| OGLA | Form: (02A)
400254799
03/17/2012 | SITE SPECIFIC COAs:
Operator must ensure 110 percent secondary containment for any volume of fluids contained at 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 stormwater management) sufficiently protective of nearby surface water. Any berm constructed at the well pad location will be stabilized, inspected at regular intervals, and maintained in good condition..
Operator must implement best management practices to contain any unintentional release of fluids, including any fluids conveyed via temporary surface pipelines or buried permanent pipelines.
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 pit 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 with additional downgradient perimeter berming. The area where flowback fluids will be stored/reused must be constructed to be sufficiently impervious to contain any spilled or released material.
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, if drill cuttings are to remain/disposed of onsite, they must also meet the applicable standards of table 910-1.
Berms or other containment devices shall be constructed to be sufficiently impervious to contain any spilled or released material around crude oil, condensate, and produced water storage tanks.
A closed loop system must be implemented during drilling.
Due to the steep slopes to the southeast, this location is in an area of moderate to high run off/run on potential; therefore the pad shall be constructed as quickly as possible and appropriate BMPs need to be in place both during, after well pad construction completion, as well as during all drilling and well completion operations. Standard stormwater BMPs must be implemented at this location to insure compliance with CDPHE and COGCC requirements and to prevent any stormwater run-on and /or stormwater runoff. |
| OGLA | Form: (02A)
400791229
05/04/2015 | Notify the COGCC 48 hours prior to start of pad reconstruction/regarding, rig mobilization, spud, pipeline testing, start of hydraulic stimulation operations, and start of flowback operations (if different than hydraulic stimulation operations) using Form 42 (the appropriate COGCC individuals will automatically be email notified, including the LGD for hydraulic stimulation operations). |
| OGLA | Form: (02A)
400791229
05/04/2015 | 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. 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 not 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 temporary surface pipelines. This will reduce surface disturbance and fragmentation of wildlife habitat in the area. |
| OGLA | Form: (02A)
400791229
05/04/2015 | Operator must ensure secondary containment for any volume of fluids contained at tank site during operations (as shown on the Proposed BMPs 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 (i.e., best management practices [BMPs] associated with stormwater management) sufficiently protective of nearby surface water. Any berm constructed at the well pad location will be stabilized, inspected at regular intervals (at least every 14 days and after significant precipitation events), and maintained in good condition.
The access road will be 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 enforcing established speed limits on private roads, to reduce fugitive dust and coating of vegetation and deposition in water sources. |
| OGLA | Form: (02A)
400791229
05/04/2015 | A closed loop system must be implemented during drilling. All cuttings generated during drilling with oil based mud (OBM) or high chloride/TDS based mud (salt) 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 cuttings containment area or pile shall be as low as practicable to prevent accumulation of liquids greater than de minimis amounts. At the time of closure, if the drill cuttings are to be left onsite, they must also meet the applicable standards of Table 910-1. Representative cuttings samples will be analyzed for all Table 910-1 constituents. Any material which does not meet Table 910-1 criteria will either be manifested and disposed offsite at an approved commercial facility, sent to a permitted WPX Cuttings Management Trench for additional amending (Form 4 Sundry must be submitted and approved), or amended further onsite to comply with Table 910-1. If operator determines that long-term onsite management of oil based mud or high chloride/TDS mud cuttings is necessary, an approved Form 27 remediation plan will be required. All liners associated with oil based or high chloride/TDS drilling mud and cuttings must be disposed of offsite per CDPHE rules and regulations.
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, 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. 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 shall occur without prior approval of a Waste Management Plan (submitted via a Form 4 Sundry Notice) specifying disposal location and waste characterization method. Commercial disposal of drill cuttings will only require notification to COGCC via a Form 4 Sundry Notice.
If the well(s) is(are) to be hydraulically stimulated, 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.
Potential odors associated with the completions process and/or with long term production operations must be controlled/mitigated. |
| OGLA | Form: (04)
401685594
07/30/2018 | 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 completion 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 E&P 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. |
| OGLA | Form: (04)
401685594
07/30/2018 | Emissions Mitigation: The following COA will apply:
COA 26 - Potential odors associated with the remote frac pad water storage and water transfer operations during the completions process at nearby well pads must be controlled/mitigated. |
| OGLA | Form: (04)
401685594
07/30/2018 | Spill / Release Response: The following COAs will apply:
COA 73a - An emergency spill response program that includes employee training, safety and maintenance provisions and current contact information for BLM, COGCC, and CPW personnel will be implemented during water storage and water transfer operations. In the event of a spill or release, the operator shall immediately implement the emergency response procedures in the above described emergency response program. All personnel working at the location during all water storage and water transfer operations will receive training on spill response and reporting.
COA 73b - A spill response trailer or spill response equipment and supplies will be available near the location 24 hours a day, 7 days a week during construction, drilling, and completion operations (the trailer should be able to reach the site within 45 to 60 minutes after an incident).
COA 73c - Appropriate heavy equipment (e.g., a backhoe) will be staged at or near the location during all water transfer operations so that any emergency diversions or pits to contain spills can be built immediately upon discovery. |
| OGLA | Form: (04)
401685594
07/30/2018 | Completions: The following COAs will apply:
COA 25 - No open top tanks can be used for water storage, water transfer, or initial flowback fluids containment. The entire pad will be surrounded by a berm with a drainage ditch constructed interior to that berm in order to contain any potential release on the temporary frac pad. Any fluid in the interior drainage ditch would be contained in the ditch until clean up.
COA 26 - If the ‘temporary remote frac pad facility’ needs to be used during the next drilling / completion season at additional oil and gas locations, or if there is more than 90 days between use, all tanks and equipment containing fluids must be drained, cleaned, and tagged as temporarily decommissioned (i.e., each tank, vessel, and piece of equipment must have a sign indicating it is empty, clean, and out of use [indicating the date]). |
| OGLA | Form: (04)
401685594
07/30/2018 | Construction: The following COAs will apply:
COA 23 - Operator must ensure secondary containment for any volume of fluids contained at the well site during 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 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)
401685594
07/30/2018 | 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 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 (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 94 - The remote frac pad facility shall be in operation for no longer than three (3) years. The three year time clock will start from the date of first use based on submittal of the Form 42 providing that date.
COA 95 - The approved Form 4 #401685594 for this location will be posted onsite during construction, temporary surface pipeline placement and operations, remote frac pad water storage and water transfer operations, and demobilization. |