| Engineer | Form: (02 )
401394953
7/6/2018 | Operator acknowledges the proximity of the 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”) stating that appropriate mitigation occurred and that it has been completed, prior to the hydraulic stimulation of this well.
Well Name API #
KALLSEN 32-9 2 (API 05-001-07980)
Operator acknowledges the proximity of the non-operated listed wells. Operator agrees to: provide mitigation option 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”) stating that appropriate mitigation occurred and that it has been completed, prior to the hydraulic stimulation of this well.
Well Name API #
HASKINS 1 (API 05-001-08831)
KALLSEN 24-9 1 (API 05-001-07732)
KALLSEN A-1 (API 05-001-09073)
Operator acknowledges the proximity of the listed non-operated wells. Operator assures that this offset list will be remediated per the DJ Basin Horizontal Offset Policy (option 3). Operator will submit a Form 42 (“OFFSET MITIGATION COMPLETED”) stating what appropriate mitigation occurred and that it has been completed, prior to the hydraulic stimulation of this well.
Well Name API #
HELEN M PENROD 1 (API 05-001-06867)
PENROD 4-3 (API 05-001-08766)
CIMARRON-PENROD 2 (API 05-001-08830)
UPRR 33 PAN AM NAV 1 (API 05-001-06229)
PENROD 4-15 1 (API 05-001-08266)
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 permitted well. This Form 42 shall be filed 48 hours prior to stimulation. Operator will assure that the offset well’s Bradenhead is open and continuously monitored during the entire stimulation treatment for all fracs on this pad for any evidence of fluid, a Bradenhead test will be performed prior to the beginning of stimulation.
TIPPERARY 1 (API 05-123-08116)
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| Engineer | Form: (02 )
401394953
7/6/2018 | Bradenhead tests shall be performed according to the following schedule and the Form
17 submitted within 10 days of each test:
1) Within 60 days of rig release and prior to stimulation and
2) If a delayed completion, 6 months after rig release and prior to stimulation.
3) Within 30 days after first production, as reported on Form 5A.
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| Engineer | Form: (02 )
401394953
7/6/2018 | 1) Submit Form 42 electronically 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) Comply with Rule 317.j. and provide cement coverage from TD to a minimum of 200' above Niobrara and from 200’ below Shannon to 200’ above Sussex. Verify coverage with cement bond log.
3) Oil-based drilling fluid is to be used only after all fresh water aquifers are covered.
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| Permit | Form: (02 )
401394953
7/10/2018 | If conductors are preset, Operator shall comply with Notice to Operators: Procedures for Preset Conductors (dated September 1, 2016, revised October 6, 2016). |
| Permit | Form: (02 )
401394953
7/10/2018 | Operator shall comply with Notice to Operators: Interim Reclamation Procedures for Delayed Operation (dated January 5, 2017). |
| Engineer | Form: (02 )
402512004
12/16/2020 | Operator acknowledges the proximity of the non-operated listed well. 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”) stating that appropriate mitigation occurred and that it has been completed, prior to the hydraulic stimulation of this well.
001-08116 TIPPERARY #1 |
| Engineer | Form: (02 )
402512004
12/16/2020 | Operator acknowledges the proximity of the listed non-operated wells. Operator assures that this offset list will be remediated per the DJ Basin Horizontal Offset Policy (option 3). Operator will submit a Form 42 (“OFFSET MITIGATION COMPLETED”) stating what appropriate mitigation occurred and that it has been completed, prior to the hydraulic stimulation of this well.
001-09199 HASKINS #4-12 |
| Engineer | Form: (02 )
402512004
12/16/2020 | In the Form 5A comments, operator will certify that this well complies with 408.u, has no treated interval within 150’ of another operator’s well for which a signed Stimulation Setback Consent was not obtained. |
| Engineer | Form: (02 )
402512004
12/18/2020 | 1) Submit Form 42 electronically 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) Comply with Rule 317.j. and provide cement coverage from TD to a minimum of 500' above Niobrara and from 500’ below Sussex to 500’ above Sussex. Verify coverage with cement bond log.
3) Oil-based drilling fluid is to be used only after all fresh water aquifers are covered. |
| Permit | Form: (02 )
402512004
1/8/2021 | Operator shall comply with Notice to Operators: Interim Reclamation Procedures for Delayed Operation (dated January 5, 2017). |
| Permit | Form: (02 )
402512004
1/8/2021 | If conductors are preset, Operator shall comply with Notice to Operators: Procedures for Preset Conductors (dated September 1, 2016, revised October 6, 2016). |
| Engineer | Form: (02 )
403280185
1/17/2023 | 1) Submit Form 42 electronically to COGCC 2 business days prior to MIRU (spud notice) for the first well activity with a rig on the pad and provide 2 business day spud notice via Form 42 for all subsequent wells drilled on the pad.
2) Comply with Rule 408.j. and provide cement coverage from TD to a minimum of 500' above Niobrara. Verify coverage with a cement bond log.
2) Comply with Rule 408.j. and provide cement coverage from TD to a minimum of 500' above Niobrara and from 500’ below Sussex to 500’ above Sussex. Verify coverage with a cement bond log. |
| Engineer | Form: (02 )
403280185
1/17/2023 | Operator acknowledges the proximity of the listed wells. Operator agrees to: provide mitigation option 1 or 2 (per the Offset Well Evaluation and Hydraulic Fracturing Operator Guidance Document) 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”) stating that appropriate mitigation occurred and that it has been completed, prior to the hydraulic stimulation of this well.
123-12567 Jordan #34-3
001-09558 AMOCO STATE #41-16 |
| Engineer | Form: (02 )
403280185
1/17/2023 | Operator acknowledges the proximity of the listed non-operated wells. Operator assures that this offset list will be remediated per the Offset Well Evaluation and Hydraulic Fracturing Operator Guidance Document Operator using Option 3. Operator will submit a Form 42 (“OFFSET MITIGATION COMPLETED”) stating what appropriate mitigation occurred and that it has been completed, prior to the hydraulic stimulation of this well.
001-06302 KALLSEN #14-10
001-08179 RMPCO-UPRR-PENROD #1
001-09199 HASKINS #4-12
123-12937 JORDAN #34-9
123-19677 HSR-CHERRY KNOLLS #9-33 |
| Engineer | Form: (02 )
403280185
1/17/2023 | 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 is observed or if there is continuous flow, Operator must contact COGCC engineering for approval prior to stimulation.
2) If a delayed completion, a second test is required between 6-9 months after rig release and must be conducted prior to stimulation. If any pressure greater than 200 psi is observed or if there is continuous flow, Operator must contact COGCC engineering for approval 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 )
403280185
2/13/2023 | Operator will log two (2) wells during the first rig occupation with open-hole resistivity log with gamma-ray log from the kick-off point into the surface casing for the two stratigraphically deepest wells on each side of the pad
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| Permit | Form: (02 )
403280185
2/13/2023 | If conductors are preset, operator shall comply with Notice to Operators: Procedures for Preset Conductors (dated September 1, 2016).
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| Permit | Form: (02 )
403280185
2/13/2023 | Operator shall comply with Notice to Operators: Interim Reclamation Procedures for Delayed Operations (dated January 5, 2017).
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