COAs

Facility Type	Facility ID/ API	Facility Name/ Number	Operator Name/ Number	Status	Field Name/ Number	Location	Location ID	Related Facilities
WELL	05-123-39078	Becker Ranch 5J-443	PDC ENERGY INC 69175	PR 11/27/2015	WATTENBERG 90750	WELD 123 NWNW 5 3N64W 6	436361

COGIS - Conditions of Approval Results

Type	Source Document	Conditions of Approval
Engineer	Form: (02) 400521575 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) 400521575 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) 400521575 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.

COGIS - Best Management Practice Results

BMP Type	Source Document	Best Management Practices
Planning	Form: (02 ) 400521575 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 ) 400521575 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 ) 400521575 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 ) 400521575 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 ) 400521575 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 ) 400521575 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 ) 400521575 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 ) 400521575 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 ) 400521575 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 ) 400521575 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 ) 400521575 3/10/2014	604c.(2).F. Leak Detection Plan: Attached.
Material Handling and Spill Prevention	Form: (02 ) 400521575 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 ) 400521575 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 ) 400521575 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 ) 400521575 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 ) 400521575 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 ) 400521575 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 ) 400521575 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 ) 400521575 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 ) 400521575 3/10/2014	Operator will comply with COGCC Policy for Bradenhead Monitoring During Hydraulic Fracturing Treatments in the Greater Wattenberg Area dated May 29, 2012. The Colorado Oil and Gas Conservation Commission (COGCC) has established this Policy Regarding Bradenhead Monitoring During Hydraulic Fracturing Treatments (“Treatment”) in the Greater Wattenberg Area (“GWA”) pursuant to COGCC 207.a. (“Policy”). This Policy applies to oil and gas operations in the GWA as defined by the COGCC Rules of Practice and Procedure.
Drilling/Completion Operations	Form: (02 ) 400521575 3/10/2014	Prior to drilling operations, Operator 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 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 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. For the proposed well, upon conclusion of drilling operations, an as-constructed gyro survey will be submitted to COGCC with the Form 5.
Drilling/Completion Operations	Form: (02 ) 400521575 3/10/2014	604c.(2).O. Loadlines: All loadlines shall be bullplugged or capped.
Drilling/Completion Operations	Form: (02 ) 400521575 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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