| Engineer | Form: (04)
402377447
08/27/2020 | This approval is good for one year and a new application must be made before 5/28/2021. Updates for the planned utilization of the well should be included with the application including an estimated date for return to production or plugging. |
| Engineer | Form: (04)
402681698
08/02/2021 | 1) This approval is good for one year and a new application must be made before 5/16/2022. Updates for the planned utilization of the well should be included with the application. |
| Engineer | Form: (04)
403121625
08/16/2022 | 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. 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. By 1/6/2023 this well must be plugged and a final Form 4 sundry filed documenting mitigation efforts prior to abandonment., The sundry should include details of the sample analysis interpretation, and the flow rate information and pressure data.
Shut in bradenhead pressure shall not exceed 50 psig.
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| Permit | Form: (06)
403194327
10/19/2022 | Submit a form 5A to report the correct Sussex perfs. This Form 5A must be submitted within 30 days for compliance with Rule 416. |
| OGLA | Form: (06)
403194327
10/20/2022 | 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. |
| OGLA | Form: (06)
403194327
10/20/2022 | COA's provided by the operator as Best Management Practices under Technical Detail/ Comments:
Notification will be given to any adjacent building unit occupants within a 1000 feet of the wellhead of planned P&A start date. |
| OGLA | Form: (06)
403194327
10/20/2022 | Due to proximity to a wetland, surface water and expected shallow groundwater, 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. |
| OGLA | Form: (06)
403194327
10/20/2022 | This oil and gas location is within a CPW-mapped bald eagle roost or communal roost Rule 309.e.(1) consultation habitat. CPW may choose to consult on this planned P&A to develop site specific measures to avoid, minimize, and mitigate impacts to wildlife prior to conducting the work. Please note that non-emergency plugging and abandonment (PA) activities should not take place from November 15 to March 15. Please confirm via email if a consultation with CPW has or will occur and provide any operator BMPs that are the result of that consultation. |
| OGLA | Form: (06)
403194327
10/27/2022 | Operator will consult with the Regional CPW Energy Liaison and employ agreed upon site specific BMPs to avoid, minimize, and mitigate potential impacts to bald eagles prior to conducting site activities. |
| Engineer | Form: (06)
403194327
11/14/2022 | 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)
403194327
11/14/2022 | 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. |
| Engineer | Form: (06)
403194327
11/14/2022 | 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 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 COGCC engineering before continuing operations.
3) Prior to placing plugs above the UPA base at 1375': 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) After isolation has been verified, pump surface casing shoe plug. If surface casing cement is not circulated to surface, shut-in, WOC 4 hours then tag plug – must be at 468’ 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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