| OGLA | Form: (02A)
401101898
01/20/2017 | Operator shall pressure test pipelines (flowlines from wellheads to separators to tanks; pipelines from onsite separators to offsite storage 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, and tested annually, unless agreed to by both parties that the flowlines can be managed under an approved COGCC variance. |
| OGLA | Form: (02A)
401101898
01/20/2017 | 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]).
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.
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.
Operator shall follow all requirements of COGCC’s current policy - NOTICE TO OPERATORS, Rule 912. VENTING OR FLARING PRODUCED NATURAL GAS – STATEWIDE, dated January 12, 2016; and to Rule 912. VENTING OR FLARING NATURAL GAS. a. thru e. in regards to venting and flaring. |
| OGLA | Form: (02A)
401101898
01/20/2017 | Operator must ensure secondary containment for any volume of fluids contained at the well site during drilling and completion operations; 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 or fluid management structures shall be sized, constructed, and compacted sufficiently to contain and/or manage potential fluid releases during operations in a manner that prevents or controls potential sedimentation and scouring on adjacent lands and drainages. Such design/build of perimeter berms or fluid management structures may include, but are not limited to the following: on location berms; diversion ditches; enhanced vegetation; or other design features necessary to achieve the goal of protecting adjacent lands and drainages from potential sedimentation and scouring.
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.
Berms or other containment devices shall be constructed to be sufficiently impervious (corrugated steel with poly liner) to contain any spilled or released material around permanent oil and/or produced water storage tanks.
If oil and produced water storage tanks are not constructed on location, operator shall submit a scaled as-built drawing (plan view with distances) of this oil and gas location (showing wellheads, pumping jacks, onsite flowlines, offsite pipelines, and production facilities [separators, etc.]) and the nearby production facility location to which the oil and produced water will be sent to via underground pipelines (showing wellheads, onsite flowlines, offsite pipelines, pumping jacks, oil and produced water storage tanks, and other production facilities) within 30 calendar days of construction of the production equipment on either or both locations. |
| OGLA | Form: (02A)
401101898
01/20/2017 | In addition to the notifications required by COGCC listed in the Northwest Notification Policy (Notice of Intent to construct a new location) and Rule 316C. COGCC Form 42. FIELD OPERATIONS NOTICE (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 lines associated with truck loading 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.
Water Well Groundwater Testing: In addition to the three groundwater sampling events required in Rule 609. STATEWIDE GROUNDWATER BASELINE SAMPLING AND MONITORING (initial sampling conducted within 12 months prior to setting conductor pipe in a well or the first well on a multi-well site; the first subsequent sampling event conducted at the same locations between 6 and 12 months; with a second subsequent sampling event at the same locations conducted between 60 and 72 months following completion of the well or the last well on a multi-well site), operator shall conduct two additional groundwater sampling events; one during drilling of the well(s) and one within 3 months of completion of the well(s). The groundwater sampling events shall be conducted at the following three (3) stock/domestic/household water wells that are located within approximately one-half mile of the proposed oil and gas location:
(1) Permit No. 91638-Van Valkenburg, William J; stock water well; TD - 100’ bgs; SWL - 50’ bgs; Pumping Rate - 5 gpm; located approximately 1699’’ to the E-SE (upgradient); (2) Permit No. 105771-Maxwell, Max R & Jean E; domestic water well; TD - 102’ bgs; Screened/Perforated Interval - 80’ to 102’ bgs; SWL - 70’ bgs; Pumping Rate - 15 gpm; located approximately 2428’’ to the S (upgradient); and (3) Permit No. 72176- Valkenburg, William J; household water well; TD - 60’ bgs; Screened/Perforated Interval – 50’ to 60’ bgs; SWL - 12’ bgs; Pumping Rate - 15 gpm; located approximately 2926’’ to the NW-W (downgradient).
The groundwater sample locations shall be surveyed in accordance with Rule 215. Sampling and analysis shall be conducted in conformance with Rule 609. STATEWIDE GROUNDWATER BASELINE SAMPLING AND MONITORING. Additional test(s) may be required if changes in water quality are identified during subsequent/follow-up testing. The Director may require further water well sampling at any time in response to complaints from water well owners. Copies of all test results described above shall be provided to the Director and the landowner where the water quality testing well is located within three (3) months of collecting the samples used for the test. The analytical data and surveyed well locations shall also be submitted to the Director in an electronic data deliverable format. Documented refusal to grant access by well owner or surface owner shall not constitute a violation of this COA. |