| Engineer | Form: (02)
400580742
04/02/2014 | Operator acknowledges the proximity of the listed wells. Operator agrees to provide mitigation Option 1 or 2 (per the DJ Basin Horizontal Offset Policy, ensure all applicable documentation is submitted based on the selected mitigation option chosen, and submit a Form 42(s) (“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.
Lofland #44-22 (API #123-13064)
Lorenz Farms #22-13 (API #123-19256)
Buderus #13-23 (API #123-12541)
Lillie #1-23 (API #123-12868)
Susan #1-23 (API #123-12902)
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| Engineer | Form: (02)
400580742
04/02/2014 | Operator acknowledges the proximity of the listed non operated wells. Operator agrees to provide mitigation Option 1 or 2 (per the DJ Basin Horizontal Offset Policy, ensure all applicable documentation is submitted based on the selected mitigation option chosen, and submit a Form 42(s) “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.
Lofland #22-42 (API #123-19227)
Billy #22-45 (API #123- 24111)
Doll #23-1 (API #123-11886)
Doll PM F #23-5 (API #123-14216) |
| Engineer | Form: (02)
400580742
04/02/2014 | Operator acknowledges the proximity of the listed, previously identified wells. Operator agrees to provide mitigation Option 1 or 2 (per the DJ Basin Horizontal Offset Policy, ensure all applicable documentation is submitted based on the selected mitigation option chosen, and submit a Form 42(s) (“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.
Alles 9-22 (API #123-14163)
Buderus #12-23 (API #123-12540)
Esther #1-23 (API #123-12672) |
| Engineer | Form: (04)
402075650
12/16/2019 | 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 abatement, 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. 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 shall 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. By January 15, 2020, 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.
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| Engineer | Form: (04)
402470193
01/11/2021 | 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. Bradenhead gas is not to be vented to the atmosphere; any gas from the Bradenhead will be routed to an enclosed tank and/or combustor. Shut in bradenhead pressure shall not exceed 50 psig. Operator will implement measures to get an estimate of the gas flow rate and/or volume from the bradenhead.
3. Within thirty days of 2/18/2021, conduct a bradenhead test, submit a Form 17, and submit a Form 4 Sundry that summarizes current well condition. The sundry should include details of the future plans, sample analysis interpretation, bradenhead test description, and the flow rate information and pressure data.
4. Shut well in for at least seven days to monitor build up pressures then conduct a new bradenhead test and submit the Form 17 within ten days of the test.
5. If a sample has not been collected from surface casing within the last twelve months collect bradenhead 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.
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| Engineer | Form: (04)
403063915
06/02/2022 | 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. Bradenhead gas is not to be vented to the atmosphere; any gas from the Bradenhead will be routed to an enclosed tank and/or combustor. Shut in bradenhead pressure shall not exceed 50 psig. Operator will implement measures to get an estimate of the gas flow rate and/or volume from the bradenhead.
3. Within thirty days of 12/1/2022, conduct a bradenhead test, submit a Form 17, and submit a Form 4 Sundry that summarizes current well condition. The sundry should include details of the future plans, sample analysis interpretation, bradenhead test description, and the flow rate information and pressure data.
4. Shut well in for at least seven days to monitor and collect data to characterize build up pressures then conduct a new bradenhead test and submit the Form 17 within ten days of the test.
5. If a sample has not been collected from surface casing within the last twelve months collect bradenhead 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.
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| Engineer | Form: (04)
403327476
02/23/2023 | This well may be returned to annual testing and monthly monitoring. If at any point in the future bradenhead conditions meet thresholds defined by Order 1-232 a new bradenhead mitigation sundry must be filed. |
| OGLA | Form: (06)
404097843
02/21/2025 | Due to proximity to a mapped wetland and surface water, 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)
404097843
02/21/2025 | COA's provided by the Operator as Best Management Practices under Technical Detail / Comments:
Notification: Notification will be given to any adjacent building unit occupants within a 1000 feet of the wellhead of planned P&A start date.
Wildlife: 3rd party wildlife surveys will be conducted on this well prior to rigging up for P&A activities. 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)
404097843
02/26/2025 | 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)
404097843
02/26/2025 | 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 (1320') : 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 plug at 1129' 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 879' 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)
404097843
02/26/2025 | 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. |