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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	05-123-42866	Marcus LD 11-380HN	PDC ENERGY INC 69175	PR 6/1/2018	WATTENBERG 90750	WELD 123 SESE 34 1N67W 6	440806

COGIS - Conditions of Approval Results

Type	Source Document	Conditions of Approval
Engineer	Form: (02 ) 400839754 1/29/2016	1) Bradenhead test shall be performed within 30 days of rig release and prior to stimulation. Test results shall be submitted on Form 17 within 10 days of test. 2) Bradenhead test shall be performed between 6 and 7 months after rig release and shall be submitted on Form 17 within 10 days of test. 3) Bradenhead test shall be performed within 30 days of First Production as reported on Form 5A and shall be submitted on Form 17 within 10 days of test.
Engineer	Form: (02 ) 400839754 2/3/2016	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 and from 200’ below Sussex to 200’ above Sussex. Verify coverage with cement bond log.
Engineer	Form: (02 ) 400839754 2/3/2016	Operator acknowledges the proximity of the listed non-operated wells. 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. Rule 12-35A (API 05-123-20746) John H A Weigandt 1 (API 05-001-08693) Weigandt 43-3 (API 05-001-09095)
Engineer	Form: (02 ) 400839754 2/3/2016	Operator acknowledges the proximity of the 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. Newlander H Unit 1 (API 05-001-09192)
Permit	Form: (04 ) 401092867 8/18/2016	Operator will not produces within the 460' setback.
Engineer	Form: (04 ) 401105349 9/8/2016	This Form 4 makes changes to the approved Form 2 and must be displayed with the Form 2 while drilling. Changes a COA for mitigation from Option 1 or 2 to Option 4. 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. A Bradenhead test will be performed prior to the beginning of stimulation and the Form 17 submitted within 10 days. 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. If there is indication of communication between the stimulation treatment and the offset well, treatment will be stopped and COGCC Engineering notified. Newlander H. Unit 1, API 05-001-09192

COGIS - Best Management Practice Results

BMP Type	Source Document	Best Management Practices
Planning	Form: (02 ) 400839754 3/3/2016	BOPE for well servicing (Rule 604.c.(2)J 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.
Planning	Form: (02 ) 400839754 3/3/2016	Identification of P&A wells (Rule 604.c.(2)U GWOC shall identify the location of the P&A wellbore with a permanent monument as specified in Rule 319.a.(5). The operator shall also inscribe or imbed the well number and date of plugging upon the permanent monument. P&A wellbores shall be cutoff well below ground surface in agricultural areas to provide for landowners to safely farm the reclaimed well area.
General Housekeeping	Form: (02 ) 400839754 3/3/2016	General housekeeping will consist of neat and orderly storage of materials and fluids. Wastes will be temporarily stored in sealed containers and regularly collected and disposed of at offsite, suitable facilities. If spills occur prompt cleanup is required to minimize any commingling of waste materials with storm water runoff. Routine maintenance will be limited to fueling and lubrication of equipment. Drip pans will be used during routine fueling and maintenance to contain spills or leaks. Any waste product from maintenance will be containerized and transported offsite for disposal or recycling. There will be no major equipment overhauls conducted onsite. Equipment will be transported offsite for major overhauls. Cleanup will consist of patrolling the roadways, access areas, and other work areas to pick up trash, scrap debris, other discarded materials, and any contaminated soil. These materials will be disposed of properly and promptly.
Noise mitigation	Form: (02 ) 400839754 3/3/2016	During the drilling phase, Great Western plans to construct sound/visual walls that will be placed along the northern, southern, eastern and western edges of the pad. This will also assist to block out any lighting from nearby occupied structures.
Emissions mitigation	Form: (02 ) 400839754 3/3/2016	Where possible, drilling rig and completion equipment engine exhaust will be directed away from occupied buildings. Sealed tanks with pressure relief valves and emissions controls will also be utilized during the production phase.
Odor mitigation	Form: (02 ) 400839754 3/3/2016	Where possible, drilling rig and completion equipment engine exhaust will be directed away from occupied buildings to assist in mitigating potential odors. Light sources will be directed downwards, and away from occupied structures where possible. While GWOC does not anticipate any mitigation measures will be necessary for odors, sealed tanks with pressure relief valves and emissions controls will be utilized for the production phase. Once the drilling and completion rigs leave the site, there will be no permanently installed lighting on site.
Drilling/Completion Operations	Form: (02 ) 400839754 3/3/2016	GWOC 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 ) 400839754 3/3/2016	Drill stem tests (Rule 604.c.(2)L Conventional drill stem tests will not be conducted on DJ Basin horizontal wells 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 downhole formation pressures and/or collecting downhole fluid samples from the target formation(s) of a particular well.
Drilling/Completion Operations	Form: (02 ) 400839754 3/3/2016	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.
Drilling/Completion Operations	Form: (02 ) 400839754 3/3/2016	One of the first wells drilled on the pad will be logged with open-hole Resistivity 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 id production liner is run) into the surface casing. The horizontal portion of every will be logging with a measure-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 and number) the well in which open-hole logs were run.