| Engineer | Form: (02 )
403240255
12/20/2022 | Operator acknowledges the proximity of the following non-operated 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.
Kodak 34-35 (API NO 123-23931)
HSR-Knox 4-3 (API NO 123-19090) |
| Engineer | Form: (02 )
403240255
12/20/2022 | Operator acknowledges the proximity of the listed wells: Operator agrees to: provide mitigation option 4 (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.
Rancho Water Valley 11 7-7-33-270-6-CH (API NO 123-36428)
Rancho Water Valley 6 (API NO 123-36433)
Rancho Water Valley 13 7-6-33-270-6-CH (API NO 123-36426)
Rancho Water Valley 12 (API NO 123-36430)
Kodak South FD 25-280HNX (API NO 123-40804) |
| Engineer | Form: (02 )
403240255
12/20/2022 | 1) Submit Form 42 electronically to COGCC 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 )
403240255
12/20/2022 | Per COGCC 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 COGCC engineer prior to stimulation.
2) If a delayed completion, a second test is required between 6-9 months, of if there is pressure above 200 psi, after rig release and 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. |
| Engineer | Form: (04 )
403847869
7/15/2024 | At the conclusion of the twelve months (06/30/2025), 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 )
403847869
7/15/2024 | Shut in Bradenhead pressure shall not exceed 50 psig.
|
| Engineer | Form: (04 )
403854128
7/15/2024 | At the conclusion of the twelve months (06/30/2025), 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 )
403854128
7/15/2024 | Shut in Bradenhead pressure shall not exceed 50 psig.
|