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COGIS DB
 
Facility TypeFacility ID/
API		Facility Name/
Number		Operator Name/
Number		StatusField Name/
Number		LocationLocation IDRelated Facilities
WELL05-123-40248Klein
19M-402 		PDC ENERGY INC
69175		PR
1/2/2026		WATTENBERG
90750		WELD  123
NWNE 19 5N64W 6		438989View Related
 
COGIS - Conditions of Approval Results
TypeSource DocumentConditions of Approval
EngineerForm: (02)
400562499
08/13/2014		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) 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.
EngineerForm: (02)
400562499
08/13/2014		Offset Wells Evaluated.
EngineerForm: (04)
400954148
02/22/2016		1) Submit Form 42 electronically to COGCC 48 hours prior to MIRU. 2) 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.
EngineerForm: (04)
400954148
02/22/2016		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.
EngineerForm: (02)
401026299
04/21/2016		Offset wells evaluated with the original APD.
EngineerForm: (02)
401026299
04/21/2016		The Bradenhead COA on the approved sundry shall be replaced with the following: Bradenhead tests shall be performed and reported 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. 2) 6 months after rig release, prior to stimulation. 3) Within 30 days of first production, as reported on Form 5A.
PermitForm: (02)
401026299
04/26/2016		Approval of this refile APD does not provide relief from compliance with the COGCC Reclamation Rules.
OGLAForm: (06)
404490929
01/20/2026		Due to proximity to a mapped wetland and surface water, 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 and surface water.
OGLAForm: (06)
404490929
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)
404490929
02/09/2026		Operator shall ensure Form 7 reporting is correct. Currently reporting reflects PA status from July 2025 onward despite no PA operations having commenced yet.
EngineerForm: (06)
404490929
02/09/2026		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)
404490929
02/09/2026		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)
404490929
02/09/2026		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)
404490929
02/09/2026		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) After placing plug at 1312’ assure that all fluid migration has been eliminated by monitoring the well for a minimum of 8 hours before proceeding to the next plug. If at any time after placing this plug there is evidence of pressure or of fluid migration, contact ECMC engineering before continuing operations. 3) Prior to placing cement above the base of the Upper Pierre (1380') : 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. 4) 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 1412’ or shallower and provide a minimum of 10 sx plug at the surface. 5) Leave at least 100’ of cement in the wellbore for each plug without mechanical isolation. 6) 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. 7) 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 )
400562499
9/20/2014		604c.(2).E. Multiwell Pads: This 2A application is for a 4-well pad. No suitable existing locations are in the area. Location was chosen by surface owner, Dennis Klein is also in agreement with these locations as they will allow him to install a center pivot for irrigation. Dennis Klein also owns BU 200 feet to the north, is in agreement with location of facility.
PlanningForm: (02 )
400562499
9/20/2014		604c.(2).V. Development From Existing Well Pads: An existing pad was not available to utilize to develop these wells.
PlanningForm: (02 )
400562499
9/20/2014		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. County road used for access has low traffic volume.
PlanningForm: (02 )
400562499
9/20/2014		604c.(2).I. BOPE Testing for Drilling Operations: PDC's contractors will supply a double ram 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 with a third party tester, all tests are digitally recorded.
PlanningForm: (02 )
400562499
9/20/2014		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.
PlanningForm: (02 )
400562499
9/20/2014		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.
PlanningForm: (02 )
400562499
9/20/2014		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.
Traffic controlForm: (02 )
400562499
9/20/2014		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 HousekeepingForm: (02 )
400562499
9/20/2014		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 HousekeepingForm: (02 )
400562499
9/20/2014		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.
General HousekeepingForm: (02 )
400562499
9/20/2014		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.
ConstructionForm: (02 )
400562499
9/20/2014		604c.(2).G. Berm Construction: A geosynthetic liner will be laid under the tanks on this location and a metal containment will be 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 as follows from the nearest well head : ditch 246 feet north-west.
ConstructionForm: (02 )
400562499
9/20/2014		604c.(2).S. Access Roads: PDC will utilize the lease access road off of WCR 51 for drilling operations and maintenance equipment. The lease access road will be properly constructed and maintained to accommodate for local emergency vehicle access.
ConstructionForm: (02 )
400562499
9/20/2014		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.
ConstructionForm: (02 )
400562499
9/20/2014		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.
ConstructionForm: (02 )
400562499
9/20/2014		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.
Noise mitigationForm: (02 )
400562499
9/20/2014		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. A review was conducted to identify potential receptors within 1000 feet of the proposed Klein 19MN-HZ Pad site. There are two building units of concern. The three building units are located as follows: NW of the proposed pad at a distance of approximately 200 feet, and NW of the proposed pad at a distance of approximantely 608 feet. Based on the receptors locations, projected noise levels are anticipated to exceed the Light Industrial Zone standard of 65 decibels (db) at the receptor location. Therefore, noise mitigation will be necessary for the Klein 19MN-HZ pad. A sound wall will be installed to the north of the proposed location prior to drilling and completion activities, 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.
Drilling/Completion OperationsForm: (02 )
400562499
9/20/2014		604c.(2).O. Loadlines: All loadlines shall be bullplugged or capped.
Drilling/Completion OperationsForm: (04 )
400954148
2/22/2016		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.
PlanningForm: (02 )
401026299
5/4/2016		604c.(2).E. Multiwell Pads: This 2A application is for a 4-well pad. No suitable existing locations are in the area. Location was chosen by surface owner, Dennis Klein is also in agreement with these locations as they will allow him to install a center pivot for irrigation. Dennis Klein also owns BU 200 feet to the north, is in agreement with location of facility.
PlanningForm: (02 )
401026299
5/4/2016		604c.(2).V. Development From Existing Well Pads: An existing pad was not available to utilize to develop these wells.
PlanningForm: (02 )
401026299
5/4/2016		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. County road used for access has low traffic volume.
PlanningForm: (02 )
401026299
5/4/2016		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.
Traffic controlForm: (02 )
401026299
5/4/2016		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 )
401026299
5/4/2016		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.
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