COAs

Facility Type	Facility ID/ API	Facility Name/ Number	Operator Name/ Number	Status	Field Name/ Number	Location	Location ID	Related Facilities
LOCATION	413754	HEBRON/MARR 7	FULCRUM ENERGY OPERATING LLC 10805	AC 10/1/2025	UNNAMED 85251	JACKSON 057 NWNE 7 7N80W 6	413754

COGIS - Conditions of Approval Results

Type	Source Document	Conditions of Approval
OGLA	Form: (02A) 400392924 06/09/2013	SITE SPECIFIC COAs: Notify the COGCC 48 hours prior to start of pad construction, rig mobilization, spud, and start of hydraulic stimulation operations using Form 42 (the appropriate COGCC individuals will automatically be email notified, including the LGD for hydraulic stimulation operations). Reserve pit, or any other pit used to contain/hold fluids, if constructed, must be lined or a closed loop system (as indicated by operator on the Form 2A Permit application) must be implemented during drilling. The access road will be constructed to prevent sediment migration from the access road to nearby surface water or any drainages leading to other nearby surface waters. 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. Operator must ensure 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. The moisture content of any 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 the drill cuttings are to be left onsite, they must also meet the applicable standards of table 910-1. If the well is to be hydraulically stimulated, then 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 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. Berms or other containment devices shall be constructed to be sufficiently impervious (preferably corrugated steel with poly liner) to contain any spilled or released material around crude oil, condensate, and produced water storage tanks.
OGLA	Form: (02A) 400392924 06/09/2013	BASELINE GROUNDWATER/SURFACE WATER TESTING COA: Operator shall comply with Rule 609. STATEWIDE GROUNDWATER BASELINE SAMPLING AND MONITORING.
OGLA	Form: (02A) 400668702 09/17/2014	PREVIOUS FORM 2A#400392924, OGCC ID#413754 GENERAL SITE COAs: Notify the COGCC 48 hours prior to start of pad construction, rig mobilization, spud, and start of hydraulic stimulation operations using Form 42 (the appropriate COGCC individuals will automatically be email notified, including the LGD for hydraulic stimulation operations). Reserve pit, or any other pit used to contain/hold fluids, if constructed, must be lined or a closed loop system (as indicated by operator on the Form 2A Permit application) must be implemented during drilling. The access road will be constructed and maintained to prevent sediment migration from the access road to nearby surface water or any drainages leading to other nearby surface waters. 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. Operator must ensure 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. The moisture content of any 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 the drill cuttings are to be left onsite, they must also meet the applicable standards of table 910-1. If the well is to be hydraulically stimulated, then 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 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. Berms or other containment devices shall be constructed to be sufficiently impervious (preferably corrugated steel with poly liner) to contain any spilled or released material around crude oil, condensate, and produced water storage tanks.
OGLA	Form: (02A) 400668702 09/17/2014	Notify the COGCC 48 hours prior to start of pad reconstruction/regrading, 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) 400668702 09/17/2014	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) 401048311 06/22/2016	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, or managed under an approved COGCC variance. 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.
OGLA	Form: (02A) 401048311 06/22/2016	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 “COMMERCIAL DISPOSAL” (as shown in the ‘DRILLING WASTE MANAGEMENT PROGRAM SECTION’ of the Form 2A#401011921; OGCC ID#438250). 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 drill cuttings management and disposal at this location will require submittal (via a Form 4 Sundry Notice) and approval of a Waste Management Plan detailing the changes (specifying cuttings characterization methods, cuttings management, amendment, and onsite disposal location[s]). 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 of a Waste Management Plan (submitted via a Form 4 Sundry Notice) specifying disposal location and waste characterization method. Operator has indicated that commercial disposal of drill cuttings will be the method of disposal for all cuttings. Flowback and stimulation fluids must be sent to enclosed tanks, separators, or other containment/filtering equipment before the fluids can be placed into any pipeline storage vessel, or other open top containment located on the well pad; or into tanker trucks for offsite disposal. No open top tanks can be used for initial flowback fluids containment. 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. No additional downgradient berming is required if operator constructs a sufficiently sized perimeter berm. Potential odors associated with the completions process and/or 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) 401048311 06/22/2016	Operator must ensure secondary containment for any volume of fluids contained at the 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 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 drilling operations, as well as all fluids contained in temporary frac tanks during completion operations. The access road will be constructed and maintained to prevent sediment migration from the access road to nearby surface water or any drainages leading to other nearby surface waters. 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 (preferably corrugated steel with poly liner or equivalent protection) to contain any spilled or released material around crude oil, condensate, and produced water storage tanks.
OGLA	Form: (02A) 401048311 06/22/2016	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 install a pit liner, 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; b. Notice of Spud; and c. Notice of Construction or Major Change); operator shall notify the COGCC 48 hours prior to 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.

COGIS - Best Management Practice Results

BMP Type	Source Document	Best Management Practices
Drilling/Completion Operations	Form: (02A ) 400392924 7/21/2013	1) EE3 LLC will use hospital grade mufflers for compressors, pump jacks, or other engines necessary to run operations at the site. Mufflers will be pointed upward to dissipate potential vibration. 2) EE3 LLC will restore appropriate sagebrush species or subspecies on disturbed sagebrush sites, if agreeable by the landowner. EE3 LLC will use locally collected seed for reseeding where possible. 3) EE3 LLC will follow COGCC Rule 1204 a-1 for dumpsters and trash receptacles. 4) EE3 LLC will utilize a closed loop system to drill the referenced well. 5) EE3 LLC will attempt to reduce truck traffic to each well pad site.
Wildlife	Form: (02A ) 400392924 7/21/2013	1) Where drilling/completion activities occur within 4 miles of greater sage-grouse leks or within other mapped greater sage-grouse breeding or summer habitat, EE3 LLC will conduct these activities outside the period between March 1 and June 30. 2) EE3 LLC will establish company guidelines to minimize wildlife mortality from vehicle collisions on roads.
Traffic control	Form: (02A ) 400668702 10/25/2014	Access roads. The access road is already in place and will be maintained for access at all times.
General Housekeeping	Form: (02A ) 400668702 10/25/2014	Removal of surface trash. All trash, debris and material not intrinsic to the operation of the oil and gas facility shall be removed and legally disposed of as is applicable.
Wildlife	Form: (02A ) 400668702 10/25/2014	1. Where oil and gas activities must occur within 4 miles of greater sage-grouse leks or within other mapped greater sage-grouse breeding or summer habitat, conduct these activities outside the period between March 1 and June 30. 2. Use hospital grade mufflers for compressors, pump jacks, or other motors necessary to run operations at the site. Mufflers will be pointed upward to dissipate potential vibration. 3. Establish company guidelines to minimize wildlife mortality from vehicle collisions on roads.
Drilling/Completion Operations	Form: (02A ) 400668702 10/25/2014	Closed Loop Drilling Systems – Pit Restrictions. Not applicable; a closed-loop system will be used for drilling.
Drilling/Completion Operations	Form: (02A ) 400668702 10/25/2014	Green Completions – Emission Control Systems. Test separators and associated flow lines and sand traps shall be installed on-site to accommodate Green completions techniques pursuant to COGCC Rules. In the anticipated absence of a viable gas sales line, the flow-back gas shall be thermally oxidized in an emissions control device (ECD), which will be installed and kept in operable condition for least the first 90-days of production pursuant to CDPHE rules. This ECD shall have an adequate capacity for 1.5 times the largest flow-back within a 10 mile radius, will be flanged to route gas to other or permanent oxidizing equipment and shall be provided with the equipment needed to maintain combustion where non-combustible gases are present.
Drilling/Completion Operations	Form: (02A ) 400668702 10/25/2014	Blowout preventer equipment (“BOPE”). A double ram and annular preventer will be used during drilling. At least the drilling company shall have a valid well blowout prevention certifications.
Drilling/Completion Operations	Form: (02A ) 400668702 10/25/2014	BOPE for well servicing operations. Adequate BOP equipment shall be used. Stabbing valves shall be installed in the event of reverse circulation and shall be prior tested with low and high pressure fluid.
Drilling/Completion Operations	Form: (02A ) 400668702 10/25/2014	Control of fire hazards. All materials which are considered fire hazards shall be a minimum of 25’ from the wellhead tanks or separators. Electrical equipment shall comply with API RP 500 and will comply with the current national electrical code. An emergency response plan has been generated for this site.
Drilling/Completion Operations	Form: (02A ) 400668702 10/25/2014	Guy line anchors. All guy line anchors shall be brightly marked pursuant to Rule 604.c (2)Q.
Final Reclamation	Form: (02A ) 400668702 10/25/2014	Well site cleared. Within 90-day subsequent to the time of plugging and abandonment of the entire site, superfluous debris and equipment shall be removed from the site.
Final Reclamation	Form: (02A ) 400668702 10/25/2014	Identification of plugged and abandoned wells. P&A’d wells shall be identified pursuant to 319.a.(5).
Traffic control	Form: (02A ) 401048311 6/24/2016	Access roads. The access road is already in place and will be maintained for access at all times.
General Housekeeping	Form: (02A ) 401048311 6/24/2016	Removal of surface trash. All trash, debris and material not intrinsic to the operation of the oil and gas facility shall be removed and legally disposed of as is applicable.
Wildlife	Form: (02A ) 401048311 6/24/2016	1. Where oil and gas activities must occur within 4 miles of greater sage-grouse leks or within other mapped greater sage-grouse breeding or summer habitat, conduct these activities outside the period between March 1 and June 30. 2. Use hospital grade mufflers for compressors, pump jacks or other motors necessary to run operations at the site (unless electric equipment used). Mufflers will be pointed upward to dissipate potential vibration. 3. Establish company guidelines to minimize wildlife mortality from vehicle collisions on roads. 4. Operator will follow COGCC Rule 1204 a-1 for dumpsters and trash receptacles.
Storm Water/Erosion Control	Form: (02A ) 401048311 6/24/2016	SandRidge Exploration & Production LLC will implement a storm water and erosion control plan to prevent sedimentation and erosion.
Drilling/Completion Operations	Form: (02A ) 401048311 6/24/2016	One of the first wells drilled on the pad will be logged with an open-hole resistivity log and gamma ray log from kick off point to surface. All wells on the pad will have a cement bond log with gamma ray run on production casing (or on intermediate casing if production liner is run) into the surface casing. The form 5 completion report for each well drilled on this pad will have all logs ran on that well noted and attached. If no logs were run, that also will be clearly noted on that well's form 5.
Drilling/Completion Operations	Form: (02A ) 401048311 6/24/2016	Operator will utilize a closed loop system to drill the referenced well. Operator will attempt to reduce truck traffic to each well pad site. Blowout preventer equipment (“BOPE”). A double ram and annular preventer will be used during drilling. At least the drilling company shall have a valid well blowout prevention certifications. BOPE for well servicing operations. Adequate BOP equipment shall be used. Stabbing valves shall be installed in the event of reverse circulation and shall be prior tested with low and high pressure fluid. Green Completions – Emission Control Systems. Test separators and associated flow lines and sand traps shall be installed on-site to accommodate Green completions techniques pursuant to COGCC Rules. In the anticipated absence of a viable gas sales line, the flow-back gas shall be thermally oxidized in an emissions control device (ECD), which will be installed and kept in operable condition for least the first 90-days of production pursuant to CDPHE rules. This ECD shall have an adequate capacity for 1.5 times the largest flow-back within a 10 mile radius, will be flanged to route gas to other or permanent oxidizing equipment and shall be provided with the equipment needed to maintain combustion where non-combustible gases are present. Control of fire hazards. All materials which are considered fire hazards shall be a minimum of 25’ from the wellhead tanks or separators. Electrical equipment shall comply with API RP 500 and will comply with the current national electrical code. An emergency response plan has been generated for this site. Guy line anchors. All guy line anchors shall be brightly marked pursuant to Rule 604.c,(2).Q. Co-locate gas and water gathering lines whenever feasible and mitigate any erosion problems that arise due to the construction of any pipeline(s).
Interim Reclamation	Form: (02A ) 401048311 6/24/2016	Operator will restore appropriate sagebrush species or subspecies on disturbed sagebrush sites, if agreeable by the landowner. Operator will use locally collected seed for reseeding where possible.
Final Reclamation	Form: (02A ) 401048311 6/24/2016	Well site cleared. Within 90-day subsequent to the time of plugging and abandonment of the entire site, superfluous debris and equipment shall be removed from the site. Identification of plugged and abandoned wells. P&A’d wells shall be identified pursuant to 319.a.(5).

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