| Engineer | Form: (02)
400958361
01/08/2016 | 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. Changed First String cement top from a null value to 2300' (200' above proposed surface casing shoe depth of 2500').
3) Offset Well Mitigation: Offset well Hebron #7-17H (057-06472) requires mitigation, as shown in the comments on this form. On 1/11/2016, the operator agreed to run a new cement bond log (CBL) in the Hebron #7-17H well to verify existing cement coverage in the previously unlogged interval from 4790' to 1232' (provide additional overlap for correlation with existing CBL). The operator shall submit the CBL for COGCC engineering review prior to stimulating Mutual 0780 3-8H.
3.a.) If the new CBL shows adequate Coalmont Formation cement coverage from the Pierre Shale top to the surface casing shoe, then additional mitigation is not required prior to stimulation of this proposed well Mutual 0780 3-8H.
3.b.) If Coalmont Formation isolation is not adequate on the new CBL, then the operator shall monitor the production casing and bradenhead pressure of the Hebron #7-17H well throughout the stimulation of Mutual 0780 3-8H. The operator shall open the bradenhead of the Hebron #7-17H well and plumb to a tank (potential for communication in the Niobrara between completions downhole). If the pressure increases and the surface casing cannot hold or if there is a leak in the casing then the pressure will go to the tank and not the formation. COGCC Monitoring Requirements: The operator shall monitor the production casing pressure and the bradenhead pressure of offset well Hebron #7-17H. The operator shall install pressure gauges on the Hebron #7-17H well at least 24 hours prior to the operator initiating a treatment on the proposed well Mutual 0780 3-8H. The operator shall monitor the gauges at least once during every 24-hour period until 24 hours after the treatment is completed and shall continue to do so until the pressure stabilizes with allowance for a ten percent daily fluctuation. The pressure gauges shall be capable of monitoring current pressure and also capable of recording the maximum pressure encountered in a 24 hour period. Such gauges shall be reset between each 24 hour period. The pressures shall be recorded and saved for a period of one year. Alternate electronic measurement may be used to record the prescribed pressures. |
| Engineer | Form: (04)
401098285
09/20/2016 | 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.
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| OGLA | Form: (04)
401010488
05/23/2017 | COA 11 - A closed loop system must be implemented during drilling (as indicated on the Form 2 and 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 SECTION’ of the Form 2A). All 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]).
COA 12 - The moisture content of water/bentonite-based mud (WBM) generated cuttings during drilling of the surface casing intervals, that will be managed onsite, shall be kept as low as practicable to prevent accumulation of liquids greater than de minimis amounts. After drilling and completion operations have been completed, any of the WBM drill cuttings that will remain on the well pad location (cuttings management area, the cut portion of the pad, cuttings trench, dry cuttings drilling pit), must meet the applicable standards of Table 910-1. No offsite disposal of cuttings to another oil and gas location shall occur without prior approval of a Waste Management Plan (submitted via a Form 4 Sundry Notice) specifying disposal location and waste characterization method. Operator has indicated that commercial disposal of cuttings will be the method of disposal for all drill cuttings. |
| Engineer | Form: (04)
401423698
10/18/2017 | 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 next years annual update (request to flare), collect a new gas sample including hydrogen sulfide and submit an Electronic Data Deliverable (EDD), prepared by the laboratory that performed the gas analysis. The EDD shall be submitted with the annual update, in the format specified on COGCC’s website, located in Help => Environmental => COGCC EDD Information.
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| Engineer | Form: (04)
401833556
03/06/2019 | 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)
402292413
02/11/2020 | 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 1/22/2021.
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)
402522770
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 Mutual 0780 3-08H well. Gondola will install one natural gas driven Arrow 90-T Genset. This work is expected to commence in the Spring of 2021 and conclude in the Summer of 2021. |
| Engineer | Form: (04)
402522770
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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| UIC | Form: (04)
402780196
10/26/2021 | Injectivity test is approved as outlined, and Operator may not inject more than 200bbl.
Operator may not exceed the frac gradient of the tested formation during the test.
Operator will report the results of the injectivity test on a Form 4 Sundry within 30 days of the end of the test. |
| Engineer | Form: (04)
403008136
01/27/2023 | Perform a Bradenhead test in June 2023 and submit a Form 17 in 10 days after the test date. Submit a Form 4 sundry with a summary of the results to date of all blowdowns and sample results to fully characterize the state of the Bradenhead of this well. If the surface casing pressure remains 0 and there is no flow then continue with monthly monitoring and annual testing. |
| Engineer | Form: (04)
403008136
01/27/2023 | Action required by the approval of this sundry will be the responsibility of successor operator. |
| Engineer | Form: (02)
403201848
06/07/2023 | 1) Submit electronic Form 42 Notice of MIRU 2 business days ahead of conversion operations.
2) Prior to starting work a bradenhead test shall be performed. If the beginning pressure is greater than 25 psi, or if pressure remains at the conclusion of the test, or if any liquids were present contact COGCC Engineer for sampling requirements. The Form 17 shall be submitted within 10 days of the test.
3) Submit monthly bradenhead monitoring data every month for the 12 months following the start of injection.
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| UIC | Form: (02)
403201848
07/05/2023 | Injection is not authorized until approval of Subsequent Forms 31 and 33. |
| Engineer | Form: (04)
403455716
07/12/2023 | The attached data indicates that the bradenhead continues to flow liquid each time the surface casing is checked, Continue with monthly blowdowns and submit results in 6 months, 1/6/24. Include casing starting and ending pressure, a graph of the build-up and blowdown, volume and be prepared to take samples if required. |
| Engineer | Form: (04)
403455716
07/12/2023 | Wells that flow liquids during the bradenhead test are not eligible for the test data bulk upload. A Form 17 is required 10 days after the test and shall be filed by 7/21/2023. |
| Engineer | Form: (04)
403645006
01/17/2024 | Approval of this sundry extends the due date for the 1/2024 bradenhead test and subsequent Form 17 submittal to 4/30/2024. Please summarize the test results and include action items in the operator comments box on the sundry. Attachments should support the summary submitted in the comments. |
| Engineer | Form: (04)
403879409
02/03/2025 | 1) Monitor monthly and record the wellhead pressure, blowdown volumes and fluid type produced.
2) Following a 7 day shut in period, perform a Bradenhead test by 4/15/2025 and submit a Form 17 in 10 days of the test.
3) Submit a Form 4 Sundry with pressure data and sample analysis interpretation for the previous 12 months, by 4/25/25. Include a proposed plan for the continuing mitigation on this well. Be prepared to implement mitigation plans as soon as weather permits.
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| Engineer | Form: (04)
404086434
02/18/2025 | 1) Monitor monthly and record the wellhead pressure, blowdown volumes and fluid type produced.
2) Following a 7 day shut in period, perform a Bradenhead test by 4/15/2025 and submit a Form 17 in 10 days of the test.
3) Submit a Form 4 Sundry with pressure data and sample analysis interpretation for the previous 12 months, by 4/25/25. Include a proposed plan for the continuing mitigation on this well. Be prepared to implement mitigation plans as soon as weather
permits. |