| OGLA | Form: (02A)
401033255
06/10/2016 | 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. |
| OGLA | Form: (02A)
401033255
06/10/2016 | Potential odors associated 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)
401033255
06/10/2016 | Operator must ensure secondary containment for any volume of fluids contained at the tank battery site during truck tank loading and production 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 shall be sized, constructed, and compacted sufficiently to contain fluids during truck tank loading and production operations.
The access road will be constructed and 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.
Berms or other containment devices shall be constructed to be sufficiently impervious (corrugated steel with poly liner or equivalent protection) to contain any spilled or released material around permanent oil and produced water storage tanks.
Operator will construct a loading/unloading station located near the tank battery, to deliver fluids to or remove fluids from the oil and produced water storage tanks by truck. The loading/unloading station shall be designed and utilized to prevent hoses from being dropped and dragged over the ground, which could lead to releases outside of containment. The loading/unloading station will be the only permitted access for manual fluids transfers to or from the storage tanks. Vehicles will not be allowed to approach the storage tanks any closer than the loading/unloading station. Each station will have a catch basin in case a leak occurs while operations personnel are connecting or disconnecting hoses. Signs clearly marking the truck loading/unloading station shall be provided and maintained by the operator.
This COA applies to vehicles (oil and water trucks) used for pulling water or oil from the loadout station, not directly from the tanks, unless there is equipment problems at the loadout station, in which case, water and oil trucks could then pull directly from the individual tanks. directly from the tanks then this should only impact. Also, if operator needs to remove/repair/replace a tank, then such equipment necessary to perform the work (water truck, vacuum truck, crane truck) would be allowed as close to the tank battery area and individual tanks as necessary.
Operator shall submit a scaled as-built drawing (plan view with distances) of the Bighorn 0780 17 tank battery location (showing oil and produced water storage tanks, onsite flowlines, offsite pipelines, and other production facilities) and the two nearby well pad locations, OGCC ID#324757-Mutual #01-17H Pad and OGCC ID#439603-Gregory #0780 1-9H Pad, (showing wellheads, onsite flowlines, offsite pipelines, pumping jacks, and onsite production facilities) within 30 calendar days of construction of the production equipment on each location. |
| OGLA | Form: (02A)
401033255
06/10/2016 | 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 the separators on the two nearby well pads to the storage tanks on this central tank battery location; 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. |
| OGLA | Form: (02A)
401080879
09/20/2016 | Operator shall pressure test onsite flowlines and onsite/offsite 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, and tested annually, unless agreed to by both parties that the flowlines can be managed under an approved COGCC variance. Tested lines shall include: flowlines from the separators on the two nearby well pads to the storage tanks on this central tank battery location; flowlines from the wellhead to separator to tanks on this location; and/or any lines associated with truck loading operations. |
| OGLA | Form: (02A)
401080879
09/20/2016 | The moisture content of water/bentonite-based mud (WBM) generated 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, 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 by COGCC (submitted via a Form 4 Sundry Notice) specifying disposal location and waste characterization method. Operator has indicated that onsite disposal of cuttings will be the method of disposal for WBM-based drill cuttings.
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 “OTHER as COMMERCIAL DISPOSAL” (as shown in the ‘DRILLING WASTE MANAGEMENT PROGRAM SECTION’ of the Form 2A#401080879; OGCC ID#446174). 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 OBM-based drill cuttings management and disposal at this location will require submittal (via a Form 4 Sundry Notice) and approval of a revised Waste Management Plan detailing the changes (specifying cuttings characterization methods, cuttings management, amendment, and onsite disposal location[s]).
Potential odors associated 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)
401080879
09/20/2016 | Operator must ensure secondary containment for any volume of fluids contained at the tank battery site during truck tank loading and production 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 shall be sized, constructed, and compacted sufficiently to contain fluids during truck tank loading and production operations.
The access road will be constructed and 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.
Berms or other containment devices shall be constructed to be sufficiently impervious (corrugated steel with poly liner or equivalent protection) to contain any spilled or released material around permanent oil and produced water storage tanks.
Operator will construct a loading/unloading station located near the tank battery, to deliver fluids to or remove fluids from the oil and produced water storage tanks by truck. The loading/unloading station shall be designed and utilized to prevent hoses from being dropped and dragged over the ground, which could lead to releases outside of containment. The loading/unloading station will be the only permitted access for manual fluids transfers to or from the storage tanks. Vehicles will not be allowed to approach the storage tanks any closer than the loading/unloading station. Each station will have a catch basin in case a leak occurs while operations personnel are connecting or disconnecting hoses. Signs clearly marking the truck loading/unloading station shall be provided and maintained by the operator.
This COA applies to vehicles (oil and water trucks) used for pulling water or oil from the loadout station, not directly from the tanks, unless there is equipment problems at the loadout station, in which case, water and oil trucks could then pull directly from the individual tanks. directly from the tanks then this should only impact. Also, if operator needs to remove/repair/replace a tank, then such equipment necessary to perform the work (water truck, vacuum truck, crane truck) would be allowed as close to the tank battery area and individual tanks as necessary.
Operator shall submit a scaled as-built drawing (plan view with distances) of the Bighorn 0780 17 tank battery location (showing oil and produced water storage tanks, onsite flowlines, offsite pipelines, and other production facilities) and the two nearby well pad locations, OGCC ID#324757-Mutual #01-17H Pad and OGCC ID#439603-Gregory #0780 1-9H Pad, (showing wellheads, onsite flowlines, offsite pipelines, pumping jacks, and onsite production facilities) within 30 calendar days of construction of the production equipment on each location. |
| OGLA | Form: (02A)
401080879
09/20/2016 | 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 the separators on the two nearby well pads to the storage tanks on this central tank battery location; flowlines from the wellhead to separator to tanks on this location; 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. |
| OGLA | Form: (02A)
401424938
11/02/2017 | Underground Injection Control (UIC): The following conditions of approval (COAs) will apply to the proposed injection well and any temporary or permanent equipment onsite used for injection:
Approval of this Form 2A and the subsequent Form 2 for the injection well (F26 697 SWD) 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 (COGCC Engineering Staff) that a water sample of the proposed injection formation(s) is(are) not required, before hydraulic stimulation of the injection well, operator shall collect a groundwater sample from the target Formation(s); that will be indicated on the future Form 2 for the injection well; 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)
401424938
11/02/2017 | Operator shall pressure test onsite flowlines and onsite/offsite 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, and tested annually, unless agreed to by both parties that the flowlines can be managed under an approved COGCC variance. Tested lines shall include: flowlines from the separators on the two nearby well pads to the storage tanks on this central tank battery location; flowlines from the wellhead to separator to tanks on this location; and/or any lines associated with truck loading operations. |
| OGLA | Form: (02A)
401424938
11/02/2017 | Potential odors associated 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)
401424938
11/02/2017 | The moisture content of water/bentonite-based mud (WBM) generated 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, 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 by COGCC (submitted via a Form 4 Sundry Notice) specifying disposal location and waste characterization method. Operator has indicated that onsite disposal of cuttings will be the method of disposal for WBM-based drill cuttings.
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 “OTHER as COMMERCIAL DISPOSAL” (as shown in the ‘DRILLING WASTE MANAGEMENT PROGRAM SECTION’ of the Form 2A#401080879; OGCC ID#446174). 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 OBM-based drill cuttings management and disposal at this location will require submittal (via a Form 4 Sundry Notice) and approval of a revised Waste Management Plan detailing the changes (specifying cuttings characterization methods, cuttings management, amendment, and onsite disposal location[s]). Potential odors associated with long term production operations must be controlled/mitigated. |
| OGLA | Form: (02A)
401424938
11/02/2017 | Operator must ensure secondary containment for any volume of fluids contained at the tank battery site during truck tank loading and production 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 shall be sized, constructed, and compacted sufficiently to contain fluids
during truck tank loading and production operations.
The access road will be constructed and 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 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 or equivalent protection) to contain any spilled or released material around permanent oil and produced water storage tanks.
Operator will construct a loading/unloading station located near the tank battery, to deliver fluids to or remove fluids from the oil and produced water storage tanks by truck. The loading/unloading station shall be designed and utilized to prevent hoses from being dropped and dragged over the ground, which could lead to releases outside of containment. The loading/unloading station will be the only permitted access for manual fluids transfers to or from the storage tanks. Vehicles will not be allowed to approach the storage tanks any closer than the loading/unloading station. Each station will have a catch basin in case a leak occurs while operations personnel are connecting or disconnecting hoses. Signs clearly marking the truck loading/unloading station shall be provided and maintained by the operator.
This COA applies to vehicles (oil and water trucks) used for pulling water or oil from the loadout station, not directly from the tanks, unless there is equipment problems at the loadout station, in which case, water and oil trucks could then pull directly from the individual tanks. directly from the tanks then this should only impact. Also, if operator needs to remove/repair/replace a tank, then such equipment necessary to perform the work (water truck, vacuum truck, crane truck) would be allowed as close to the tank battery area and individual tanks as necessary.
All tanks and aboveground vessels containing fluids must have secondary containment structures. All secondary containment structures/areas must be lined. Operator must ensure 150 percent secondary containment for the largest structure containing fluids within each bermed area 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 implement reasonable noise reduction equipment on compressors and other production equipment or add sound barriers to limit noise levels at property boundaries.
Operator shall submit a scaled as-built drawing (plan view with distances) of the Bighorn 0780 17 tank battery location (showing oil and produced water storage tanks, onsite flowlines, offsite pipelines, other production facilities, and all gas processing plant equipment and structures), the two nearby well pad locations, OGCC ID#324757-Mutual #01-17H Pad and OGCC ID#439603-Gregory #0780 1-9H Pad, as well as any additional well pads that will be connected to this location (showing wellheads, onsite flowlines, offsite pipelines, pumping jacks, and onsite production facilities) within 30 calendar days of construction of the production equipment on each location. |
| OGLA | Form: (02A)
401424938
11/02/2017 | 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 the separators on the two nearby well pads to the storage tanks on this central tank battery location;
flowlines from the wellhead to separator to tanks on this location; 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.
Notify the COGCC 48 hours prior to start of gas processing plant construction, pipeline testing, and start of operations using Form 42 (the appropriate COGCC individuals will automatically be email notified). |
| OGLA | Form: (02A)
401990954
06/05/2020 | Prior to construction of the earthen berm using materials from the gas plant area along the western and south edges of the truck loadout area of the facility; any materials from the reclaimed gas plant area (soil, roadbase, and gravel) will be sampled to confirm that these materials meet applicable COGCC standards for reuse. Sample report will be submitted to COGCC upon request. |
| OGLA | Form: (04)
403326452
02/23/2023 | When the temporary combustor has been removed, operator will submit a Form 4 Sundry Notice indicating the date of removel. |
| Engineer | Form: (04)
403110450
04/21/2023 | No sample data attached to Form 43-403111095. Submit data on a Form 43 in the proper EDD format, due 4/28/23. WO Operator reply to pass.
New 43 submitted 5/2/23, Doc #403391661 |
| Environmental | Form: (04)
403206536
07/06/2023 | Submit a Form 27 for the removal of the 5-1100BBL tanks. Per Rule 911. At this time the location of the tanks on the Bighorn pad is unknown. |
| Engineer | Form: (04)
403110450
10/14/2024 | Emissions during upset event not captured with Form 7 reporting should be correct at CDPHE. |
| Engineer | Form: (04)
403110450
10/14/2024 | Assure if F27 403810373 needs to be resubmitted it is resubmitted timely and complete. |