the proximity of The Becker 5-2 ( API NO 123-13742), the Becker 5-7 ( API NO 123-13764), the Becker 5-8 (API NO 123-13839), the Becker 5-3 (API NO 123-17299), the Becker 5-11 ( API NO 123-17300), the Becker 5-13 ( API NO 123-17302), the Becker 5-14 (API NO 123-18180), and the Dechant 7-11 (API NO 123-15476). 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 (“OTHER – AS SPECIFIED BY PERMIT CONDITION”) stating what appropriate mitigation occurred and that it has been completed, prior to the hydraulic stimulation of this well.
Engineer	Form: (02) 400521564 02/04/2014	Operator acknowledges the proximity of the non-operated wells: The McKenney 6-2 (API NO 123-11907), the McKenney 6-3 (API NO 123-14815), the McKenney 6-14 (API NO 123-15780), the UPRR OCOMA II C31-16 (API NO 123-13603), the Howell 1 (API NO 123-07827), and the McGuirk-Howell C 32-14 (API NO 123-15882). Operator assures that these offsets will be remediated per the DJ Basin Horizontal Offset Policy (options 1 or 2) or operator will address this well with mitigation option 4. Operator will submit a Form 42 (“OTHER – AS SPECIFIED BY PERMIT CONDITION”) stating what appropriate mitigation occurred and that it has been completed, prior to the hydraulic stimulation of this well.
Engineer	Form: (02) 400521564 02/04/2014	1) Submit Form 42 electronically to COGCC 48 hours prior to MIRU. 2) Comply with Rule 317.i and provide cement coverage from the bottom of the production casing to a minimum of 200' above Niobrara and from 200’ below the Sussex to 200’ above Sussex . Verify coverage with cement bond log. 3) Run and submit Directional Survey from TD to base of surface casing. The operator shall comply with Rule 321, and it shall be the operator’s responsibility to ensure that the wellbore complies with setback requirements in commission orders or rules prior to producing the well.
Engineer	Form: (04) 403515291 09/08/2023	1. Operator will 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 abatement, if a sample has not been collected within the last twelve months collect bradenhead and production gas samples for laboratory analysis. Sampling will comply with Operator Guidance - Bradenhead Testing and Reporting Instructions, Appendix A: Liquid and Gas Sampling. Copies of all final laboratory analytical results will be provided to the ECMC within three months of collecting the samples. 3. Bradenhead gas is not to be vented to atmosphere; any gas from the Bradenhead will be routed to an enclosed tank and/or combustor. Operator will implement measures to get an initial estimate of the gas flow rate and/or volume from the bradenhead. The abatement program may be used for six consecutive months. 4. Operator will submit a Form 42 (“OTHER”) stating that “bradenhead abatement program has started.” 5. 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, flow rate information, pressure data and a discussion of the sample analysis. Shut in bradenhead pressure shall not exceed 50 psig.
Engineer	Form: (04) 404018513 01/23/2025	1. Operator will 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 abatement, if a sample has not been collected within the last twelve months collect bradenhead and production gas samples for laboratory analysis. Sampling will comply with Operator Guidance - Bradenhead Testing and Reporting Instructions, Appendix A: Liquid and Gas Sampling. Copies of all final laboratory analytical results will be provided to the ECMC within three months of collecting the samples. 3. Bradenhead gas is not to be vented to atmosphere; any gas from the Bradenhead will be routed to the specified abatement system. Operator will implement measures to get an initial estimate of the gas flow rate and/or volume from the bradenhead. The abatement program may be used for six consecutive months. 4. Operator will submit a Form 42 (“OTHER”) stating that “bradenhead abatement program has started.” 5. By 4/22/25, 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, flow rate information, pressure data and a discussion of the sample analysis. Bradenhead pressure shall not exceed threshold pressure (50 psig).
Engineer	Form: (04) 404177046 05/14/2025	1. Operator will 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. Bradenhead gas is not to be vented to the atmosphere; any gas from the Bradenhead will routed to to specified abatement system. Shut in bradenhead pressure shall not exceed threshold pressure . Operator will implement measures to get an estimate of the gas flow rate and/or volume from the bradenhead. 3. No later than 4/14/26, conduct a bradenhead test, submit a Form 17, and submit a Form 4 Sundry that summarizes current well condition. The well should be shut in for seven days to monitor and collect data to characterize build up pressures prior to conducting the bradenhead test. The sundry should include details of the future plans, sample analysis interpretation, bradenhead test description, and the flow rate information and pressure data. 4. If a sample has not been collected from surface casing within the last twelve months collect bradenhead gas samples for laboratory analysis. Sampling will comply with Operator Guidance - Bradenhead Testing and Reporting Instructions, Appendix A: Liquid and Gas Sampling. Copies of all final laboratory analytical results will be provided to the ECMC within three months of collecting the samples.

COGIS - Best Management Practice Results

BMP Type	Source Document	Best Management Practices
Planning	Form: (02 ) 400521564 3/10/2014	604c.(2).E. Multiwell Pads: This 2A application is for a 4-well pad. No suitable existing locations are in the area.
Planning	Form: (02 ) 400521564 3/10/2014	604c.(2).I. BOPE Testing for Drilling Operations: PDC's contractors will supply a double ram-5000’ PSI rated BOPE (Blinds and pipes) and always function test BOPE’s prior to placement on the well head and inspect and replace all seals and ram block rubbers. After installation of the BOPE, PDCE conducts a pressure test on the BOPE at a low pressure of (200-400 psi) and a high pressure test to the maximum amount of the BOPE rating with a third party tester, all tests are digitally recorded.
Planning	Form: (02 ) 400521564 3/10/2014	604c.(2).J. BOPE for Well Servicing Operations: All valves will also be tested to maximum rating by a third party prior to being delivered to location. Whenever snubbing operations are being used the snubbing stack will be pressure tested at the same time the BOPE is being tested which consist of a single pipe ram and a annular bag.
Planning	Form: (02 ) 400521564 3/10/2014	604c.(2).L. Drill Stem Tests: PDC does not conduct drill stem tests, but will seek prior approval from the director if a drill stem test will be preformed.
Planning	Form: (02 ) 400521564 3/10/2014	604c.(2).U. Identification of Plugged and Abandoned Wells: Pursuant to rule 319.a. (5)., once the well has been plugged and abandoned, PDC will identify the location of the wellbore with a permanent monument that will detail the well name and date of plugging.
Planning	Form: (02 ) 400521564 3/10/2014	604c.(2).V. Development From Existing Well Pads: An existing pad was not available to utilize to develop these wells.
Traffic control	Form: (02 ) 400521564 3/10/2014	604c.(2).D. Traffic Plan: If required by the local government, a traffic plan will be coordinated with the local jurisdiction prior to commencement of operations.
General Housekeeping	Form: (02 ) 400521564 3/10/2014	604c.(2).N. Control of Fire Hazards: PDC will ensure that any material that might be deemed a fire hazard will be will remain no less than twenty-five (25) feet from the wellhead(s), tanks and separator(s). PDC installs automation equipment for tank level and pressure monitoring inside the bermed area that complies with API RP 500 classifications and with the current national electrical code as adopted by the State of Colorado.
General Housekeeping	Form: (02 ) 400521564 3/10/2014	604c.(2).T. Well Site Cleared: The wellsite will be cleared of all non-essential equipment within ninety (90) days after all wells associated with the pad have been plugged and abandoned.
General Housekeeping	Form: (02 ) 400521564 3/10/2014	604c.(2).P. Removal of Surface Trash: A commercial size trash bin for removing debris will be located on site. This bin will be for use by all parties affiliated with the operation.
Material Handling and Spill Prevention	Form: (02 ) 400521564 3/10/2014	604c.(2).F. Leak Detection Plan: Attached.
Material Handling and Spill Prevention	Form: (02 ) 400521564 3/10/2014	604c.(2).K. Pit Level Indicators: PDC uses an Electronic Drilling Recorder (EDR) with pit level monitor(s) and alarm(s) for production rigs. Basic level gages are used on steel pits utilized for the surface rig.
Construction	Form: (02 ) 400521564 3/10/2014	604c.(2).G. Berm Construction: A geosynthetic liner will be laid under the tanks on this location and a metal containment has been constructed. Operator must implement site-specific best management practices in accordance with good engineering practices, including, but not limited to, construction of a berm or diversion dike, site grading, or other comparable measures, sufficient to protect the down gradient water sources located 321 feet south-west and 444 feet north-west from the nearest well head.
Construction	Form: (02 ) 400521564 3/10/2014	604c.(2).M. Fencing Requirements: The completed wellsites will be surrounded with a fence and gate. PDC personnel will monitor the wellsites regularly upon completion of the wells. Authorized representatives and/or PDC personnel shall be on-site during drilling and completion operations.
Construction	Form: (02 ) 400521564 3/10/2014	604c.(2).Q. Guy Line Anchors: Rig guy wires are anchored to the rig’s base beam that the rig stands on, temporary and permanent anchors will not be set on this location.
Construction	Form: (02 ) 400521564 3/10/2014	604c.(2).R. Tank Specifications: Condensate storage tanks will be designed, constructed and maintained in accordance with National Fire Protection Association (NFPA) Code 30 (2008 version). PDC will maintain written records to verify proper design, construction and maintenance. All records will be available for inspection by the Director.
Construction	Form: (02 ) 400521564 3/10/2014	604c.(2).S. Access Roads: PDC will utilize the lease access road from WCR 53 for drilling operations and maintenance equipment. The road will be properly constructed and maintained to accommodate for local emergency vehicle access.
Noise mitigation	Form: (02 ) 400521564 3/10/2014	604c.(2).A. Noise: PDC has conducted baseline noise surveys for all drilling rigs that are being contracted and has also conducted a baseline noise survey for hydraulic fracture stimulation operations on a representative horizontal well. These baseline surveys are utilized for site specific noise modeling to determine if any mitigation measures are warranted. A review will be conducted to identify potential receptors within 1000 feet of the proposed Becker Ranch 5J-HZ pad site. The building units of concern are located north-east of the proposed pad at a distance of approximately 758 feet, 776 feet and 908 feet respectively. Noise modeling will be conducted for the proposed pad. If results exceed the Light Industrial Zone standard of 65 decibels (db) at the receptor location, additional methods of noise mitigation shall include but not be limited to hay bales, noise walls, or customized semi-trailers.
Emissions mitigation	Form: (02 ) 400521564 3/10/2014	604c.(2).C. Green Completions: Flowlines, 48” HLPs, sand traps all capable of supporting green completions as described in rule 805 shall be installed at any Oil and Gas location at which commercial quantities of gas and or oil are reasonable expected to be produced based on existing wells. All green flow back equipment will be able to handle more than 1.5 times the amount of any know volumes in the surrounding field. First sign of salable gas will be put into production equipment and turned down line.
Drilling/Completion Operations	Form: (02 ) 400521564 3/10/2014	604c.(2).O. Loadlines: All loadlines shall be bullplugged or capped.
Drilling/Completion Operations	Form: (02 ) 400521564 3/10/2014	Open hole resistivity log with gamma ray will be run on one of the wells on this pad to describe the stratigraphy of the vertical section of the wellbore and to adequately verify the setting depth of the surface casing and aquifer coverage. The Drilling Completion Report - Form 5 for every well on the pad shall identify which well was logged.

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