| Agency | Form: (02 )
400025131
1/28/2010 | Location is less than 150 feet from property line; exception granted |
| Agency | Form: (02 )
400025131
1/28/2010 | Location is less than 150 feet from property line; exception granted |
| Agency | Form: (02 )
400025131
1/29/2010 | 1) Provide 24 hour notice of MIRU to Bo Brown at 970-397-4124 or e-mail at bo.brown@state.co.us. 2) Comply with Rule 317.i 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) 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. |
| Agency | Form: (02 )
400025131
2/6/2010 | RULE 603.a.(2) EXCEPTION LOCATION (PROPERTY LINE @ 38’) REVIEWED BY CDPHE FOR FORM 2A, GRANTED BY COGCC |
| Engineer | Form: (04 )
400629977
6/20/2014 | The additional cement referenced shall be placed as indicated and comply with Rule 317.i. The placed cement shall be verified with a CBL and documented with a Form 5 Drilling Completion Report. |
| Engineer | Form: (04 )
402310309
5/1/2020 | 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 mitigation, 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. Operator shall implement measures to get an initial estimate of the gas flow rate and/or volume from the bradenhead. During the shut-in period record pressure data to adequately characterize the build-up.
4. This mitigation plan may be used for six consecutive months from the approved sundry date. At the conclusion of the six months, 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. |
| Engineer | Form: (04 )
402567722
1/11/2021 | 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. This well is scheduled to be plugged in 2022. Operator will continue to manage, monitor and mitigate pressures for this well. A Form 4 bradenhead plan report of work done will be submitted within 30 days of 01/11/2022 (12 months from approval date). The sundry should include monthly pressure monitoring data, flow rate information, sample analysis interpretation, and bradenhead test description.
3. Shut in bradenhead pressure shall not exceed 50 psig. |
| Engineer | Form: (04 )
402944477
2/28/2022 | 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. Well to plugged no later than 12/31/2022. Pressure is to be managed and mitigated until plugging is complete. Summary of well monitoring and mitigation will be submitted on a Form 4 Sundry within 30 days of the well being plugged and abandoned but no later than 12/31/2022. The sundry should include monthly pressure monitoring data, flow rate information, sample analysis interpretation, and bradenhead test description.
3. Shut in bradenhead pressure shall not exceed 50 psig. |
| OGLA | Form: (06 )
403112409
8/4/2022 | COA's provided by the operator as Best Management Practices under Technical Detail/ Comments:
Prior to commencing operations, KMG 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. |
| OGLA | Form: (06 )
403112409
8/4/2022 | COA's provided by the operator as Best Management Practices under Technical Detail/ Comments:
Courtesy notifications will be sent to all parcel owners with building units within 1,500 feet of the location letting them know about our plugging and abandonment operations and providing contact information for Kerr McGee’s response line and online resources. |
| OGLA | Form: (06 )
403112409
8/4/2022 | COA's provided by the operator as Best Management Practices under Technical Detail/ Comments:
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. |
| OGLA | Form: (06 )
403112409
8/4/2022 | COA's provided by the operator as Best Management Practices under Technical Detail/ Comments:
Water will be placed on dirt access roads to mitigate dust as needed.
Operations are daylight-only; no lighting impacts are anticipated from operations. |
| OGLA | Form: (06 )
403112409
8/4/2022 | This oil and gas location is within a Mule Deer Severe Winter Concentration Area High Priority Habitat. Well completions activities should not take place from December 1 to April 30. If activities must take place from December 1 to April 30, operator will consult with CPW to determine site-specific measures to avoid, minimize, and mitigate adverse impacts to wildlife and the environment. At a minimum, operations with heavy machinery will not start before 8 a.m. and will cease at 4 p.m. |
| OGLA | Form: (06 )
403112409
8/4/2022 | This oil and gas location is within 0.5-mile of a CPW-mapped bald eagle nest area. Plugging and abandonment (PA) should not occur from December 1 to July 31. If site conditions warrant that PA activities must be performed from December 1 to July 31, Operator will consult with the regional CPW Energy Liaison to develop site specific measures to avoid, minimize, or mitigate impacts to wildlife. |
| Engineer | Form: (06 )
403112409
9/8/2022 | 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.
If there is a need for sampling, contact COGCC engineering for verification of plugging procedure. |
| Engineer | Form: (06 )
403112409
9/8/2022 | 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 4320’ 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 COGCC engineering before continuing operations.
3) Prior to placing the 1550’ plug: verify that all fluid (liquid and gas) migration has been eliminated. If evidence of fluid migration or pressure remains, contact COGCC Engineer for an update to plugging orders.
4) If surface casing cement is not circulated to surface, shut-in, WOC 4 hours then tag plug – must be at 557’ 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) With the Form 6 SRA operator must provide written documentation which positively affirms each COA listed above has been addressed.
|
| Engineer | Form: (06 )
403112409
9/8/2022 | 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 with the Form 27: pressure test results conducted in the prior 12 months as well as identification of any document numbers for a COGCC Spill/Release Report, Form 19, associated with the abandoned line. |