| Permit | Form: (02)
400420669
08/05/2013 | Operator must meet water well testing requirements per Rule 318A. |
| Engineer | Form: (02)
400420669
09/11/2013 | 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.
Dinner #13-33 API #05-123-22370
Palser E. #14-23 API #05-123-22616
Schwisow E. #14-16 API #05-123-16126
Schwisow E. #14-09 API #05-123-16125
Dinner #14-32 API #05-123-21943
Dinner #14-31 API #05-123-21944
Dinner #1 API #05-123-10788
Dinner #15-43 API #05-123-20032
Mel Bickling #31-22 API #05-123-11059
Bickling E. #22-8 API #05-123-18788
Dinner #23-2 API #05-123-17767
Feit E. #23-5 API #05-123-17728
Feit E. #23-3 API #05-123-17727
Feit #2-23 EG API #05-123-12056
Ryan #1-26 EG API #05-123-07431 |
| Engineer | Form: (02)
400420669
09/11/2013 | 1) Submit Form 42 electronically to COGCC 48 hours prior to MIRU.
2) Comply with Rule 317.i and provide cement coverage from end of 7” casing to a minimum of 200' above Niobrara and from 200’ below and 200’ above Parkman. 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. |
| Permit | Form: (02)
400420669
01/14/2014 | Operator shall comply with Buffer Zone Move-In, Rig-Up Notice Policy dated 12-16-2013. |
| Permit | Form: (02)
400420669
01/14/2014 | Open hole resistivity and gamma logs shall be run to describe the stratigraphy of the entire well bore and to adequately verify the setting depth of surface casing and aquifer coverage. On a multi-well pad, these open hole logs are only required on one of the first wells drilled on the pad and the Form 5 for every well on the pad shall identify which well was logged. |
| Engineer | Form: (02)
400420669
01/21/2014 | 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.
JR #1 API #05-123-12840
Benson #24-15 API #05-123-14705
Benson #13-15 API #05-123-12942
Willson #1-15 API #05-123-13327
Riggs #44-16 API #05-123-14480
Ole #21-24 API #05-123-23634
Ole #4-24 API #05-123-13239 |
| Engineer | Form: (02)
400420669
01/21/2014 | Operator acknowledges the proximity of the listed non producing wells. Operator agrees to provide mitigation Option 3 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.
Bickling #1 API #05-123-13024
Dinner #15-1 API #05-123-10987
Dinner #15-2 API #05-123-11166
Mel Bickling #11-22 API #05-123-10719 |
| Engineer | Form: (04)
402878441
12/02/2021 | This approval is good for one year and a new application must be made before November 30, 2022. Updates for the planned utilization of the well should be included with the application.
|
| Engineer | Form: (04)
402878441
12/02/2021 | The Form 7 reporting must reflect the well status dates reported on the Form 4-TA request. |
| Engineer | Form: (04)
403148215
08/30/2022 | 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. During the first day of mitigation 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. This mitigation plan may be used for six consecutive months.
4. 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)
403148215
08/30/2022 | Shut in Bradenhead pressure shall not exceed 50 psig.
|
| Engineer | Form: (06)
403275938
01/03/2023 | 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. |
| Engineer | Form: (06)
403275938
01/03/2023 | 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)
403275938
01/03/2023 | 1) Provide 2 business day notice of plugging MIRU via electronic Form 42, and provide 48 hours Notice of Plugging Operations, prior to mobilizing for plugging operations via electronic Form 42. These are 2 separate notifications, required by Rules 405.e and 405.I.
2) After placing plug at 2420’ 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 855’ plug: verify that all fluid migration (liquid and gas) 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 cement is not circulated to surface, shut-in, WOC 4 hours then tag plug – must be at 540’ or shallower and provide 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)
403275938
01/03/2023 | FLOWLINE AND SITE CLOSURE
1)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.
2)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. |
| OGLA | Form: (06)
403275938
01/11/2023 | 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)
403275938
01/11/2023 | 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)
403275938
01/11/2023 | 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. |