| OGLA | Form: (02A)
401338955
10/18/2017 | The following COAs will apply to this Form 2A Permit if any temporary surface (COAs 1, 2, 3, and 4) or buried permanent (COA 1) flowlines and/or offsite pipelines (poly or steel) are used during operations at this oil and gas location:
COA 1 - Operator shall pressure test pipelines (flowlines from wellheads to separators to blowdown tank; 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.
COA 2 - 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 3 - 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 not to reach groundwater or flowing surface water.
COA 4 - 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. |
| OGLA | Form: (02A)
401338955
10/18/2017 | Potential odors associated with the completions process and/or with long term production operations must be controlled/mitigated. |
| OGLA | Form: (02A)
401338955
10/18/2017 | The moisture content of water/bentonite based mud (WBM) generated drill cuttings 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, if any of the WBM drill cuttings will remain on the well pad location (cuttings management area, the cut portion of the pad, cuttings trench, dry cuttings drilling pit), they must be sampled and meet the applicable standards of Table 910-1. No liners (if used) are allowed to be disposed of with the drill cuttings. After the drill cuttings have been amended (if necessary) and placed on the well pad, sampling frequency of the drill cuttings (to be determined by the operator) shall be representative of the material left on location. No offsite disposal of cuttings to another oil and gas location (TEP’s permitted Cuttings Trench locations or nearby locations) shall occur without prior approval of a Form 4 Sundry Notice specifying disposal location and waste characterization method. Commercial disposal of drill cuttings will also require notification to COGCC via a Form 4 Sundry Notice.
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 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. |
| OGLA | Form: (02A)
401338955
10/18/2017 | 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.
The access road 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.
Since permanent oil, condensate, or produced water storage tanks are not planned to be constructed on location, operator shall submit a scaled as-built drawing (plan view with distances) of this oil and gas location (showing wellheads, onsite flowlines, offsite pipelines, and production facilities [separators, etc.]) and the nearby well pad / production facility location to which the oil, condensate and/or produced water will be sent to via underground pipelines (showing onsite flowlines, offsite pipelines, oil, condensate, and/or 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)
401338955
10/18/2017 | 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 flowline/pipeline testing (flowlines from wellheads to separators to onsite blowdown tank; 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. |
| OGLA | Form: (04)
401540417
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)
401540417
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)
401540417
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)
401540417
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. |
| Permit | Form: (04)
401632265
05/15/2018 | If the well is not drilled prior to the expiration of the original APD, the operator shall meet the requirements of the Conductor Notice to Operators dated 10/6/2016 within 60 days of the expiration: (a) plug conductor and reclaim site, (b) request to keep conductor and provide additional financial assurance, or (c) submit an alternative plan as a variance request. |
| OGLA | Form: (04)
401924920
04/02/2019 | Material Handling and Spill Prevention: The following conditions of approval (COAs) will apply:
•Operator shall pressure test pipelines prior to putting into initial service any temporary surface or permanent buried pipelines.
•Operator must routinely inspect the entire length of the surface pipeline 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 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. These BMPs may shall include 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; or develop alternative means for containment.
•To reduce surface disturbance and fragmentation of wildlife habitat in the area, 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. |
| OGLA | Form: (04)
401924920
04/02/2019 | Construction: The following conditions of approval (COAs) will apply:
•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: (04)
401924920
04/02/2019 | Planning: The following conditions of approval (COAs) will apply:
•Provide Notices as described in the most current version of the Northwest Notification Policy.
•Operator shall prepare an emergency spill response program that includes employee training, safety, and maintenance provisions.
•The temporary frac pad facility shall be in operation for no longer than 3 years. |