| Engineer | Form: (02)
401544729
12/17/2018 | 1) Operator shall comply with the most current revision of the Northwest Notification Policy.
2) Operator shall provide cement coverage from the production casing shoe (5 1/2" First String) to a minimum of 200' above the surface casing shoe to provide full isolation of the Coalmont Formation. Verify production casing cement coverage with a cement bond log.
3) Oil-based drilling fluid is to be used only after all fresh water aquifers are covered.
4) Operator acknowledges the proximity of the listed non-operated wells. Operator assures that this offset list will be remediated per the 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.
Peterson Ridge 1-20H (API 05-057-06515)
Grizzly 3-32H (API 05-057-06523)
5) The Operator shall monitor the bradenhead pressure of all wells under Operator’s control within 300 feet of the well which is to be treated, provided such other wells penetrate the productive zone which is to be treated. This offset monitoring will be required for any well stimulated on this pad.
If at any time during the Treatment or the 24-hour post-stimulation period, the bradenhead annulus pressure of the Treatment well or any of the monitored offset wells increases by more than 200 psig, the Operator of the well being treated shall notify the Director by Form 42, as soon as practicable, but no later than twenty-four (24) hours following such incident. Within fifteen (15) days after the occurrence, the Operator or Adjacent Operator(s), as the case may be, shall submit a Sundry Notice, Form 4, giving all details, including corrective actions taken.
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| OGLA | Form: (02)
401544729
12/17/2018 | Drilling/Completions: The following conditions of approval (COAs) will apply:
• A closed loop system must be implemented during drilling (as indicated on this Form 2 and previously submitted / approved Form 2A). All cuttings generated during drilling with oil based mud (OBM) must be segregated from water/bentonite based mud-(WBM-) generated drill cuttings and placed separately on the well pad. All OBM-generated drill cuttings must be kept in tanks/containers, or placed on a lined/bermed portion of the well pad; prior to disposition. The moisture content of any OBM-generated drill cuttings in a tank, cuttings containment area, or pile shall be as low as practicable to prevent accumulation of liquids greater than de minimis amounts. The operator has indicated that ‘Cuttings Disposal’ will be “Offsite” and that the ‘Cuttings Disposal Method’ will be “Commercial Disposal” (as shown in the ‘Drilling Waste Management Program’ sections of the Form 2A and this Form 2). Any liners associated with oil-based drilling mud and OBM-generated drill cuttings must be disposed of offsite per CDPHE rules and regulations. Any changes to drill cuttings management and disposal at this location will require submittal (via a Form 4 Sundry Notice) and approval of a Waste Management Plan detailing the changes (specifying cuttings characterization methods, cuttings management, amendment, and onsite disposal location[s]).
• The moisture content of water/bentonite-based drilling mud (WBM) drill cuttings, generated during drilling of the surface casing intervals and intermediate intervals, and managed onsite; shall be kept as low as practicable to prevent accumulation of liquids greater than de minimis amounts. The operator has indicated that ‘Cuttings Disposal’ will be “Offsite” and that the ‘Cuttings Disposal Method’ will be “Commercial Disposal” (as shown in the ‘Drilling Waste Management Program’ sections of the Form 2A and the Form 2). After drilling and completion operations have been completed, if any of the WBM-generated drill cuttings will remain on the well pad location (cuttings management area, the cut portion of the pad, cuttings trench, dry cuttings drilling pit, or utilized in onsite interim reclamation activities), they must be sampled and meet the applicable standards of Table 910-1. No liners (if used) are allowed to be disposed of with the drill cuttings. |
| Engineer | Form: (04)
401980753
08/15/2019 | 1. Flaring of natural gas shall comply with COGCC Rule 912.
2. The unnecessary or excessive venting or flaring of produced natural gas is prohibited.
3. Operator is to provide prior notification to the local emergency dispatch or the local governmental designee of any flaring or venting event.
4. An Operator Monthly Report of Operations, Form 7, requires the reporting of flared, vented or used on the lease gas volumes. The reported volume includes flowback and production gas.
5. The operator is required to obtain and maintain any required air permits from CDPHE.
6. Submit an updates when this approval expires (request to flare) to COGCC on Form 4s (Sundry Notices), including all information specified in COGCC’s "Notice to Operators, Rule 912 Venting or Flaring Produced Natural Gas - Statewide."
7. Within 30 days of commencement of flaring: collect a gas sample for laboratory analysis including hydrogen sulfide and submit a Form 43 to upload the laboratory results to the COGCC Environmental Database. Form 43 instructions are on COGCC’s website under Regulation => Forms => Form 43 COGCC Environmental Database.
8. This approval is good until February 15, 2020.
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| Engineer | Form: (04)
402293212
02/12/2020 | 1) Comply with all requirements of Rule 912, including monthly reporting of flared volumes (on Form 7) and notifications to local emergency dispatch or the local government designee.
2) Submit annual updates (requests to flare) to COGCC on Form 4s (Sundry Notices), including all information specified in COGCC’s "Notice to Operators, Rule 912 Venting or Flaring Produced Natural Gas - Statewide." Next sundry request due 1/23/2021.
3) Comply with any Colorado Department of Public Health and Environment, Air Pollution Control Division rules or requirements for all atmospheric discharges.
4) An enclosed flare shall be used, unless an open flare is specifically allowed by CDPHE’s Regulation 7.
5) With the next annual update (request to flare), collect a new gas sample for laboratory analysis including hydrogen sulfide and submit a Form 43 to upload the laboratory results to the COGCC Environmental Database. Form 43 instructions are on COGCC’s website
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| Engineer | Form: (04)
402522951
01/27/2021 | Following the anticipated acquisition of certain assets owned and operated by SandRidge Energy in Jackson County, Colorado, SandRidge acknowledges Gondola Resources plans to modify SandRidge’s pending Gas Capture Plan for the PRU 0880 2-29H17 well and the five additional wells at the Oxbow Pad. Gondola will install a JT Unit and two natural gas-powered CAT driven 550 KW generators at the Oxbow Pad and use natural gas from the wells to power the engines on the pad. This work is expected to commence in the Spring of 2021 and conclude in the Summer of 2021. In addition, Gondola will engage an established third party to utilize remaining field gas from the Oxbow Pad to power a mobile data center and energy intensive computing facilities located on the Oxbow Pad. Gondola anticipates this arrangement to be deployed and operational by year end. |
| Engineer | Form: (04)
402522951
01/29/2021 | 1) Flaring of natural gas shall comply with COGCC Rule 903.
2) Report metered volumes on Form 7, Operator’s Monthly Report of Operations for gas flared, sold or used on location.
3) The operator is required to obtain and maintain any required air permits from CDPHE.
4) The expectation for permanent flares controlling separators or residual gas will be an enclosed combustion device with a 98% design destruction efficiency for hydrocarbons. Operator shall manage this well so that production volumes do not exceed the combustor capacity.
5) Operator is to provide prior notification to the local emergency dispatch or the local governmental designee of any flaring or venting event.
Operator shall have an approved a Gas Capture Plan or have sought and received a variance from the COGCC Commission for continued production without gas infrastructure, prior to January 15, 2022 or wells must be shut in by January 15, 2022.
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