| Permit | Form: (02)
400521602
01/22/2014 | 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 Drilling Completion Report - Form 5 for every well on the pad shall identify which well was logged. |
| Engineer | Form: (02)
400521602
01/22/2014 | Operator acknowledges the proximity of the Becker 5-1 (API NO 123-12297), and the Becker 5-6 (API NO 123-13763). 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(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. |
| Engineer | Form: (02)
400521602
01/22/2014 | Operator acknowledges the proximity of the non-operated wells: The Marie D 4-4 (API NO 123-13111), the Marie D 4-12 (API NO 123-13182), the Marie D 4-5 (API NO 123-15121), the Marie D 4-13 (API NO 123-15142), the PTF C 32-16 (API NO 123-14880), the Pluss 32-43 (API NO 123-15974), and the Lindsay C33-13 (API NO 123-14712) 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, and submit 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. |
| Engineer | Form: (02)
400521602
01/22/2014 | 1) Submit Form 42 electronically to COGCC 48 hours prior to MIRU.
2) Comply with Rule 317.i and provide cement coverage from the bottom of the production casing to a minimum of 200' above Niobrara. Verify coverage with cement bond log.
3) Run and submit Directional Survey from TD to base of surface casing. The operator shall comply with Rule 321, and it shall be the operator’s responsibility to ensure that the wellbore complies with setback requirements in commission orders or rules prior to producing the well.
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| Engineer | Form: (04)
400651158
08/22/2014 | 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 , 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.
Becker 5-5 API 123-13838
Becker 5-16 API 123-18181 |
| Engineer | Form: (04)
400651158
08/22/2014 | 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, and submit 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.
Pluss 32-43 API 123-15974 |
| Engineer | Form: (04)
400651158
08/22/2014 | Operator acknowledges the proximity of the listed non-operated wells. Operator agrees to provide mitigation Option 4 (per the DJ Basin Horizontal Offset Policy), ensure all applicable documentation is submitted, and submit 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. Use of Option 4 is contingent upon completion of successful Bradenhead test and submission of form 17 that shows the well is in compliance with the COGCC "Policy for Special Bradenhead Testing Area in Weld County" dated 12/16/2009. Option 4 remediation will include pulling tubing, installing at least 2 RBPs, pressure test of casing, installing a 5K wellhead, and onsite monitoring of the Bradenhead during hydraulic stimulation of offset wells within a 1500' radius.
PTF C32-16 API 123-14880
McGuirk-Howell C 32-14 API 123-15882
Ruby Red D 8-2 API 123-16885 |
| Engineer | Form: (04)
400651158
08/22/2014 | Operator acknowledges the proximity of the listed wells. Operator agrees to provide mitigation Option 4 (per the DJ Basin Horizontal Offset Policy), ensure all applicable documentation is submitted , 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. Use of Option 4 is contingent upon completion of successful Bradenhead test and submission of form 17 that shows the well is in compliance with the COGCC "Policy for Special Bradenhead Testing Area in Weld County" dated 12/16/2009. Option 4 remediation will include pulling tubing, installing at least 2 RBPs, pressure test of casing, installing a 5K wellhead, and onsite monitoring of the Bradenhead during hydraulic stimulation of offset wells within a 1500' radius.
Becker 5-1 API 123-12297
Becker 5-2 API 123-13742
Becker 5-6 API 123-13763
Becker 5-10 API 123-16974
Becker 5-3 API 123-17299
Becker 5-11 API 123-17300
Becker 5-12 API 123-17301
Becker 5-13 API 123-17302
Becker 5-4 API 123-18179
Becker 5-15 API 123-18182
Becker 6 API 123-22594 |
| Engineer | Form: (04)
400651158
08/22/2014 | 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 the Sussex to 200’ above Sussex. 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. |
| OGLA | Form: (06)
404098075
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)
404098075
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)
404098075
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 (1560') : 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 1114' 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 432' 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)
404098075
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. |
| Engineer | Form: (06)
404098075
02/26/2025 | 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. |