| Engineer | Form: (02)
401900466
05/31/2019 | 1) Submit Form 42 online to COGCC 48 hours prior to MIRU (spud notice) for the first well activity with a rig on the pad and provide 48 hour spud notice via Form 42 for all subsequent wells drilled on the pad.
2) Provide cement coverage to a minimum of 200' above Niobrara. Verify coverage with cement bond log.
3) Oil-based drilling fluid is to be used only after setting surface casing.
Bradenhead
Bradenhead tests shall be performed and reported according to the following schedule and Form 17 submitted within 10 days of each test.:
1) All: Within 60 days of rig release, prior to stimulation. If any pressure greater than 200 psi, must contact COGCC engineer prior to stimulation.
2) Delayed completion: 6 months after rig release, prior to stimulation. If any pressure greater than 200 psi, must contact COGCC engineer prior to stimulation.
3) A post-production test within 60 days after first sales, as reported on the Form 10, Certificate of Clearance.
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| Permit | Form: (02)
401900466
07/16/2019 | Operator will ensure the wellbore beyond the unit boundary setback is physically isolated and is not completed. In the Operator Comments on the Form 5A the operator will (1) report the footages from the section lines of the bottom of the completed interval (2) describe how the wellbore beyond the unit boundary setback is physically isolated and (3) certify that none of the wellbore beyond the setback was completed. |
| Engineer | Form: (02)
404023357
12/19/2024 | Operator acknowledges the proximity of the listed 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 based on the selected mitigation option chosen, and submit a Form 42 (“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.
Jake #2-01H (API NO 123-30574)
Lamotta #5-01M (API NO 123-30556) |
| Engineer | Form: (02)
404023357
12/19/2024 | Operator acknowledges the proximity of the listed wells. Operator assures that this offset list will be remediated per the DJ Basin Horizontal Offset Policy (option 4). Operator will submit a Form 42 (“OTHER – AS SPECIFIED BY PERMIT CONDITION”) stating that appropriate mitigation will be completed, during the hydraulic stimulation of this well. This Form 42 shall be filed 48 hours prior to stimulation. Operator will assure that the well’s Bradenhead is open and monitored during the entire stimulation treatment – a person will monitor for any evidence of fluid, a Bradenhead test will be performed prior to the beginning of stimulation.
Critter Creek #6-12H (API NO 123-31493)
Longhorn B #3-36H (API NO 123-30586)
Longhorn G #4-36H (API NO 123-31573)
Longhorn B #5-36H (API NO 123-31532)
Fox Creek 12-63 #25-2-1 (API NO 123-50374)
Fox Creek 12-63 #25-2-2 (API NO 123-50369)
Fox Creek 12-63 #25-23-4 (API NO 123-50373)
Fox Creek 12-63 #25-24-5 (API NO 123-50371)
Fox Creek 12-63 #25-24-6 (API NO 123-50368)
Fox Creek #505-2501H (API NO 123-41613)
Fox Creek #504-2524H (API NO 123-41612) |
| Engineer | Form: (02)
404023357
12/19/2024 | 1) Submit Form 42 electronically to ECMC 2 business days prior to MIRU (Spud Notice), for the first well/activity on the pad and provide 2 business days spud notice for all subsequent wells drilled on the pad.
2) Comply with Rule 408.j and provide cement coverage from the end of production casing to a minimum of 500' above Niobrara. Verify coverage with cement bond log.
3) Oil-based drilling fluid is to be used only after all aquifers are covered. |
| Engineer | Form: (02)
404023357
12/19/2024 | Per Order 1-232, Bradenhead tests shall be performed according to the following schedule and Form 17 submitted within 10 days of each test:
1) Within 60 days of rig release, prior to stimulation. If any pressure greater than 200 psi, must contact ECMC engineer prior to stimulation.
2) If a delayed completion, 6 months after rig release and prior to stimulation. If any pressure greater than 200 psi, must contact ECMC engineer prior to stimulation.
3) A post-production test within 60 days after first sales, as reported on the Form 10, Certificate of Clearance. |
| Permit | Form: (02)
404023357
02/05/2025 | Operator will log two (2) additional well(s) with open-hole resistivity log with gamma-ray log from the kick-off point into the surface casing for the stratigraphically deepest wells of the pad for a total of three (3) wells logged during the second rig occupation of this location |
| Permit | Form: (02)
404023357
02/05/2025 | The nearest well in the same formation is less than the order minimum of 150’ set by order 421-121. Operator will plug and abandoned the Longhorn B 3-36H (123-30586) well before this well can be completed within 150’ of Longhorn B 3-36H well |
| Permit | Form: (02)
404023357
02/05/2025 | Operator will ensure the wellbore beyond the unit boundary setback is physically isolated and is not completed. In the Operator Comments on the Form 5A the operator will (1) report the footages from the section lines of the bottom of the completed interval (2) describe how the wellbore beyond the unit boundary setback is physically isolated and (3) certify that none of the wellbore beyond the setback was completed. |
| Permit | Form: (02)
404023357
02/05/2025 | In the event delayed operations are to occur, Operator shall comply with Notice to Operators: Interim Reclamation Procedures for Delayed Operations (dated January 5, 2017) |