| Engineer | Form: (02 )
400455142
10/3/2013 | 1)Provide notice of MIRU via an electronic Form 42.
2)Comply with Rule 317.i and provide cement coverage from the 7” casing TD to a minimum of 200' above the Niobrara and from 200’ below Sussex to 200’ above Sussex. Verify coverage with a cement bond log.
3)Operator acknowledges the proximity of the Wagner Red VV22-8 (API# 123-16668), Wagner Red VV 22-7 (API #123-16667), Albert Sack Unit/NAV/2 (API #123-15327), Moser C Unit 1 (API #123-10488), Dorothy Sebold Unit 1 (API #123-08119), Grenemeyer 1 (API #123-07152), and UPRR 42 Pan AM K 2 (API #123-09215) wells. Operator agrees to: provide mitigation option 1, 2 or 3 (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 (“OTHER – AS SPECIFIED BY PERMIT CONDITION”) stating what appropriate mitigation occurred and that it has been completed, prior to the hydraulic stimulation of this well.
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| Engineer | Form: (02 )
400503426
11/14/2013 | 1)Provide notice of MIRU via an electronic Form 42.
2)Comply with Rule 317.i and provide cement coverage from the 7” casing TD to a minimum of 200' above the Niobrara
and from 200’ below Sussex to 200’ above Sussex. Verify coverage with a cement bond log.
3)Operator acknowledges the proximity of the Wagner Red VV22-8 (API# 123-16668), Wagner Red VV 22-7 (API #123-
16667), Albert Sack Unit/NAV/2 (API #123-15327), Moser C Unit 1 (API #123-10488), Dorothy Sebold Unit 1 (API #123-
08119), Grenemeyer 1 (API #123-07152), and UPRR 42 Pan AM K 2 (API #123-09215) wells. Operator agrees to:
provide mitigation option 1, 2 or 3 (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 (“OTHER –
AS SPECIFIED BY PERMIT CONDITION”) stating what appropriate mitigation occurred and that it has been completed,
prior to the hydraulic stimulation of this well. |
| Engineer | Form: (04 )
402559929
12/31/2020 | 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. 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 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.
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 will 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 twelve consecutive months.
4. Operator will submit a Form 42 (“OTHER”) stating that “bradenhead abatement program has started.”
5. At the conclusion of the twelve 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, flow rate information, pressure data and a discussion of the sample analysis. |
| Engineer | Form: (04 )
402559929
12/31/2020 | Shut in bradenhead pressure shall not exceed 50 psig. |
| Engineer | Form: (04 )
402618914
3/18/2021 | 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. 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 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.
3. Operator will implement measures to get an initial estimate of the gas flow rate and/or volume from the bradenhead.
4. Operator will submit a Form 42 (“OTHER”) stating that “bradenhead abatement program has started.”
5. Within thirty days of 04-Sep-2021, 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, flow rate information, pressure data and a discussion of the sample analysis.
6. Shut in bradenhead pressure shall not exceed 50 psig. |
| Engineer | Form: (04 )
402737667
7/9/2021 |
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. 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 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.
3. Operator will 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. This mitigation plan may be used for six consecutive months from the date test reported on the Form 17.
4. At the conclusion of the six months (16-Dec-2021), 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, sample analysis interpretation, and the flow rate information and pressure data.
Shut in bradenhead pressure shall not exceed 50 psig. |
| Engineer | Form: (04 )
402882107
12/1/2021 | All placed cement shall be verified with a CBL and submitted to COGCC on a Form4 sundry.
Submit successful pressure tests with follow up sundry. |
| OGLA | Form: (06 )
403319559
3/9/2023 | 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 )
403319559
3/9/2023 | COA's provided by the operator as Best Management Practices under Technical Detail/ Comments:
Operations are daylight-only; no lighting impacts are anticipated from operations. |
| OGLA | Form: (06 )
403319559
3/9/2023 | 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. |
| OGLA | Form: (06 )
403319559
3/9/2023 | 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 out plugging and abandonment operations and providing contact information for Kerr McGee's response line and online resources. |
| OGLA | Form: (06 )
403319559
3/9/2023 | 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. |
| Engineer | Form: (06 )
403319559
3/10/2023 | 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.
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| Engineer | Form: (06 )
403319559
3/10/2023 | 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 4700’ 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 cement above the base of the Upper Pierre: 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 shoe plug is not circulated to surface, shut-in, WOC 4 hours then tag plug – must be at 1188’ 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.
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| Engineer | Form: (06 )
403319559
3/10/2023 | 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.
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