| Agency | Form: (02A)
400042254
05/07/2010 | The nearby hillside must be monitored for any day-lighting of drilling fluids throughout the drilling of the surface casing interval. |
| Agency | Form: (02A)
400042254
05/07/2010 | No portion of any pit that will be used to hold liquids shall be constructed on fill material, unless the pit and fill slope are designed and certified by a professional engineer, subject to review and approval by the director prior to construction of the pit. The construction and lining of the pit shall be supervised by a professional engineer or their agent. The entire base of the pit must be in cut. |
| Agency | Form: (02A)
400042254
05/07/2010 | Reserve pit must be lined. |
| Agency | Form: (02A)
400042254
05/07/2010 | Operator must ensure 110 percent secondary containment for any volume of fluids contained at well site during drilling and completion operations. If fluids are conveyed via pipeline, operator must implement best management practices to contain any unintentional release of fluids. |
| Agency | Form: (02A)
400042254
05/07/2010 | All pits must be lined. |
| Agency | Form: (02A)
400042254
05/07/2010 | The moisture content of any drill cuttings in a cuttings pit, trench, or pile shall be as low as practicable to prevent accumulation of liquids greater than de minimis amounts. At the time of closure, the drill cuttings must also meet the applicable standards of table 910-1.
|
| OGLA | Form: (04)
401472432
12/05/2017 | Material Handling and Spill Prevention: The following COAs will apply to this location since temporary surface (COAs 1, 2, 3, and 4) and buried permanent (COA 1) flowlines and/or offsite pipelines (poly or steel) are used during operations at the temporary frac pad and the nearby well pad location:
MH 1 - 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.
MH 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 thesurface poly or steel pipeline route will be continuously monitored when operating in order to swiftly respond to such a failure.
MH 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.
MH 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 wildlifehabitat in the area. |
| OGLA | Form: (04)
401472432
12/05/2017 | Completion Operations: The following COAs will apply to this location for all completion activities:
CMPL 1 - Potential odors associated with the completions process operations must be controlled / mitigated. |
| OGLA | Form: (04)
401472432
12/05/2017 | Construction: The following COAs will apply to this location for temporary frac pad re-construction and installation activities:
CON 1 - Operator must ensure secondary containment for any volume of fluids contained at the well site and temporary frac pad site during nearby completion operations; including, but not limited to, re-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 re- constructed at the 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.
|
| OGLA | Form: (04)
401472432
12/05/2017 | Planning: The following COAs will apply to this location for general planning, notification, and coordination of activities:
PLN 1 - 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 offsite pipeline installation and onsite flowline/pipeline testing (flowlines from wellheads to separators to tanks; 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.
PLN 2 - Temporary Frac Pad location cannot be used for more than 3 years. |
| Reclamation Specialist | Form: (04)
402702448
06/07/2021 | Per email conversation between Operator and Reclamation Supervisor, an extension to submit a plan attached to a Form 4 Sundry to Reclamation Specialist by 6/4/2021 (from 5/27/2021) is approved. |
| Reclamation Specialist | Form: (04)
402726405
06/24/2021 | Any future material from sediment trap maintenance for potential use in the reclamation for the current year will need to be approved by COGCC prior to it being placed on any locations and requires a Reclamation Plan. |
| Reclamation Specialist | Form: (04)
402726405
06/24/2021 | Operator shall not mix sediment material with topsoil, and must only be used as subsoil material. |