| Permit | Form: (02A)
400981717
02/18/2016 | Approval of this amended Form 2A does not provide relief from compliance with the COGCC Reclamation Rules. |
| OGLA | Form: (02A)
400981717
03/30/2016 | Approval of this Form 2A#400981717 and the Form 2#400955602 for the injection well (Mesa E25-SWD) does not authorize operator the right to inject. Authorization to inject into the selected Formation(s) requires approval of both the Form 31 and the Form 33.
Operator will use qualified containment devices for all appropriate chemicals/hazardous materials and injection equipment (pumps) used onsite during the operation of the injection well.
All tanks and aboveground vessels containing fluids for use during injection operations must have secondary containment structures. All secondary containment structures/areas must be lined. Operator must ensure a minimum of 110 percent secondary containment for the largest structure containing fluids within each bermed area at the facility during operations.
Operator shall equip and maintain on all produced water storage tanks used during injection operations electronic level monitoring devices that will shut in all of the wells on the pad to prevent a tank release.
Before hydraulic stimulation of the injection well, operator shall collect a groundwater sample(s) from the targeted injection formation(s) and analyzed in accordance with the parameters set forth in the injection well permit (Form 31 and Form 33) requirement(s); unless otherwise determined by COGCC engineering staff that a water sample of the proposed injection formation(s) is (are) not required; submit laboratory analytical results in electronic format to COGCC. |
| OGLA | Form: (02A)
400981717
03/30/2016 | Due to the highly fractured nature of the surface and shallow subsurface geologic materials (within the Uinta Formation), the nearby hillsides below the well pad shall be monitored for any day-lighting of drilling fluids throughout the drilling of the surface casing intervals for all wells.
Flowback and stimulation fluids must be sent to closed system (e.g. capable of containing under pressure any vapors, fumes, or gases) tanks, separators, or other containment/filtering equipment before the fluids can be placed into any pipeline, storage vessel, or other open top containment structures located on the well pad; or into tanker trucks for offsite disposal. No open top tanks can be used for initial flowback fluids containment. The flowback and stimulation fluid tanks, separators, or other containment/filtering equipment must be placed on the well pad in an area constructed to be sufficiently impervious to contain any spilled or released material. No additional downgradient berming of the fluid flowback containment equipment will be required if the operator constructs a sufficiently sized perimeter berm around the location. |
| OGLA | Form: (02A)
400981717
03/30/2016 | If E&P Waste is encountered during construction in a previously closed reserve pit, contact COGCC EPS staff, and take measures to verify that E&P Waste meets the applicable standards of Table 910-1 and that the pit is properly closed in accordance with Rules 905 and 1003 and the NOTICE TO OPERATORS (NTO) DRILLING WELLS WITHIN ¾ MILE OF THE RIM OF THE ROAN PLATEAU IN GARFIELD COUNTY - PIT DESIGN, CONSTRUCTION, AND MONITORING REQUIREMENTS, dated June 12, 2008.
Operator must ensure secondary containment for any volume of fluids contained at the well site during drilling and completion operations (as shown on the Construction Layout Drawings, Location Drawing, Proposed BMPs, and Facility Layout Drawing attachments). These may include, but are not limited to, construction of a berm or diversion dike, diversion/collection trenches within and/or outside of berms/dikes, site grading, or other comparable measures sufficiently protective of nearby surface water. The proposed BMPs may be changed based on actual site conditions. Any berm constructed at the well pad location will be stabilized, inspected at regular intervals as required by CDPHE (at least every 14 days and after precipitation events), and maintained in good condition. The design/build of any perimeter berm shall be sized, constructed, and compacted sufficiently to contain fluids during drilling operations, as well as all fluids contained in temporary frac tanks during completion operations.
The location is in an area of moderate to high run-on/run-off potential; therefore standard stormwater BMPs must be implemented prior to, during, and after access road and location construction, as well as during drilling, completion, and production operations at this location to insure compliance with CDPHE and COGCC requirements.
The access road will be constructed and maintained as to not allow sediment to migrate from the access road to nearby surface water or any drainages leading to surface water.
Strategically apply fugitive dust control measures, including encouraging established speed limits on private roads, to reduce fugitive dust and coating of vegetation and deposition in water sources. |
| OGLA | Form: (02A)
400981717
03/30/2016 | In addition to the notifications required by COGCC listed in the Northwest Notification Policy (Notice of Intent to Construct a New Location, Notice of Intent to Spud Surface Casing, and Notice of Intent to Commence Hydraulic Fracturing Operations) and Rule 316C. COGCC Form 42. FIELD OPERATIONS NOTICE (a. Notice of Intent to Conduct Hydraulic Fracturing Treatment and c. Notice of Construction or Major Change); operator shall notify the COGCC 48 hours prior to pipeline testing (flowlines from wellheads to separators to tanks; and/or any temporary surface lines used for hydraulic stimulation and/or flowback operations) using the Form 42 (as described in Rule 316C.m. Notice of Completion of Form 2/2A Permit Conditions). The appropriate COGCC individuals will automatically be email notified.
The operator shall submit, via a Form 4 Sundry Notice, and receive approval of, a reuse and recycling plan per Rule 907.a.(3), prior to any offsite reuse/recycling of cuttings. |