| Engineer | Form: (02)
401302856
06/18/2018 | 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. |
| Engineer | Form: (02)
401302856
06/18/2018 | 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 and prior to stimulation or
2) If a delayed completion, 6 months after rig release and prior to stimulation.
3) Within 30 days after first production, as reported on Form 5A.
If a Bradenhead test reports a surface casing pressure greater than 200 psig, stimulation is not allowed until the Engineering Supervisor has been consulted.
|
| Engineer | Form: (02)
401302856
06/18/2018 | Operator acknowledges the proximity of the following non-operated listed 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”) 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.
Kintz 2 (API No 123-36621)
E.L. Minch 22-9D (API No 123-33635)
E.L. Minch 21-9 (API No 123-33637)
E.L. Minch 25-9D (API No 123-33642)
|
| Engineer | Form: (02)
401302856
06/18/2018 | 1) Submit Form 42 electronically to COGCC 48 hours prior to MIRU (Spud Notice), for the first well/activity on the pad and provide 48 hour spud notice for all subsequent wells drilled on the pad.
2) Comply with Rule 317.j and provide cement coverage from the end of production casing to a minimum of 200' above Niobrara. Verify coverage with cement bond log.
3) Oil-based drilling fluid is to be used only after all fresh water aquifers are covered.
|
| Permit | Form: (02)
401302856
07/17/2018 | If conductors are preset, Operator shall comply with Notice to Operators: Procedures for Preset Conductors (dated September 1, 2016, revised October 6, 2016). |
| Permit | Form: (02)
401302856
07/17/2018 | Operator shall comply with Notice to Operators: Interim Reclamation Procedures for Delayed Operation (dated January 5, 2017). |
| Engineer | Form: (06)
403294961
01/25/2023 | 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. |
| Engineer | Form: (06)
403294961
01/25/2023 | 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 4900’ 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) Circulate shoe plug cement to surface if casing is not pulled.
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)
403294961
01/25/2023 | 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.
|
| Engineer | Form: (06)
403294961
01/25/2023 | Perforations at 400' to be performed in a manner that avoids damage to surface casing (low strength charges, casing punches, or other method).
|
| OGLA | Form: (06)
403294961
03/08/2023 | Due to proximity of plugging and abandonment (P&A) operations to BUs, operator will comply with Table 423-1 Maximum Permissible Noise Levels for residential land use. Prior to initiating work, operator will install temporary sound walls, straw bales, or other BMPs to dampen noise if necessary for compliance. |
| Engineer | Form: (04)
403345881
03/24/2023 | 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 six consecutive months.
4. Operator will submit a Form 42 (“OTHER”) stating that “bradenhead abatement program has started.”
5. 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, flow rate information, pressure data and a discussion of the sample analysis.
Shut in bradenhead pressure shall not exceed 50 psig.
|
| Engineer | Form: (06)
403539080
10/04/2023 | 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 ECMC within three (3) months of collecting the samples.
If there is a need for sampling, contact ECMC engineering for verification of plugging procedure.
|
| Engineer | Form: (06)
403539080
10/04/2023 | 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 4900’ 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 surface casing shoe plug: 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) If surface casing shoe plug is not circulated to surface, shut-in, WOC 4 hours then tag plug – must be at 1502’ 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) Prior to cut and cap, verify isolation by either a 15 minute bubble test or 15 minute optical gas imaging recording. 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.
|
| Engineer | Form: (06)
403539080
10/04/2023 | 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 ECMC Spill/Release Report, Form 19, associated with the abandoned line.
|
| Engineer | Form: (06)
403539080
10/04/2023 | Perforations at 400' to be performed in a manner that avoids damage to surface casing (low strength charges, casing punches, or other method).
|
| Engineer | Form: (06)
403969502
11/11/2024 | 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) 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 1502’ or shallower and provide a minimum of 10 sx plug at the surface.
3) Leave at least 100’ of cement in the wellbore for each plug without mechanical isolation.
4) After surface plug and prior to cap, verify isolation by either a 15 minute bubble test or 15 minute optical gas imaging recording. 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.
5) With the Form 6 SRA operator must provide written documentation which positively affirms each COA listed above has been addressed. |
| Engineer | Form: (06)
403969502
11/11/2024 | 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 ECMC Spill/Release Report, Form 19, associated with the abandoned line. |
| Engineer | Form: (06)
403969502
11/11/2024 | 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. |
| Engineer | Form: (06)
403969502
11/11/2024 | 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. |
| OGLA | Form: (06)
404193493
05/20/2025 | COA's provided by the operator as Best Management Practices under Technical Detail / Comments:
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.
Please be aware that Form 6 Approval can predate actual rig work by up to several months and that environmental conditions can change quickly over that time. 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. |
| Engineer | Form: (06)
404193493
05/21/2025 | Deepest Water Well within 1 Mile – 780'
SB5 Base of Fox Hills – N/A |
| Engineer | Form: (06)
404193493
05/21/2025 | 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. |
| Engineer | Form: (06)
404193493
05/21/2025 | 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) Prior to placing cement above the base of the Upper Pierre (1184') : 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.
3) Pump surface casing shoe at 1752' 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 1502' or shallower and provide a minimum of 10 sx plug at the surface.
4) Leave at least 100’ of cement in the wellbore for each plug without mechanical isolation.
5) After cut and prior to cap, verify isolation by either a 15 minute bubble test or 15 minute optical gas imaging recording. 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.
6) With the Form 6 SRA operator must provide written documentation which positively affirms each COA listed above has been addressed. |
| Engineer | Form: (06)
404193493
05/21/2025 | 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 ECMC Spill/Release Report, Form 19, associated with the abandoned line. |