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COGIS DB
 
Facility TypeFacility ID/
API		Facility Name/
Number		Operator Name/
Number		StatusField Name/
Number		LocationLocation IDRelated Facilities
WELL05-123-43304HILGERS
8N-34HZ 		KERR MCGEE OIL & GAS ONSHORE LP
47120		SI
11/1/2023		WATTENBERG
90750		MEAD/WELD  123
SESE 22 3N68W 6		331768View Related
 
COGIS - Conditions of Approval Results
TypeSource DocumentConditions of Approval
EngineerForm: (02)
400930115
05/13/2016		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 the 7-inch string to a minimum of 200' above Niobrara. Verify coverage with cement bond log.
EngineerForm: (02)
400930115
05/13/2016		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.
EngineerForm: (04)
401149816
12/19/2016		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. Verify coverage with cement bond log.
PermitForm: (04)
401149816
01/12/2017		This Permit to Drill is approved subject to all the BMPs and COAs on the most recently approved Form 2A and any subsequently approved Form 4 for the Oil and Gas Location (Location ID #331768). The most recently approved Form 2A and any subsequent Form 4s containing applicable COAs for this location shall be posted onsite during construction, drilling, and completions operations.
EngineerForm: (04)
403039306
05/05/2022		The well must successfully pass a MIT or plugged and abandoned within 6 months of casing integrity issue, no later than 03-Nov-2022.
EngineerForm: (04)
403039306
05/06/2022		Pressure test to be submitted on Form 21 within 30 days of the pressure test.
OGLAForm: (04)
403039306
05/10/2022		Operator will implement measures to capture, combust, or control emissions to protect health and safety, and to ensure that vapors and odors from well repair/maintenance, well perforating, and/or testing operations with a workover rig, wireline rig, or other heavy equipment 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.
OGLAForm: (04)
403039306
05/10/2022		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 well repair/maintenance, well perforating, and/or testing operations with a workover rig, wireline rig, or other heavy equipment.
OGLAForm: (06)
404583478
03/25/2026		Notification will be given to any adjacent building unit occupants within 1,000 feet of the wellhead of planned P&A start date.
OGLAForm: (06)
404583478
03/25/2026		Operator committed to the following Best Management Practices under the Technical Detail/ Comments section on the Submit Tab: Signage for P&As: Prior to commencing operations, Kerr McGee will post signs in conspicuous locations. The signs will indicate plugging and abandonment operations are being conducted, the well name, well, and the Operator’s contact information. Signs will be placed so as not to create a potential traffic hazard. Notifications: Courtesy notifications will be sent to all parcel owners with building units within 1,500 feet of the location letting them know about out plugging and abandonment operations and providing contact information for Kerr McGee's response line and online resources. Wellbore Pressure: In some cases, wellbore pressure drawdown operations may occur approximately 1-2 days prior to Move In Rig Up (MIRU) of the workover rig. This is conducted to allow for reduced time that the workover rig is needed on location. These operations will be conducted in accordance with Form 4 and/or Form 6 requirements. Water: Water will be placed on dirt access roads to mitigate dust as needed. Lighting: Operations are daylight-only; no lighting impacts are anticipated from operations. Noise: Operations will be in compliance with Table 423-1 requirements. Based off the rig sound signature, rig orientation will be considered to reduce noise levels to nearby building units.
EngineerForm: (06)
404583478
04/06/2026		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)
404583478
04/06/2026		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)
404583478
04/06/2026		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)
404583478
04/06/2026		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) Operator shall run a new CBL to verify existing TOC. Provide a copy to ECMC engineering for verification of plugging orders. 3) After placing plug at 2500’ 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. 4) Prior to placing cement above the base of the Upper Pierre (1313') : 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. 5) 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 1763’ or shallower and provide a minimum of 10 sx plug at the surface. 6) Leave at least 100’ of cement in the wellbore for each plug without mechanical isolation. 7) 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. 8) 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 )
400930115
6/22/2016		604c.(2).E. Multi-Well Pads: In order to reduce surface impact, this application is for a nine-well pad.
PlanningForm: (02 )
400930115
6/22/2016		604c.(2).Q. Guy Line Anchors: Should guy line anchors be left buried for future use, they shall be identified by a bright marker greater than four (4) feet high and no more than one (1) foot east of the guy line anchor.
PlanningForm: (02 )
400930115
6/22/2016		604c.(2).R. Tank Specifications: Two 500 barrel skid-mounted frac tanks will be temporarily placed on-site for use of the pre-spud rig only. One tank will store water and the other will store water based mud.
PlanningForm: (02 )
400930115
6/22/2016		604c.(2).S. Access Roads: KMG will utilize a lease access road from Highway 66 for drilling, completions, and production operations, including maintenance equipment. The road will be properly constructed and maintained to accommodate for local emergency vehicle access.
PlanningForm: (02 )
400930115
6/22/2016		604c.(2).V. Development From Existing Well Pads: KMG will locate the nine new proposed horizontal wells on the existing well pad with location ID # 331768 to reduce the amount of surface disturbance associated with this project.
Community Outreach and NotificationForm: (02 )
400930115
6/22/2016		305.a.(2) A Notice of Intent to Conduct Operations was sent to each building unit owner within the Exception Zone or Buffer Zone Setback. Recipients did not contact KMG. As a part of planning this proposed location, Kerr-McGee held multi-disciplinary Surface Impact Planning Meetings regarding the impacts and mitigations associated with this proposed location. The toll-free hotline number and email for the Anadarko Colorado Response Line will be posted at the entrance to the lease access road for stakeholders during drilling and completion operations at this proposed location. Courtesy Notifications will be sent to impacted stakeholders prior to drilling operations and again prior to completions operations, providing contact information for the Anadarko Colorado Response Line and online resources.
Traffic controlForm: (02 )
400930115
6/22/2016		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 )
400930115
6/22/2016		604c.(2).O. Loadlines: All loadlines shall be bullplugged or capped.
General HousekeepingForm: (02 )
400930115
6/22/2016		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 )
400930115
6/22/2016		604c.(2).G. Berm Construction: Kerr-McGee will create tertiary containment by construction of a berm or diversion dike, site grading, or other comparable measures sufficient to further protect the ditch located 698' SW of this proposed oil and gas location.
Storm Water/Erosion ControlForm: (02 )
400930115
6/22/2016		604c.(2).W. Site-Specific Measures: KMG maintains a Storm Water Management Plan that assesses erosion control for every KMG operated location. This location will be added to this plan once construction begins. This site will be inspected every fourteen (14) days during construction activities, every twenty-eight (28) days after construction is completed, and after any major weather event.
Material Handling and Spill PreventionForm: (02 )
400930115
6/22/2016		604c.(2).N. Control of Fire Hazards: KMG and its contractors will employ best management practices during the drilling and production of its wells and facilities and will comply with appropriate COGCC rules concerning safety and fire. KMG will ensure that any material that might be deemed a fire hazard will remain no less than twenty-five (25) feet from the wellhead(s), tanks and separator(s).
Dust controlForm: (02 )
400930115
6/22/2016		805.c. Dust: Water will be placed on dirt access roads to mitigate dust as needed. If feasible, magnesium chloride will also be used as needed on access roads to further abate dust. Highway 66 is paved and maintained by Weld County and will therefore not require dust mitigation. Straw bales places on location will further help to minimize dust impacts from operations on location to the surrounding area.
ConstructionForm: (02 )
400930115
6/22/2016		604c.(2).M. Fencing Requirements: The completed wellsites will be surrounded with a fence and gate with adequate lock to restrict access to authorized personnel only. KMG personnel will monitor the wellsites regularly upon completion of the wells. Authorized representatives and/or KMG personnel shall be on-site during drilling and completion operations.
Noise mitigationForm: (02 )
400930115
6/22/2016		604c.(2).A. Noise: Sound surveys have been conducted on each rig type and are utilized to anticipate any additional effective noise mitigation once a drilling rig is determined. At a minimum, and pending a safety review after construction of the location, sound mitigation barriers (straw bales) will be placed around the perimeter of the pad location (excluding access points) to dampen noise and minimize impact to the nearby residences and to Highway 66 and Interstate 25 during drilling and completions. Operations are not expected to significantly impact the building units on the other side of the Interstate, due to the commercial/industrial nature of the building units and the ambient noise from the Interstate. Should technological advancements allow for better noise mitigation at the time of drilling and completion operations on this location, Kerr-McGee will re-evaluate the most effective method at that time.
Drilling/Completion OperationsForm: (02 )
400930115
6/22/2016		604c.(2).B. Closed Loop Drilling System: KMG will use a closed loop or “pitless” system for drilling and fluid management and will not construct a reserve pit.
Drilling/Completion OperationsForm: (02 )
400930115
6/22/2016		604c.(2).C. Green Completions: Temporary above ground polyethylene water pipelines will deliver water to location operations from larger trunk lines to reduce truck traffic and minimize air pollution. Pipeline infrastructure is in place prior to completions operations to ensure saleable gas, once hydrocarbons are cut, is sent directly to sales without flaring during flowback.
Drilling/Completion OperationsForm: (02 )
400930115
6/22/2016		604c.(2).H. BOPE: Our rigs at a minimum will have a double ram with blind and pipe ram and annular preventer.
Drilling/Completion OperationsForm: (02 )
400930115
6/22/2016		604c.(2).I. BOPE Testing for Drilling Operations: Upon initial rig-up, BOPEs will be tested at a minimum of every 30 days.
Drilling/Completion OperationsForm: (02 )
400930115
6/22/2016		604c.(2).J. BOPE for Well Servicing Operations: Blowout prevention equipment will be used on any servicing operations associated with this well. Backup stabbing valves will be used during any future servicing operations during reverse circulation. Valves shall be pressure tested before each well servicing operation using low-pressure air and high-pressure fluid.
Drilling/Completion OperationsForm: (02 )
400930115
6/22/2016		604c.(2).K. Pit Level Indicators: All storage tanks used for active drilling operations (used in lieu of pits) contain pit level monitors with Electronic Drilling Recorders (EDR). KMG uses EDRs with pit level monitor(s) and alarm(s) for production rigs. Basic level gauges are used on tanks utilized for the surface rig.
Drilling/Completion OperationsForm: (02 )
400930115
6/22/2016		604c.(2).L. Drill Stem Tests: No drill stem tests are planned and none will be performed without prior approval from the Director.
Drilling/Completion OperationsForm: (02 )
400930115
6/22/2016		803. Lighting: To the extent practicable, site lighting shall be shielded and directed downward and inward toward operations to avoid glare on public roads and nearby Building Units. Straw bales placed on location will further assist in mitigating light nuisance for residents and drivers in the area. LED lighting will be utilized during completions operations on this location.
Drilling/Completion OperationsForm: (02 )
400930115
6/22/2016		Visual Mitigation: A flare enclosure will be utilized during drilling operations. Straw bales will also assist in providing visual mitigation during drilling and completion operations.
Drilling/Completion OperationsForm: (02 )
400930115
6/22/2016		604.c.(4)B.i. Production Facility will be automated and remotely monitored by the Integrated Operations Center (IOC) at all times. In the event of a fire, explosion or lighting strike, wells flowing to the Production Facility would be remotely shut-in and Kerr McGee’s Emergency Response Plan would be initiated. This location is bonded and grounded and static is not a concern due to the lack of oil storage tanks.
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