| Engineer | Form: (02)
400621812
06/19/2014 | (1) COMPLIANCE WITH THE MOST CURRENT REVISION OF THE NORTHWEST COLORADO NOTIFICATION POLICY IS REQUIRED. SEE ATTACHED NOTICE.
(2) COGCC CONCURS WITH OPERATORS PROPOSED FIRST STRING CEMENT TOP AT THE GROUND SURFACE. AT A MINIMUM, FIRST STRING (5-1/2" CASING) CEMENT SHALL EXTEND FROM THE FIRST STRING CASING SHOE TO AT LEAST 200’ ABOVE THE SURFACE CASING SHOE TO PROVIDE FULL ISOLATION OF THE COALMONT FORMATION. FIRST STRING CEMENT COVERAGE VERIFICATION BY CBL IS REQUIRED. |
| Permit | Form: (02)
400621812
07/07/2014 | Open hole resistivity and gamma logs shall be run to describe the stratigraphy of the entire well bore and to adequately verify the setting depth of surface casing and aquifer coverage. On a multi-well pad, these open hole logs are only required on one of the first wells drilled on the pad and the Drilling Completion Report - Form 5 for every well on the pad shall identify which well was logged.
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| Engineer | Form: (02)
401013202
06/08/2016 | 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. |
| Environmental | Form: (04)
401095688
08/19/2016 | Refer Document 401062567 (Waste Management Plan). |
| Engineer | Form: (02)
401100976
10/20/2016 | 1) Operator shall comply with the most current revision of the Northwest Notification Policy.
2) Plug back cement of this pilot hole shall be provided as shown on the attached wellbore diagram and drilling plan. |
| Engineer | Form: (04)
401177448
01/17/2017 | 1) Operator shall comply with the most current revision of the Northwest Notification Policy.
2) Plug back cement of this pilot hole shall be provided as shown on the attached wellbore diagram and drilling plan. |
| OGLA | Form: (02)
401854296
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: (02)
401854296
12/31/2018 | 1) Operator shall comply with the most current revision of the Northwest Notification Policy.
2) Oil-based drilling fluid is to be used only after all fresh water aquifers are covered.
3) 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.
4) 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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| Permit | Form: (02)
401854296
12/31/2018 | 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)
401854296
12/31/2018 | Operator shall comply with Notice to Operators: Interim Reclamation Procedures for Delayed Operation (dated January 5, 2017). |
| Permit | Form: (02)
401854296
12/31/2018 | Operator shall post a copy of the approved form 2 and a copy of the approved amended form 2A Oil & Gas Location Assessment on location during all construction, drilling, and completions operations. |
| Engineer | Form: (04)
401946455
03/07/2019 | 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."
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 under Regulation => Forms => Form 43 COGCC Environmental Database.
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| Engineer | Form: (04)
402293243
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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| UIC | Form: (04)
402310059
12/23/2020 | Operator required to repeat this analysis in 5 years from the sample date here = 5/30/2019. Unless there is a significant change in the water being injected, such as addition of new producing formations in the source water, the next sample is due 5/30/2024. If there is a significant change in the water to be injected then a new sample will be required. See the new 800 Series Rules that become effective 1/15/2021. The 2024 sample will be required to be submitted by EDD; Electronic Data Deliverable. |
| Engineer | Form: (04)
402522778
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 Ray Ranch 0780 1-16H well and one additional well at the Ray Ranch Pad. Gondola will install a CAT driven 250 KW generator at the Ray Ranch 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. Remaining gas volumes will be routed to the Pintail SWD Pad. Gondola anticipates this arrangement to be deployed and operational by Summer 2021. |
| Engineer | Form: (04)
402522778
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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| Engineer | Form: (04)
403006723
12/09/2022 | The 2021 test was performed on 2/7/2022. A followup test was performed on 5/11/2022 for which the initial pressure was 0 psi and no fluid produced. Monitor bradenhead pressure monthly; test and report annually per Rule 419. |