COAs

Facility Type	Facility ID/ API	Facility Name/ Number	Operator Name/ Number	Status	Field Name/ Number	Location	Location ID	Related Facilities
WELL	05-123-37330	ALM 33W-314	PDC ENERGY INC 69175	PA 8/5/2022	WATTENBERG 90750	WELD 123 NENE 33 7N65W 6	432871

COGIS - Conditions of Approval Results

Type	Source Document	Conditions of Approval
Permit	Form: (02) 400396768 04/16/2013	Operator must meet Water Well Testing requirements as per amended Rule 318Ae(4)
Engineer	Form: (02) 400396768 04/18/2013	1)Provide notice of MIRU via an electronic Form 42. 2)Comply with Rule 317.i and provide cement coverage to a minimum of 200' above the Niobrara. Verify cement coverage with a cement bond log per 317.o.
Permit	Form: (02) 400648465 02/10/2015	Operator shall comply with Buffer Zone Move-In, Rig-Up Notice Rule 305.h (effective 9/30/2014).
Engineer	Form: (02) 400648465 02/12/2015	1) Submit Form 42 electronically to COGCC 48 hours prior to MIRU. 2) Comply with Rule 317.i and provide cement coverage from end of 7” casing to a minimum of 200' above Niobrara. Verify coverage with cement bond log. 3) Comply with Rule 321. Run and submit Directional Survey from TD to base of surface casing. Ensure that the wellbore complies with setback requirements in commission orders or rules prior to producing the well.
Engineer	Form: (02) 400648465 02/24/2015	Operator acknowledges the proximity of the listed non-producing well(s). Operator agrees to provide mitigation Option 3 (per the DJ Basin Horizontal Offset Policy), ensure all applicable documentation is submitted, and submit Form 42(s) (“OFFSET MITIGATION COMPLETED”) for the remediated well(s), referencing the API Number of the proposed horizontal well(s) stating what appropriate mitigation occurred and that it has been completed, prior to the hydraulic stimulation of this well. Harper 34-22 (API #123-26081)
OGLA	Form: (06) 402957823 02/16/2022	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) 402957823 02/16/2022	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.
Engineer	Form: (06) 402957823 02/17/2022	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.
Engineer	Form: (06) 402957823 02/17/2022	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 (2500'), 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 1440’ 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 875’ 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 Workplans 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.

COGIS - Best Management Practice Results

BMP Type	Source Document	Best Management Practices
Drilling/Completion Operations	Form: (02 ) 400396768 5/16/2013	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.
Planning	Form: (02 ) 400648465 2/27/2015	604c.(2).E. Multiwell Pads: This 2A application is for a 4-well pad. No suitable existing locations are in the area. The location was surface owners preference as it kept impact to farmable ground to a minimum.
Planning	Form: (02 ) 400648465 2/27/2015	604c.(2).V. Development From Existing Well Pads: An existing pad was not available to utilize to develop these wells.
Planning	Form: (02 ) 400648465 2/27/2015	604.c.(2).W. Site Specific Measures: Lights should be turned downward and away from building units within the 1,000 foot buffer area. Dust mitigation will be provided as necessary on lease access roads.
Planning	Form: (02 ) 400648465 2/27/2015	804. Visual Impact: Production facilities, regardless of construction date, which are observable from any public highway will be painted with uniform, non-contrasting, non-reflective color tones (similar to the Munsell Soil Color Coding System), and with colors matched to but slightly darker than the surrounding landscape.
Planning	Form: (02 ) 400648465 2/27/2015	604c.(2).I. BOPE Testing for Drilling Operations: PDC's contractors will supply a double ram BOPE (Blinds and pipes). BOPE is always function tested and all seals and ram block rubbers are inspected. 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 with a third party tester, all tests are digitally recorded and any failed equipment or seals are replaced and re-tested.
Planning	Form: (02 ) 400648465 2/27/2015	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 ) 400648465 2/27/2015	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.
Traffic control	Form: (02 ) 400648465 2/27/2015	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 ) 400648465 2/27/2015	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 ) 400648465 2/27/2015	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.
General Housekeeping	Form: (02 ) 400648465 2/27/2015	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.
Material Handling and Spill Prevention	Form: (02 ) 400648465 2/27/2015	604c.(2).F. Leak Detection Plan: See attached.
Material Handling and Spill Prevention	Form: (02 ) 400648465 2/27/2015	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.
Dust control	Form: (02 ) 400648465 2/27/2015	805.b(1)-(c) Odors and Dust: Oil and gas facilities and equipment will operate in a manner that odors and dust do not constitute a nuisance or hazard to public welfare. Odors: Oil and gas operations will be in compliance with the Department of Public Health and Environment, Air Quality Control Commission, Regulation No. 2 Odor Emission, 5 C.C.R. 1001-4, Regulation No. 3 (5 C.C.R. 1001-5), and Regulation No. 7 Section XVII.B.1 (a-c) and Section XII. Dust; PDC will employ practices for control of fugitive dust caused by operations include but not limited to the use of speed restrictions, regular road maintenance, restriction of construction activity during high-wind days, and silica dust controls when handling sand used in hydraulic fracturing operations. When necessary, PDC coordinates dust mitigation with the county on gravel roads, places road base where allowed by surface owner around tanks and wellheads to minimize dust, and will water the roads and locations when dry. In addition, automation is used on all new wells to minimize truck traffic.
Construction	Form: (02 ) 400648465 2/27/2015	604c.(2).G. Berm Construction: Containment berms shall be constructed of steel rings with a geosynthetic liner, designed and installed to prevent leakage and resist degradation from erosion or routine operation. All berms will be visually checked periodically to ensure proper working condition. Secondary containment devices shall be sufficiently impervious to contain any spilled or released material. Due to a downgradient surface water body within 500’, tertiary containment (such as an earthen berm or the like), will be installed around Production Facilities.
Construction	Form: (02 ) 400648465 2/27/2015	"604c.(2).S. Access Roads: PDC will utilize the existing lease access road off of CR 43, paved, for drilling operations and maintenance equipment. The lease access road will be properly constructed and maintained to accommodate for local emergency vehicle access. Dust will be mitigated as necessary on lease access road. "
Construction	Form: (02 ) 400648465 2/27/2015	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 ) 400648465 2/27/2015	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 ) 400648465 2/27/2015	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.
Noise mitigation	Form: (02 ) 400648465 2/27/2015	604c.(2).A. Noise: WELL PAD: 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 was conducted to identify potential receptors within 1000 feet of the proposed pad site. There are 4 building units of concern There are 4 building units of concern. Light and sound mitigation will be installed to the north and south east of the proposed location. Methods of noise mitigation shall include but not be limited to hay bales, noise walls, or customized semi-trailers. PRODUCTION FACILITIES: It is not anticipated that noise mitigation will be necessary at the proposed tank battery location. After construction is completed, equipment installed and production begins, noise levels will be assessed to determine if mitigation measures will be required to be compliant with Rule 802.
Emissions mitigation	Form: (02 ) 400648465 2/27/2015	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 ) 400648465 2/27/2015	604c.(2).O. Loadlines: All loadlines shall be bullplugged or capped.
Drilling/Completion Operations	Form: (02 ) 400648465 2/27/2015	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.

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