| Agency | Form: (02A)
400036073
04/12/2010 | Comply with all DOE office of legacy management requests for sampling and analysis of natural gas and other materials associated with drilling and production. Operator must ensure 110 percent secondary containment for any volume of fluids contained at well site during drilling and completion operations. If fluids are conveyed via pipeline, operator must implement best management practices to contain any unintentional release of fluids. Flowback to tanks only. Submit a secondary and tertiary containment plan via sundry notice form 4 for the tanks. Attn: Chris Canfield. Obtain approval of the plan prior to flowback. Produced water from this location may not be transported to or re-used at another location without specific written approval from COGCC and only after analysis confirms compliance with the Rulison SAP. Drill solids and cuttings from this location may not be transported to, disposed of or re-used at another location without specific written approval from COGCC and only after analysis confirms compliance with the Rulison SAP. A closed loop mud system shall be utilized to ensure containment of all materials that have been in contact with downhole strata and fluids. All cuttings and fresh make up water storage pits shall be lined to ensure containment. Contour features, french drains and other stormwater BMPs as necessary shall be employed to ensure site integrity. No individual operator shall utilize more than one rig within one mile of the project rulison blast site at any given time and no individual operator shall utilize more than two rigs within a three mile radius of the site at any given time. The total number of rigs allowed by all operators within three miles of the site shall be limited to five at any given time. Operator shall comply with all provisions of the most recent COGCC approved revision of the rulison sampling and analysis plan. In addition to the produced water sampling and analysis outlined in section 5.8 of the plan the operators shall also obtain and analyze produced water samples on wells described in the plan for constituents listed in the plan using the specified method where applicable. Pit construction shall comply with the "reserve pit and liner design technical specifications," dated July 2008. The moisture content of any drill cuttings in a cuttings pit, trench, or pile shall be as low as practicable to prevent accumulation of liquids greater than de minimis amounts. At the time of closure, the drill cuttings must also meet the applicable standards of Table 910-1. No portion of any pit that will be used to hold liquids shall be constructed on fill material, unless the pit and fill slope are designed and certified by a professional engineer, subject to review and approval by the director prior to construction of the pit. The construction and lining of the pit shall be supervised by a professional engineer or their agent. The entire base of the pit must be in cut. |
| OGLA | Form: (02A)
400965025
02/26/2016 | Approval of this Form 2A and the Form 2 for the injection well (Form 2# 400952380) 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 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. The construction and lining of the secondary containment structures/areas shall be supervised by a professional engineer or their agent.
Operator shall equip and maintain on all tanks an electronic fluid level monitoring device.
Unless otherwise determined by COGCC staff (Bob Koehler) that a water sample of the proposed injection formation is not required, before hydraulic stimulation of the injection well, operator shall collect a groundwater sample from the Cozzette-Corcoran Formation and the Ohio Formation and analyze for total dissolved solids (TDS); submit laboratory analytical results to COGCC (emails: bob.koehler@state.co.us and arthur.koelspell@state.co.us). |
| OGLA | Form: (02A)
400965025
02/26/2016 | Operator shall pressure test pipelines (flowlines from wellheads to separators to tanks; and any temporary surface lines used for hydraulic stimulation and/or flowback operations) in accordance with Rule 1101.e.(1) prior to putting into initial service any temporary surface or permanent buried pipelines and following any reconfiguration of the pipeline network. |
| OGLA | Form: (02A)
400965025
02/26/2016 | Flowback and stimulation fluids must be sent to enclosed tanks, separators, or other containment/filtering equipment before the fluids can be placed into any pipeline storage vessel, or other open top containment 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 is required if operator constructs a sufficiently sized perimeter berm.
Potential odors associated with the completions process and/or with long term production operations must be controlled/mitigated. |
| OGLA | Form: (02A)
400965025
02/26/2016 | 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, and Proposed BMPs attachments); including, but 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 (i.e., best management practices [BMPs] associated with fluid containment/control as well as stormwater management for the control of run-on and run-off) sufficiently protective of nearby surface water. 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 access road will be maintained as to not allow any 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)
400965025
02/26/2016 | 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 rig mobilization and 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.
In lieu of standard Form 42 spud notices, submit Form 42 Rulison SAP / Rio Blanco SAP - Spud Notices, specifying the bottom hole location sector and tier.
Operator shall provide complete well-specific emergency contact information to COGCC via email prior to spuding wells on this pad. Rulison.Submittal@state.co.us.
The operator shall follow all requirements of the Project Rulison Sampling and Analysis Plan (SAP), Revision 3.0, dated July 2010. |
| OGLA | Form: (02A)
400965025
02/26/2016 | APPLICABLE PROJECT RULISON COAs FROM PREVIOUS FORM 2A#400036073:
Comply with all DOE Office of Legacy Management requests for sampling and analysis of natural gas and other materials associated with drilling and production.
All materials removed for setting the conductor or for any other excavation on this site must be screened for gamma emitters; if any gamma emitter detection above background is encountered, the operator must isolate the materials and contact COGCC, CDPHE and DOE for further instructions.
Produced water from this location may not be transported to or re-used at another location without specific written approval from COGCC and only after analysis confirms compliance with the Rulison SAP.
Drill solids and cuttings from this location may not be transported to, disposed of or re-used at another location without specific written approval from COGCC and only after analysis confirms compliance with the Rulison SAP.
No individual operator shall utilize more than one rig within one mile of the Project Rulison blast site at any given time and no individual operator shall utilize more than two rigs within a three mile radius of the site at any given time; the total number of rigs allowed by all operators within three miles of the site shall be limited to five at any given time.
Pit construction shall comply with the Reserve Pit and Liner Design Technical Specifications, dated July 2008 (if a pit is constructed).
No portion of any pit that will be used to hold liquids shall be constructed on fill material, unless the pit and fill slope are designed and certified by a professional engineer, subject to review and approval by the director prior to construction of the pit; the construction and lining of the pit shall be supervised by a Professional Engineer or their agent; the entire base of the pit must be in cut (if a pit is constructed).
The proposed surface casing is more than 50' below the depth of the deepest water well within 1 mile of the surface location when corrected for elevation differences; the deepest water well within 1 mile is 250 feet deep. water wells within one (1) mile of all locations must be checked. (Rule 321) the operator shall comply with Rule 321; and it shall be the operator's responsibility to ensure that the wellbore complies with setback requirements in commission orders or rules prior to producing the well (unless otherwise indicated by COGCC Engineering on the Form 2s). |