| OGLA | Form: (02A)
400673596
10/20/2014 | Notify the COGCC 48 hours prior to start of frac pad reconstruction/regrading, pipeline testing, start of hydraulic stimulation operations, and start of flowback operations using Form 42 (the appropriate COGCC individuals will automatically be email notified, including the LGD for hydraulic stimulation operations).
The frac pad facility shall be in operation for no longer than 3 years. |
| OGLA | Form: (02A)
400673596
10/20/2014 | Operator must ensure secondary containment for any volume of fluids contained at frac pad site during operations (as described in the Sensitive Area Data attachment); 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 sufficiently protective of nearby surface water. Any berm constructed at the pit/frac pad location will be stabilized, inspected at regular intervals (at least every 14 days and after precipitation events), and maintained in good condition.
Strategically apply fugitive dust control measures, including enforcing established speed limits on private roads, to reduce fugitive dust and coating of vegetation and deposition in water sources.
Operator shall stabilize exposed soils and slopes as an interim measure during frac pad operations at this site.
The access road will maintained as to not allow any sediment to migrate from the access road to nearby surface water or any drainages leading to surface water.
Additional containment shall be required where temporary or permanent pumps and other necessary equipment or chemicals are located on the frac pad site.
Operator will use adequately sized containment devices for all chemicals and/or hazardous materials stored or used on location. |
| OGLA | Form: (02A)
400673596
10/20/2014 | Flowback and stimulation fluids must be sent to tanks, separators, or other containment/filtering equipment before the fluids can be placed into any pipeline or storage vessel located on the well pad; or into tanker trucks for offsite disposal. 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 and with additional downgradient perimeter berming.
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 fluids. Operator shall also employ a method for monitoring buildup of phase-separated hydrocarbons on the surface of stored fluids.
Potential odors associated with the completions process and/or with long term production operations must be controlled/mitigated. |
| OGLA | Form: (02A)
400673596
10/20/2014 | Operator shall pressure test pipelines 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.
Operator must routinely inspect the entire length of the surface pipeline to ensure integrity. Operator shall conduct daily inspections of surface poly 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. The operator shall maintain records of inspections, findings and repairs, if necessary, for the life of the pipelines. In addition, pump stations along the surface poly or steel 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 these crossings: if poly pipe is used on the surface, operator will ensure appropriate containment by either installing over-sized pipe “sleeves” which extend the length of the crossing and beyond to a distance deemed adequate to capture (catchment basins) and/or divert any possible release of fluids and prevent fluids from reaching the stream or drainage; 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 develop an alternative means for containment. For all other pipeline materials, operator will implement BMPs necessary to mitigate a potential for E&P fluids to reach groundwater or flowing surface water.
Operator will utilize, to the extent practical, all existing access and other public roads, and/or existing pipeline right-of-ways, when placing/routing the surface pipelines. This will reduce surface disturbance and fragmentation of wildlife habitat in the area. |
| OGLA | Form: (04)
401557747
03/31/2018 | Planning: The following COAs will apply:
COA 91 - 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 onsite / offsite pipeline testing (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.
COA 92 - Prior to first use, operator shall submit a Site Drawing showing the location of the temporary frac tanks and any transfer pumps on this oil and gas location.
COA 93 - The temporary frac pad facility shall be in operation for no longer than 3 years. |
| OGLA | Form: (04)
401557747
03/31/2018 | Construction: The following COAs will apply:
COA 23 - Operator must ensure secondary containment for any volume of fluids contained at the well site during remote frac pad operations; including, but not limited to, reconstruction of a berm or diversion dike, diversion/collection trenches within and/or outside of berms/dikes, site re-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.
COA 27 - Operator shall stabilize exposed soils and slopes as an interim measure during temporary frac pad operations at this site.
COA 28 - Additional containment shall be required where temporary or permanent pumps and other necessary equipment or chemicals are located on the frac pad site.
COA 29 - Operator will use adequately sized containment devices for all chemicals and/or hazardous materials stored or used on location. |
| OGLA | Form: (04)
401557747
03/31/2018 | Emissions Mitigation: The following COA will apply:
COA 26 - Potential odors associated with the completions process must be controlled/mitigated. |
| OGLA | Form: (04)
401557747
03/31/2018 | Material Handling and Spill Prevention: The following COAs will apply to this Form 4 Sundry Notice if any temporary surface (COAs 45, 49, 54, and 55) or buried permanent offsite pipelines (poly or steel) are used during remote frac pad operations at this oil and gas location:
COA 45 - Operator shall pressure test pipelines (pipelines from 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.
COA 49 - Operator must routinely inspect the entire length of the surface pipeline to ensure integrity. Operator shall conduct daily inspections of surface poly 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 poly or steel pipeline route will be continuously monitored when operating in order to swiftly respond to such a failure.
COA 54 - Operator will implement BMPs necessary to mitigate a potential for a release of fluids to impact streams, intermittent streams, ditches, and drainage crossings. For these crossings: if poly pipe is used on the surface, operator will ensure appropriate containment by either installing over-sized pipe “sleeves” which extend the length of the
crossing and beyond to a distance deemed adequate to capture (catchment basins) and/or divert any possible release of fluids and prevent fluids from reaching the stream or drainage; 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 develop an alternative means for containment. For all other pipeline materials, operator will implement BMPs necessary to mitigate a potential for fluids not to reach groundwater or flowing surface water.
COA 55 - Operator will utilize, to the extent practical, all existing access and other public roads, and/or existing pipeline right-of-ways, when placing/routing the temporary surface pipelines. This will reduce surface disturbance and fragmentation of wildlife habitat in the area. |