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COGIS DB
 
Facility TypeFacility ID/
API		Facility Name/
Number		Operator Name/
Number		StatusField Name/
Number		LocationLocation IDRelated Facilities
WELL05-123-42691Connie
26F-402 		PDC ENERGY INC
69175		SI
4/1/2024		WATTENBERG
90750		WELD  123
NWNW 26 5N64W 6		444694View Related
 
COGIS - Conditions of Approval Results
TypeSource DocumentConditions of Approval
Engineering TechForm: (02)
400942872
12/28/2015		1) Submit Form 42 electronically to COGCC 48 hours prior to MIRU (Spud Notice), for the first well/activity on the pad and provide 48 hour spud notice for all subsequent wells drilled on the pad. 2) Comply with Rule 317.j and provide cement coverage from the end of 7” casing to a minimum of 200' above Niobrara. Verify coverage with cement bond log.
EngineerForm: (02)
400942872
12/28/2015		Offset Wells Evaluated
EngineerForm: (04)
401019254
04/05/2016		COA's attached to the original APD still apply.
EngineerForm: (04)
402076683
12/17/2019		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 abatement, 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. 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 shall 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 January 15, 2020, 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.
EngineerForm: (04)
402076685
09/13/2021		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 be routed to an enclosed tank and/or combustor. Shut in bradenhead pressure shall not exceed 50 psig. Operator will implement measures to get an estimate of the gas flow rate and/or volume from the bradenhead. 3. Within thirty days of 8/5/2021, conduct a bradenhead test, submit a Form 17, and submit a Form 4 Sundry that summarizes current well condition. The sundry should include details of the future plans, sample analysis interpretation, bradenhead test description, and the flow rate information and pressure data. 4. Shut well in for at least seven days to monitor build up pressures then conduct a new bradenhead test and submit the Form 17 within ten days of the test. 5. 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 COGCC within three months of collecting the samples.
EngineerForm: (04)
403393705
05/12/2023		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. Bradenhead gas is not to be vented to the atmosphere; any gas from the Bradenhead will be routed to an enclosed tank and/or combustor. Shut in bradenhead pressure shall not exceed 50 psig. Operator will implement measures to get an estimate of the gas flow rate and/or volume from the bradenhead. 3. By 5/2/2024, conduct a bradenhead test, submit a Form 17, and submit a Form 4 Sundry that summarizes current well condition. The sundry should include details of the future plans, sample analysis interpretation, bradenhead test description, and the flow rate information and pressure data. 4. Shut well in for at least seven days to monitor and collect data to characterize build up pressures then conduct a new bradenhead test and submit the Form 17 within ten days of the test. 5. 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 COGCC within three months of collecting the samples.
EngineerForm: (04)
404005498
01/13/2025		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 4/19/25, 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.
EngineerForm: (04)
404185960
05/23/2025		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. 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 4/9/26, 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.
OGLAForm: (06)
404489097
01/20/2026		Due to proximity to a mapped wetland, Operator will use secondary containment for all tanks and other liquid containers. Operator will implement stormwater BMPs and erosion control measures as needed to prevent sediment and stormwater runoff from entering the wetland.
OGLAForm: (06)
404489097
01/20/2026		Operator committed to the following Best Management Practices under the Technical Detail/Comments section on the Submit Tab: 3rd party wildlife surveys will be conducted on this well prior to rigging up for P&A activities. Notification will be given to any adjacent building unit occupants within a 1000 feet of the wellhead of planned P&A start date. Chevron’s Environmental Site Screening Process incorporates full environmental field clearances within 7 days of a scheduled well-work activity once the well is added to the active workover rig schedule. Should sensitive HPH conditions be identified during the screening process, Chevron will delay the work until conditions (nesting) clear and/or consult directly with CPW for guidance and discussion of potential mitigation measures that may be incorporated.
EngineerForm: (06)
404489097
02/06/2026		Consistent with Rule 911.a, a Form 27 must be approved prior to cut and cap, conducting flowline abandonment, or removing production equipment. Allow 30 days for Director review of the Form 27; include the Form 27 document number on the Form 44 for offsite flowline abandonment (if applicable) and on the Form 6 Subsequent. Properly abandon flowlines per Rule 1105. If flowlines will be abandoned in place, include details with the Form 27.
EngineerForm: (06)
404489097
02/06/2026		Operator shall implement measures to control venting, 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 welfare.
EngineerForm: (06)
404489097
02/06/2026		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 ECMC within three (3) months of collecting the samples. If there is a need for sampling, contact ECMC engineering for verification of plugging procedure.
EngineerForm: (06)
404489097
02/06/2026		1) Provide electronic Form 42 Notice of MIRU 2 business days ahead of operations and electronic Form 42 Notice of Plugging Operations 48 hours prior to mobilizing for plugging operations. These are two separate notifications, required by Rules 405.e and 405.l. 2) Prior to placing cement above the base of the Upper Pierre (1330') : verify that all fluid (liquid and gas) migration has been eliminated. If evidence of fluid migration or pressure remains, contact ECMC Engineer for an update to plugging orders. 3) Pump surface casing shoe plug only after isolation has been verified. If surface casing cement is not circulated to surface, shut-in, WOC 4 hours then tag plug – must be at 1417’ or shallower and provide a minimum of 10 sx plug at the surface. 4) Leave at least 100’ of cement in the wellbore for each plug without mechanical isolation. 5) After surface plug and prior to cap, verify isolation by either a 15 minute bubble test or 15 minute optical gas imaging. If there is indication of flow contact ECMC Engineering. Provide a statement on the 6SRA which method was used and what was observed. Retain records of final isolation test for 5 years. 6) With the Form 6 SRA operator must provide written documentation which positively affirms each COA listed above has been addressed.
 
COGIS - Best Management Practice Results
BMP TypeSource DocumentBest Management Practices
PlanningForm: (02 )
400942872
2/5/2016		604c.(2).E. Multiwell Pads: This 2A application is for a 5-well pad. PDC Energy considered all options for this area including Landowner concerns. The Landowner, Connie Bihain and the Tenant farmer, Kevin Chesnut "Strongly Preferred" that the facilites were located out of the irrigated field and Pivot. They did not want to loose any farmed acreage to our operations. There is also a JBS Feedlot to the east end of the 1/4 and 1/2 section which ruled out that area. With this location we were also able to use an existing access point that was preferred by Weld County. There are two old buildings currently located on the property and within the battery and well site locations which will be removed by 1/20/2016.
PlanningForm: (02 )
400942872
2/5/2016		604c.(2).V. Development From Existing Well Pads: An existing pad was not available to utilize to develop these wells.
Traffic controlForm: (02 )
400942872
2/5/2016		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 HousekeepingForm: (02 )
400942872
2/5/2016		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 HousekeepingForm: (02 )
400942872
2/5/2016		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.
Storm Water/Erosion ControlForm: (02 )
400942872
2/5/2016		This Stormwater Management Plan contains required elements associated with PDC’s construction activities, as defined in the CDPS General Permit for Stormwater Discharges Associated with Construction Activity, Authorization to Discharge Under the Colorado Discharge Permit System (Permit No. COR-030000, re-issued and effective July 1, 2007).BMPs for sediment and erosion control will be accomplished through a combination of construction techniques, vegetation and re-vegetation, administrative controls, and structural features.
Dust controlForm: (02 )
400942872
2/5/2016		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.
ConstructionForm: (02 )
400942872
2/5/2016		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.
ConstructionForm: (02 )
400942872
2/5/2016		"604c.(2).S. Access Roads: PDC will utilize an improved lease access road off of County Road 54 (dirt) all heavy truck traffic and rig moves along with 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. "
Noise mitigationForm: (02 )
400942872
2/5/2016		"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 three (3) building units of concern located 239' NW, 321' NW and 540' SW. Light and sound mitigation will be installed to the West and South of the proposed location. Methods of noise mitigation shall include but not be limited to hay bales, sound 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 mitigationForm: (02 )
400942872
2/5/2016		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 OperationsForm: (02 )
400942872
2/5/2016		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.
Drilling/Completion OperationsForm: (02 )
400942872
2/5/2016		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.
Drilling/Completion OperationsForm: (02 )
400942872
2/5/2016		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.
Drilling/Completion OperationsForm: (02 )
400942872
2/5/2016		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. 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 OperationsForm: (02 )
400942872
2/5/2016		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 OperationsForm: (02 )
400942872
2/5/2016		One of the first wells drilled on the pad will be logged with Cased hole Pulsed Neutron Log with Gamma Ray Log from TD 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 in that well and have those logs attached. The Form 5 for each well shall clearly state “No open-hole logs were run” and shall reference the Rule 317.p Exception granted for the well.
Drilling/Completion OperationsForm: (02 )
400942872
2/5/2016		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.
Drilling/Completion OperationsForm: (02 )
400942872
2/5/2016		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.
Drilling/Completion OperationsForm: (02 )
400942872
2/5/2016		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.
Drilling/Completion OperationsForm: (02 )
400942872
2/5/2016		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.
Drilling/Completion OperationsForm: (02 )
400942872
2/5/2016		604c.(2).O. Loadlines: All loadlines shall be bullplugged or capped.
Drilling/Completion OperationsForm: (02 )
400942872
2/5/2016		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.
Drilling/Completion OperationsForm: (02 )
400942872
2/5/2016		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.
Drilling/Completion OperationsForm: (02 )
400942872
2/5/2016		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.
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