| OGLA | Form: (04)
400560815
02/24/2014 | Planning: The following conditions of approval (COAs) will apply:
Notify the COGCC 48 hours prior to start of temporary frac tank pad reconstruction/regrading, containment construction, and pipeline testing, using Form 42 (the appropriate COGCC individuals will automatically be email notified, including the LGD for hydraulic stimulation operations).
Concurrent with notice required by Rule 316C., operator shall provide Form 42 notification to COGCC for this Oil and Gas Location when fracing operations will be supported by this pad. |
| OGLA | Form: (04)
400560815
02/24/2014 | Construction: The following conditions of approval (COAs) will apply:
Operator must ensure secondary containment for any volume (total manifolded volume) of fluids contained at frac pad site during operations; including, but not limited to, construction of a berm or diversion dike, site grading, or other comparable measures (i.e., best management practices (BMPs) associated with stormwater management) sufficiently protective of nearby surface water or drainages. Any berm constructed at the frac pad site will be stabilized, inspected at regular intervals (at least every 14 days), and maintained in good condition.
Berms or other containment devices shall be constructed to be sufficiently impervious (corrugated steel with poly liner) to contain any spilled or released material around permanent crude oil, condensate, and produced water storage tanks. |
| OGLA | Form: (04)
400560815
02/24/2014 | Drilling/Completions: The following conditions of approval (COAs) will apply:
A spill response trailer will be on location 24 hours a day, 7 days a week during construction and completion operations to facilitate a timely response to any spills that may occur.
Appropriate heavy equipment (e.g., a backhoe) will be staged nearby and available at the location during all completion operations so that any emergency diversions or pits to contain spills can be built immediately upon discovery.
All personnel working at the location during all drilling and completion operations will receive training on spill response and reporting. Documentation of this training will be maintained in the operator’s office/onsite trailer.
At a minimum, weekly spill prevention meetings will be held identifying staff responsibilities in order to provide a quick and effective response to a spill. Appropriate documentation will be maintained in the operator’s office/onsite trailer.
Operator will conduct daily inspections of equipment for leaks and equipment problems with appropriate documentation retained in the operator’s office/onsite trailer. All equipment deficiencies shall be corrected. Daily monitoring should end approximately 14 days after well completion and/or after production has been stabilized; however, timely inspections should continue during the production phase.
Operator shall have trained personnel present at the frac tanks during water transfer into or out of tanks; personnel shall be able to shut off transfer pumps or close valves as necessary in response to upset conditions.
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 hazardous chemicals and/or materials stored or used on location.
Operator will implement measures to ensure that adequate separation of hydrocarbons from the influent occurs to prevent accumulation of oil on the surface of stored fluids.
Operator shall also employ a method for monitoring buildup of phase-separated hydrocarbons on the surface of stored fluids.
Based on the schedule provided by Operator, use of this Oil and Gas Location for the purposes of a temporary remote frac pad is not permitted beyond May 31, 2014. |
| OGLA | Form: (04)
400560815
02/24/2014 | Pipelines: The following conditions of approval (COAs) will apply to the Form 4 if any temporary surface (poly/steel) or buried (poly or steel) pipelines are used during operations at the temporary frac pad location or nearby well pads:
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 shall 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 testing surface or buried poly/steel pipelines.
Operator must 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.
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. Inspections shall be conducted by viewing the length of the pipeline; operator will endeavor to minimize surface disturbance during pipeline monitoring. The operator shall maintain records of inspections, findings and repairs, if necessary, for the life of the pipelines.
Operator must ensure appropriate secondary containment for volume of fluids that may be released before pump shut down from the surface pipeline at all stream, intermittent stream, ditch, and drainage crossings. Catchment basins, if needed, should be sized to contain the volume between pump stations or between the nearest pump station and the frac pad being used for this well pad location. 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 utilize, to the extent practical, all existing access and other public roads, and/or existing pipeline right-of-ways, when placing/routing the surface pipelines. Operator shall notify the COGCC OGLA Specialist for Western Colorado (Dave Kubeczko; email dave.kubeczko@state.co.us) 48 hours prior to placement of temporary surface poly pipelines.
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| OGLA | Form: (02A)
400853982
09/29/2015 | Approval of this Form 2A and the Form 2 for the injection well (Form 2# 400854939) 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 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 Creek 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)
400853982
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)
400853982
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)
400853982
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, Proposed BMPs, and Location Drawing attachments); 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)
400853982
09/29/2015 | Notify the COGCC 48 hours prior to start of pad construction, rig mobilization, 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). In lieu of standard Form 42 spud notices, submit Form 42 Rulison SAP / Rio Blanco SAP - Spud Notices, specifying the bottom hole location sector and tier.
The operator shall follow all requirements of the Project Rulison Sampling and Analysis Plan (SAP), Revision 3.0, dated July 2010.
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. |
| Final Review | Form: (02A)
400853982
11/05/2015 | Operator shall provide complete well-specific emergency contact information to COGCC via email prior to spudding wells on this pad. Rulison.Submittal@state.co.us |
| Environmental | Form: (04)
401229366
03/13/2017 | IF LOCATIONS ARE IN A SENSITIVE AREA BECAUSE OF ITS PROXIMITY TO SURFACE WATER OPERATOR MUST ENSURE 110 PERCENT SECONDARY CONTAINMENT FOR ANY VOLUME OF FLUIDS CONTAINED AT THE WATER HANDLING FACILITY SITE DURING NATURAL GAS DEVELOPMENT ACTIVITIES AND 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. |
| Environmental | Form: (04)
401229366
03/13/2017 | OPERATOR MUST IMPLEMENT BEST MANAGEMENT PRACTICES TO CONTAIN ANY UNINTENTIONAL RELEASE OF FLUIDS, INCLUDING ANY FLUIDS CONVEYED VIA TEMPORARY SURFACE PIPELINES. |
| Environmental | Form: (04)
401229366
03/13/2017 | OPERATOR PROPOSES THAT THIS FACILITY WILL BE IN OPERATION FOR A PERIOD OF 180 DAYS. THIS TRANSFER CAN BE EXTENDED VIA SUNDRY REQUEST, HOWEVER, SHOULD THE OPERATION OF THIS FACILITY CONTINUE MORE THAN ONE YEAR, A FORM 28 SHALL BE SUBMITTED AND APPROVED BEFORE THE ONE-YEAR ANNIVERSARY DATE OF THE FIRST USE OF THE TRANSFER FACIITY/LOCATION. |
| Environmental | Form: (04)
401229366
03/13/2017 | TERMINATION OF ACITIVITES: BOTH CAERUS AND TEP SHALL NOTIFY THE COGCC VIA SUNDRY IMMEDIATELY UPON TERMINATION OF ACTIVITIES. |
| Environmental | Form: (04)
401229366
03/13/2017 | CAERUS AND TEP WILL EACH SEPERATELY SUBMIT AN ANNUAL REPORT TO THE COGCC SUMMARIXZING THE TRANSFER OF PRODUCTION WATER (BOTH AS TRANSFER AND RECEIVING OPERATOR) DURING THE CALENDAR YEAR AND INCUDING LABORATORY ANALYTICAL RESULTS FOR REPRESENTATIVE SAMPLES(S) OF THE PRODUCTION WATER PROVIDED AS THE TRANSFER/RECIEVER. THE ANNUAL REPORT SHALL BE SUBMITTED ON OR BEFORE THE ANNIVERSAY OF THE FIRST DATE OF TRANSFER. |
| Environmental | Form: (04)
401229366
03/13/2017 | PROVIDE PRECAUTIONS/SECONDARY CONTAINMENT THAT WILL BE INPLACE FOR BOTH BELOW GRADE AND ABOVE GRADE PIPELINES AS THEY CROSS STREAMS, SENSITVE AREAS, OR ALONG SENSITIVE AREAS. |
| Environmental | Form: (04)
401229366
03/13/2017 | PRODUCED WATER OR FLOWBACK WATER OR OTHER EXPLORATION AND PRODUCTION WASTE SHALL NOT BE TEMPORARILY STORED IN MODULAR LARGE VOLUME STORAGE TANKS (MLVSTs). PRODUCED WATER OR FLOWBACK WATER SHALL BE TEMPORAILY STORED IN FRAC TANKS. |
| Environmental | Form: (04)
401229366
03/13/2017 | CAERUS AND TEP WILL EACH SEPERATELY SUBMIT AN ANNUAL REPORT TO THE COGCC SUMMARIZING THE TRANSFER OF PRODUCTION WATER (BOTH AS TRANSFER AND RECEIVING OPERATOR) DURING THE CALENDAR YEAR AND INCUDING LABORATORY ANALYTICAL RESULTS FOR REPRESENTATIVE SAMPLES(S) OF THE PRODUCTION WATER PROVIDED AS THE TRANSFER/RECIEVER. THE ANNUAL REPORT SHALL BE SUBMITTED ON OR BEFORE THE ANNIVERSAY OF THE FIRST DATE OF TRANSFER. PROVIDE FREQUENCY OF PIPELINE INTERGRITY TESTING FOR BOTH BELOW GRADE AND ABOVE GRADE PIPELINES AS PART OF THE ANNUAL REPORT. |
| Environmental | Form: (04)
401229366
03/14/2017 | Within 30-days of this Sundry approval, provide detail of the temporary surface water line(s) including at a minimum diameter, construction mateiral and thickness, integrity testing prior to placing the line(s) in service, duration that the line(s) will be in service and in place, monitor points, valve locations, booster pump locations (if any), and if the line(s) can remotely be shut in. |
| Environmental | Form: (04)
401229366
03/14/2017 | Within 30-days of this Sundry approval provide frequency or schedule for monitoring the temporary surface water line(s) that will be used to convey fluids for this transfer. |