| OGLA | Form: (02A)
401298622
08/03/2017 | Operator shall pressure test temporary surface or permanent buried pipelines (including flowlines from the existing tank battery to the multi-well pit [if constructed] and any temporary surface lines used for fluid transfer between this location and other oil and gas locations) in accordance with Rule 1101.e.(1) prior to putting any pipeline into initial service.
Operator must routinely inspect the entire length of all surface pipelines to ensure integrity. Operator shall conduct daily inspections of surface pipeline routes for leaks during active transfer of fluids and implement best management practices to contain any unintentional release of fluids along all portions of the surface pipeline route where temporary pumps and other necessary equipment are located. Inspections shall be conducted by viewing the length of the pipeline; operator will endeavor to minimize surface disturbance during pipeline monitoring. In addition, pump stations along the surface pipeline route will be continuously monitored when operating in order to swiftly respond to such a failure.
Operator will implement BMPs necessary to mitigate a potential for a release of fluids to impact streams, intermittent streams, ditches, and drainage crossings. For surface pipelines at these crossings, operator will ensure appropriate containment by either 1) installing over-sized pipe “sleeves” which extend the length of the crossing and beyond to adequately sized catchment basins or appropriately designed divergent trenches to prevent a spill of fluids from reaching the stream or drainage; 2) installing over-sized pipe “sleeves” which extend the length of the crossing and installing shut off valves on either side of crossing instead of catchment basins; or 3) develop an alternative means for spill control and containment.
To reduce surface disturbance and minimize fragmentation of wildlife habitat, operator shall utilize, to the extent practical, existing public roads, private roads, and access roads, and/or existing pipeline right-of-ways, when placing/routing the temporary surface pipelines. |
| OGLA | Form: (02A)
401298622
08/03/2017 | Potential odors associated with the mutli-well pit operations must be controlled/mitigated. |
| OGLA | Form: (02A)
401298622
08/03/2017 | Operator has indicated that fluid transfer from the pit to nearby well locations will be done entirely through existing permanent pipelines, or possibly temporary surface pielines. Operator will not be allowed to load or unload produced water to or from the pit using trucks. Vacuum trucks may be utilized for use in skimming operations and in the final draining process prior to pit closure, but not utilized in the normal operation of the pit.
Operator must submit an as-built drawing (plan view and cross-sections) of the multi-well pit and the oil and gas location (including all tanks and other pit operations equipment) within 60 calendar days of re-construction of the location, pit, and any operating equipment.
After installation of the uppermost liner and prior to operating the pit, the synthetic liner(s) integrity shall be tested to the operating capacity of the pit facility (not to exceed the 2-foot freeboard requirement). The operator shall monitor the pit for leaks for a period of 72 hours prior to either draining the pit or commencing operations. Operator shall notify the COGCC 48 hours prior to start of the hydrotest using the Form 42. Hydrotest monitoring results must be maintained by the operator for the life of the pit and provided to COGCC prior to using the pit via a Form 4 Sundry.
The multi-well pit must be fenced and netted. The operator must maintain the fencing and netting until the pit is closed. The fencing shall be placed a minimum of 1-foot from the pit liner anchor trench.
Operator will use adequately sized secondary containment devices for all chemicals and/or hazardous materials stored or used on location.
Operator will implement measures to ensure that adequate separation of hydrocarbons from the influent occurs to prevent accumulation of oil on the surface of stored completions fluids. Operator shall also employ a method for monitoring buildup of phase-separated hydrocarbons on the surface of stored fluids.
Any oil (other than de minimis amounts) observed on the surface of completions fluids must be removed in accordance with Rule 902.c. |
| OGLA | Form: (02A)
401298622
08/03/2017 | The access road from the public road to the multi-well pit location will be 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 to reduce fugitive dust and coating of vegetation and deposition in water sources. |
| OGLA | Form: (02A)
401298622
08/03/2017 | Operator shall submit a revised Hydrology Map that meets the requirements of the Form 2A Rules and the Form 2A Attachment Guidance for Hydrology Maps within 14 days of approval of the Form 2A and Form 15.
Prior to first use of the multi-well pit, operator shall submit and receive approval of an E&P waste management plan per Rule 907.a.(3).
Prior to first use of the multi-well pit, operator shall submit via Form 4 Sundry an Operating Plan which lists locations and wells that this multi-well pit will be used to support and facilitate completions; the Operating Plan shall be updated annually as needed.
Per Rule 902.e, this multi-well pit is permitted for maximum of three (3) years use for storage, recycling, reuse, treatment, or disposal of E&P waste or fresh water, as applicable. The three year time clock will start from the date of first use after hydrostatic testing and be based on submittal of the Form 42 providing that date. The operator shall cease using the pit after three (3) years use and immediately begin pit closure in accordance with Rule 905.
In addition to the notifications required by COGCC listed in the Northwest Notification Policy and Rule 316C., operator shall notify the COGCC 48 hours prior to start of hydrostatic test, start of first use of pit for operations, onsite and offsite pipeline testing (any permanent buried or temporary surface lines used for transferring fluids to or from this multi-well pit) using the Form 42 (as described in Rule 316C.m. Notice of Completion of Form 2/2A Permit Conditions).
In addition to the notifications required by COGCC listed in the Northwest Notification Policy (Notice of Intent to Construct a New Location 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 start of pit construction, pit liner installation, start of hydrostatic test, start of first use of pit for operations, pipeline testing, onsite and offsite pipeline testing (any permanent buried or temporary surface lines used for hydraulic stimulation and/or flowback operations), and start of hydraulic stimulation operations at nearby well pad locations 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.
Prior to placement of any temporary surface pipelines (poly or steel), operator will submit a Form 4 Sundry Notice indicating the proposed route of the temporary surface pipelines and any pump stations along the route. |
| Environmental | Form: (04)
401427217
11/10/2017 | Prior to first use, provide a time frame (duration) that the proposed temporary above ground lines will be in service. |