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COGIS DB
 
Facility TypeFacility ID/
API		Facility Name/
Number		Operator Name/
Number		StatusField Name/
Number		LocationLocation IDRelated Facilities
WELL05-001-09948Rio LC
12-363HNX 		PDC ENERGY INC
69175		PR
5/1/2025		WATTENBERG
90750		ADAMS  001
NWNW 6 1S67W 6		320491View Related
 
COGIS - Conditions of Approval Results
TypeSource DocumentConditions of Approval
EngineerForm: (02 )
400956406
5/25/2016		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 end of 7” casing to a minimum of 200' above Niobrara and from 200’ below Sussex to 200’ above Sussex. Verify coverage with cement bond log.
EngineerForm: (02 )
400956406
5/25/2016		1) Bradenhead test shall be performed within 60 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.
EngineerForm: (02 )
400956406
5/25/2016		Operator acknowledges the proximity of the non-operated listed well(s). 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. 05-001-07108, BEISEL UNIT 1 ;
PermitForm: (02 )
401772605
1/29/2019		Drilling Beyond the Unit Boundary Setback: Operator will ensure the wellbore beyond the unit boundary setback is physically isolated and is not completed. In the Operator Comments on the Form 5A the operator will (1) report the footages from the section lines of the bottom of the completed interval, (2) describe how the wellbore beyond the unit boundary setback is physically isolated, and (3) certify that none of the wellbore beyond the setback was completed.
EngineerForm: (02 )
401772605
4/3/2019		Operator acknowledges the proximity of the listed wells. Operator assures that this offset list 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. Operator will assure that the listed well’s Bradenhead is open and monitored during the entire stimulation treatment – a person will monitor for any evidence of fluid, a Bradenhead test will be performed prior to the beginning of stimulation. 123-34470, NORTHGLENN STATE 15-36; 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. 001-09291, BREDEHOFT 13-6 ; Operator acknowledges the proximity of the listed wells. Operator agrees to: provide mitigation option 1 or 2 (per the DJ Basin Horizontal Offset Policy) to mitigate the situation, or adequately demonstrate isolation is present, 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. 001-09091, VEAL 14-6 (1) ; Operator acknowledges the proximity of the listed wells. Operator agrees to provide mitigation Option 1 or 2 (per the DJ Basin Horizontal Offset Policy), ensure all applicable documentation is submitted, and submit Form 42(s) (“OFFSET MITIGATION COMPLETED”) for the remediated wells, 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. Operator will assure that the well’s required aquifer isolation is present and verified. 001-08886, REHFELD K UNIT 1 ; 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), ensure all applicable documentation is submitted, and submit Form 42(s) (“OFFSET MITIGATION COMPLETED”) for the remediated wells, 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. Operator will assure that the well’s required aquifer isolation is present and verified. 001-07059, SACK 1
EngineerForm: (02 )
401772605
4/3/2019		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. 3) Oil-based drilling fluid is to be used only after setting surface casing. Per COGCC Order 1-232, Bradenhead tests shall be performed according to the following schedule and Form 17 submitted within 10 days of each test: 1) Within 60 days of rig release, prior to stimulation. If any pressure greater than 200 psi, must contact COGCC engineer prior to stimulation. 2) If a delayed completion, 6 months after rig release and prior to stimulation. If any pressure greater than 200 psi, must contact COGCC engineer prior to stimulation. 3) A post-production test within 60 days after first sales, as reported on the Form 10, Certificate of Clearance.
EngineerForm: (02 )
401772605
4/3/2019		All Stimulation Setback Consent letters for this pad must be received prior to commencing stimulation work
EngineerForm: (04 )
402766456
8/2/2021		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. Bradenhead gas is not to be vented to the atmosphere; any gas from the Bradenhead will be routed to the specified abatement system. Shut in bradenhead pressure shall not exceed 50 psig. Operator shall implement measures to get an estimate of the gas flow rate and/or volume from the bradenhead. 3. Within thirty days of 2/09/2022, 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 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.
 
COGIS - Best Management Practice Results
BMP TypeSource DocumentBest Management Practices
PlanningForm: (02 )
400956406
5/31/2016		604c.(2).V. Development From Existing Well Pads: An existing pad was not available to utilize to develop these wells.
PlanningForm: (02 )
400956406
5/31/2016		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.
PlanningForm: (02 )
400956406
5/31/2016		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.
PlanningForm: (02 )
400956406
5/31/2016		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.
PlanningForm: (02 )
400956406
5/31/2016		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.
PlanningForm: (02 )
400956406
5/31/2016		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.
PlanningForm: (02 )
400956406
5/31/2016		One of the first wells drilled on the pad will be logged with Cased hole Pulsed Neutron Log with Gamma Ray Log from 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 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.
Traffic controlForm: (02 )
400956406
5/31/2016		"604c.(2).S. Access Roads: PDC will utilize an improved lease access road off of Colorado Blvd. for 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. "
Traffic controlForm: (02 )
400956406
5/31/2016		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 )
400956406
5/31/2016		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 )
400956406
5/31/2016		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.
General HousekeepingForm: (02 )
400956406
5/31/2016		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.
Dust controlForm: (02 )
400956406
5/31/2016		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 )
400956406
5/31/2016		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.
ConstructionForm: (02 )
400956406
5/31/2016		604c.(2).O. Loadlines: All loadlines shall be bullplugged or capped.
ConstructionForm: (02 )
400956406
5/31/2016		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.
ConstructionForm: (02 )
400956406
5/31/2016		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.
Noise mitigationForm: (02 )
400956406
5/31/2016		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 2 building units of concern located 654 feet north-east and 812 feet north-east. Light and sound mitigation will be installed to the north, east and west sides 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 mitigationForm: (02 )
400956406
5/31/2016		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 )
400956406
5/31/2016		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 )
400956406
5/31/2016		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 )
400956406
5/31/2016		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 )
400956406
5/31/2016		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 )
401772605
6/7/2019		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 down hole formation pressures and/or collecting down hole fluid samples from the target formation(s) of a particular well.
Drilling/Completion OperationsForm: (02 )
401772605
6/7/2019		Wellbore Collision Prevention – Rule 317.r Prior to drilling operations, GWOG 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 well path with its respective error of uncertainty. If current surveys do not exist for the offset wells, Operator may have gyro surveys conducted to verify bottom hole 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.
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