| Engineer | Form: (02)
400749097
01/30/2015 | (1) Operator shall comply with the most current revision of the Northwest Notification Policy. See attached notice.
(2) Operator shall comply with the most current revision of the Garfield County Rulison Field Notice to Operators, with the following exception: All field notice requirements specified in that Notice to Operators are superseded by the requirements of the most current revision of the Northwest Colorado Notification Policy (see Condition of Approval #1). See attached notice.
(3) Operator shall provide cement coverage from the intermediate casing (9+5/8" first string) to a minimum of 200' above all Mesa Verde Group (and Ohio Creek Formation, if present) oil, gas, and water-bearing sandstone and coalbed formations. Verify intermediate casing coverage with a cement bond log.
(4) Monitor the bradenhead of offset wells RULISON DEEP #1 (API#045-06877) and the VASSAR/HEATH RMV 229-27 (API#045-07610) during completion operations. If at any time during the treatment or the 24-hour post-stimulation period the bradenhead annulus pressure of either offset well increases by more than 200 psig the Operator shall verbally notify the Director, as soon as practicable, but no later than twenty-four (24) hours following such incident. Within fifteen (15) days after the occurrence, the Operator shall submit a Sundry Notice, Form 4, giving all details, including corrective actions taken. |
| Engineer | Form: (02)
401217342
03/15/2017 | 1) Operator shall comply with the most current revision of the Northwest Notification Policy.
2) Operator shall comply with the most current revision of the Garfield County Rulison Field Notice to Operators, with the following exception: All field notice requirements specified in that Notice to Operators are superseded by the requirements of the most current revision of the Northwest Colorado Notification Policy (see Condition of Approval #1).
3) Operator shall provide cement coverage from the intermediate casing shoe (9+5/8" FIRST STRING) to a minimum of 200' above the Lower Wasatch (as defined by COGCC in the report "Casing and Cement Standards for Geologic Isolation Piceance Basin Bradenhead Monitoring Area and Nearby Fields," dated April 18, 2016, COGCC Document No. 2056199, Appendix A Field Scout Cards and Annotated Type Logs) to provide isolation of the Lower Wasatch, all Mesaverde Group formations including the Ohio Creek Formation, and underlying formations, if penetrated. Verify intermediate casing cement coverage with a cement bond log.
4) The operator's planned top of cement for the production casing (5 ½” Second String) at about 1000' above the intermediate casing shoe is acceptable. Verify production casing cement coverage with a cement bond log.
5) The Operator shall monitor all annulus and casing pressures of offset well RULISON DEEP #1 (API#045-06877). Monitoring shall occur from 24 hours prior to stimulation and shall continue until 24 hours after stimulation is complete. Recording shall be at a frequency of at least once per 24 hours with the capability of recording the maximum pressure observed during each 24 hour period. Operator shall notify COGCC Engineering staff if pressures increase by more than 200 psig. |
| Permit | Form: (02)
401217342
04/06/2017 | 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)
401217342
04/06/2017 | Operator shall comply with Notice to Operators: Interim Reclamation Procedures for Delayed Operations (dated January 5, 2017). |
| OGLA | Form: (02)
401217342
09/06/2017 | The moisture content of water/bentonite based mud (WBM) generated drill cuttings 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, 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 be sampled and meet the applicable standards of Table 910-1. No liners are allowed to be disposed of with the drill cuttings. After the drill cuttings have been amended (if necessary) and placed on the well pad, sampling frequency of the drill cuttings (to be determined by the operator) shall be representative of the material left on location. No offsite disposal of cuttings to another oil and gas location (TEP’s permitted Cuttings Trench locations or nearby locations) shall occur without prior approval of a Form 4 Sundry Notice specifying disposal location and waste characterization method. Commercial disposal of drill cuttings will also require notification to COGCC via a Form 4 Sundry Notice.
A closed loop system must be implemented during drilling. All cuttings generated during drilling with oil based mud (OBM) 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 cuttings containment area or pile shall be as low as practicable to prevent accumulation of liquids greater than de minimis amounts. At the time of closure, if the drill cuttings are to be left onsite, they must be sampled and also meet the applicable standards of Table 910-1. Representative cuttings samples will be analyzed for all Table 910-1 constituents. Any material which does not meet Table 910-1 criteria will either be manifested and disposed offsite at an approved commercial facility, or amended further onsite to comply with Table 910-1. If operator determines that long-term onsite management of oil based mud cuttings is necessary, an approved Form 27 remediation plan will be required. All liners associated with oil based drilling mud and cuttings must be disposed of offsite per CDPHE rules and regulations. |