| OGLA | Form: (02A)
400125302
03/21/2011 | SENSITIVE AREA (CLOSE SURFACE WATER) COAs:
Location is in a sensitive area because of proximity to surface water; therefore, 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 (at least every 14 days), and maintained in good condition.
Operator must implement best management practices to contain any unintentional release of fluids, including any fluids conveyed temporary surface pipelines or buried pipelines.
Either a lined drilling pit or a closed loop system (which operator has indicated on the Form 2A) must be implemented. |
| OGLA | Form: (02A)
400125302
03/21/2011 | GENERAL SITE COAs:
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.
The surface soils and materials are fine-grained and highly unconsolidated; therefore appropriate BMPs need to be in place 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.
Notify the COGCC Oil and Gas Location Assessment (OGLA) Specialist for Western Colorado (Dave Kubeczko; email dave.kubeczko@state.co.us) and the COGCC Field Inspection Supervisor for Northwest Colorado (Shaun Kellerby; email shaun.kellerby@state.co.us) 48 hours prior to start of fracing operations.
Flowback and stimulation fluids must be sent to tanks to allow the sand to settle out before the fluids can be placed into any pipeline or pit located on the well pad. The flowback and stimulation fluid tanks 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 (per Rule 604.a.(4)).
Berms or other containment devices shall be constructed in compliance with Rule 604.a.(4) around crude oil, condensate, and produced water storage tanks.
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| OGLA | Form: (02A)
400853079
09/29/2015 | Approval of this Form 2A and the Form 2 for the injection well (Form 2# 400850708) 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, their agent, or “competent person” as identified by the operator.
Operator shall equip and maintain on all tanks an electronic level monitoring device.
Unless otherwise determined by COGCC staff (Bob Koehler) that a water sample of the proposed injection formation is not required, before hydraulic stimulation of the injection well, operator shall collect a groundwater sample from the Cozzette-Corcoran Formation and the Ohio Formation 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)
400853079
09/29/2015 | 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. |
| OGLA | Form: (02A)
400853079
09/29/2015 | The moisture content of 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 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.
Flowback and stimulation fluids must be sent to tanks, separators, or other containment/filtering equipment before the fluids can be placed into any pipeline, storage vessel, or lined pit (only if an amended Form 2A has been submitted/approved and a Form 15 Earthen Pit Permitted has been submitted/approved) 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: (02A)
400853079
09/29/2015 | Operator must ensure secondary containment for any volume of fluids contained at well site during drilling and completion operations (as shown on the Construction Layout Drawings, Facility Layout Drawing, and Location Drawing); 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 per CDPHE requirements and after precipitation events), and maintained in good condition.
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.
The location is in an area of moderate to high run-on/run-off potential; therefore standard stormwater BMPs must be implemented; prior to, during, and after construction, as well as during drilling, completion, and production operations; at this location to insure compliance with CDPHE and COGCC requirements and to prevent any stormwater run-on and /or stormwater run-off.
Berms or other containment devices shall be constructed to be sufficiently impervious (corrugated steel with poly liner or equivalent) to contain any spilled or released material around permanent crude oil, condensate, and produced water storage tanks. |
| OGLA | Form: (02A)
400853079
09/29/2015 | Notify the COGCC 48 hours prior to start of pad construction, rig mobilization, spud, pipeline testing, start of hydraulic stimulation operations, and start of flowback operations (if different that stimulation) using Form 42 (the appropriate COGCC individuals will automatically be email notified, including the LGD for hydraulic stimulation operations).
The operator shall submit, and receive approval of, a reuse and recycling plan per Rule 907.a.(3), prior to any offsite reuse/recycling of cuttings. |
| Environmental | Form: (04)
403257361
12/13/2022 | Returned to Draft for operator correction. Based on the information provided the operator should be requesting four (4) exceptions to Rule 609. |
| Environmental | Form: (04)
403257361
12/13/2022 | A review of information available on COGIS maps indicates that the Operator has addressed all water features that meet the 100 series definition of a Water Source within 1/2 mile of the oil/gas location as required under Rule 609. |
| Environmental | Form: (04)
403257361
12/13/2022 | The spring with Facility ID 754620 was dry and not able to be sampled. |