| Agency | Form: (02)
400043743
04/29/2010 | <style type="text/css">
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<p><span class="Normal">1) COMPLIANCE WITH THE MOST CURRENT REVISION OF THE NORTHWEST COLORADO NOTIFICATION POLICY IS </span><span class="Normal">REQUIRED.</span></p>
<br /><p><span class="Normal">2) RESERVE PIT MUST BE LINED.</span></p>
<br /><p><span class="Normal">3) CEMENT TOP VERIFICATION BY CBL REQUIRED. </span></p>
<br /><p><span class="Normal">4) OPERATOR MUST ENSURE 110 PERCENT SECONDARY CONTAINMENT FOR ANY VOLUME OF FLUIDS CONTAINED AT </span><span class="Normal">WELL SITE DURING DRILLING AND COMPLETION OPERATIONS. IF FLUIDS ARE CONVEYED VIA PIPELINE, OPERATOR </span><span class="Normal">MUST IMPLEMENT BEST MANAGEMENT PRACTICES TO CONTAIN ANY UNINTENTIONAL RELEASE OF FLUIDS.</span></p>
<br /><p><span class="Normal">5) THE MOISTURE CONTENT OF ANY DRILL CUTTINGS IN A CUTTINGS PIT, TRENCH, OR PILE SHALL BE AS LOW AS </span><span class="Normal">PRACTICABLE TO PREVENT ACCUMULATION OF LIQUIDS GREATER THAN DE MINIMIS AMOUNTS. AT THE TIME OF </span><span class="Normal">CLOSURE, THE DRILL CUTTINGS MUST ALSO MEET THE APPLICABLE STANDARDS OF TABLE 910-1.</span></p>
<br /><p><span class="Normal">6) NO PORTION OF ANY PIT THAT WILL BE USED TO HOLD LIQUIDS SHALL BE CONSTRUCTED ON FILL MATERIAL, </span><span class="Normal">UNLESS THE PIT AND FILL SLOPE ARE DESIGNED AND CERTIFIED BY A PROFESSIONAL ENGINEER, SUBJECT TO </span><span class="Normal">REVIEW AND APPROVAL BY THE DIRECTOR PRIOR TO CONSTRUCTION OF THE PIT. THE CONSTRUCTION AND LINING </span><span class="Normal">OF THE PIT SHALL BE SUPERVISED BY A PROFESSIONAL ENGINEER OR THEIR AGENT. THE ENTIRE BASE OF THE PIT </span><span class="Normal">MUST BE IN CUT.</span></p>
<br /><p><span class="Normal">7) THE PROPOSED SURFACE CASING IS MORE THAN 50' BELOW THE DEPTH OF THE DEEPEST WATER WELL WITHIN </span><span class="Normal">1MILE OF THE SURFACE LOCATION WHEN CORRECTED FOR ELEVATION DIFFERENCES. THE DEEPEST WATER WELL </span><span class="Normal">WITHIN 1 MILE IS 000 FEET DEEP. </span></p>
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| OGLA | Form: (04)
403096170
07/19/2022 | Operator will implement measures to capture, combust, or control emissions to protect health and safety, and to ensure that vapors and odors from well completion(s), well repair/maintenance, well perforating, temporary abandonment activities, additional equipment installation, and/or testing operations with a workover rig, wireline rig, or other heavy equipment do not constitute a nuisance or hazard to public health, welfare and the environment. |
| Engineer | Form: (04)
403096170
07/21/2022 | 1) Report work completed with a Form 4 Sundry REPORT OF WORK DONE - Repair Well noting final pressure test results and include any operational or job summaries. If the wellbore geometry changes submit an updated WBD.
2) If wellbore geometry changes or cement work is executed, submit information on a Form 5
3) Complete a bradenhead test following completion of the repair (This test will satisfy the annual BH testing requirements) |
| Engineer | Form: (04)
403881893
10/03/2024 | 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. Well to plugged or repaired no later than 12/11/2024. Pressure is to be managed and mitigated until plugging or repair is complete. Summary of well monitoring and mitigation will be submitted on a Form 4 Sundry within 30 days of the well being cut and capped or repaired. The sundry should include monthly pressure monitoring data, flow rate information, sample analysis interpretation, and bradenhead test description.
3. Shut in bradenhead pressure shall not exceed threshold pressure.
4. If a sample has not been collected within the last twelve months collect liquid, 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.
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| Engineer | Form: (04)
404424483
11/10/2025 | 1) For applicable operations, report work completed within 30 days on a Form 4 Sundry REPORT OF WORK DONE - Repair Well noting final pressure test results and include any operational or job summaries. If the wellbore geometry changes or there is not an updated WBD in the well file submit an updated WBD.
2) For applicable operations, submit a Form 5 or 5A (updated packer and tubing depths) within 30 days of the work with job related documents including a minimum of one of the following attachments: operations summary, cement job summary and/or wireline summary. Additionally, include CBL’s and any additional logs run.
3) Complete a bradenhead test within 30 days of completing the repair and submit results on a Form 17
4) Provide electronic Form 42 Notice of MIRU 2 business days ahead of operations
5) Operator shall notify ECMC Engineering staff of changes and/or additional repair methods to the approved repair procedure.
6) Operator will successfully pressure test the production casing for a minimum of 15 minutes and to a minimum of 300 psi. Pressure test to be submitted on Form 21 within 30 days of the pressure test. |
| Engineer | Form: (04)
404424483
11/10/2025 | The mechanical integrity test will be performed after isolating the wellbore with a bridge plug or similar approved isolating device set 100 feet or less above the highest open perforation. |
| OGLA | Form: (04)
404424483
12/17/2025 | Mule Deer and E k BMPs
1. Wildlife - Minimization: To minimize the potential for wildlife related traffic accidents, TEP will implement speed restrictions for all lease roads and require that all TEP employees and contractors adhere to these posted speed restrictions.
2. Wildlife - Minimization: The operator and its contractors agree to restrict well site visitations to portions of the day between 9:00 a.m. and 3:00 p.m. during the winter season (December 1 through April 30) within CPW-mapped mule deer and elk winter concentration areas and severe winter ranges.
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| OGLA | Form: (04)
404424483
12/17/2025 | Aquatic Species BMPs
1. Wildlife Minimization - Maintain adequate spill response equipment at or near the Oil and Gas Location during subsequent operations.
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| Engineer | Form: (06)
404506208
01/16/2026 | If unable to fish tubing, stop and contact ECMC engineer for an update to the plugging procedure. |
| Engineer | Form: (06)
404506208
01/16/2026 | If production casing pressure test does not pass, contact ECMC for verification of plugging orders prior to continuing plugging operations.
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| Engineer | Form: (06)
404506208
01/16/2026 | 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 details with the Form 27.
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| Engineer | Form: (06)
404506208
01/16/2026 | 1) Provide electronic Form 42 Notice of Plugging Operations 48 hours prior to mobilizing for plugging operations.
2) After placing plug at 6911’ 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 cement above the surface casing ( 3120’): 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) 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 3070’ 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.
7) After surface plug and prior to cap, verify isolation by either a 15 minute bubble test or 15 minute optical gas imaging. 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.
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| OGLA | Form: (06)
404506208
01/20/2026 | Location is within CPW mapped areas for the following High Priority Habitats: Mule Deer Migration Corridor, Mule Deer Severe Winter Range, Mule Deer Winter Concentration Area. Although plugging and abandonment operations with heavy equipment will be allowed, the Operator is strongly encouraged to avoid them from December 1 through April 30.
Operator completed CPW consultation [Doc # 404508526]. The following Conditions of Approval were agreed to during the consultation:
1. Wildlife – Minimization: To minimize the potential for wildlife related traffic accidents, TEP will implement speed restrictions for all lease roads and require that all TEP employees and contractors adhere to these posted speed restrictions.
2. Wildlife - Minimization: The operator and its contractors agree to restrict well site visitations to portions of the day between 9:00 a.m. and 3:00 p.m. during the winter season (December 1 through April 30) within CPW-mapped mule deer and elk winter concentration areas and severe winter ranges. |
| OGLA | Form: (06)
404506208
01/20/2026 | This oil and gas location is located within a CPW mapped 500 foot buffer of the Ordinary High Water Mark of an unnamed stream within Ryan Gulch for protection of Aquatic Native Species Conservation Water High Priority Habitat. At a minimum, Operator will use secondary containment for all tanks and other liquid containers and will review the stormwater program and implement stormwater BMPs and erosion control measures as needed to prevent fine-grained sediment and impacted stormwater runoff from entering surface water.
Operator completed CPW consultation [Doc # 404508526]. The following Conditions of Approval were agreed to during the consultation:
1. Wildlife Minimization - Maintain adequate spill response equipment at or near the Oil and Gas Location during subsequent operations.
2. Wildlife Minimization - Stormwater control measures will be in place during all phases of development (construction, drilling, completions, interim reclamation, and production) to control stormwater runoff in a manner that minimizes erosion, transportation of sediment offsite, and site degradation and to minimize potential downstream impacts on aquatic sportfish. |
| Engineer | Form: (06)
404506208
01/29/2026 | 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.
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