| OGLA | Form: (02A)
400877885
02/08/2016 | Operator shall pressure test pipelines (flowlines from wellhead to separator to 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. All permanent flowlines from wellhead to separator and from the separator to the tanks will also be pressure tested annually. |
| OGLA | Form: (02A)
400877885
02/08/2016 | A closed loop system (which operator has indicated on the Form 2A) must be implemented during drilling.
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 or reuse of drill cuttings to another oil and gas location shall occur without prior approval of a revised Waste Management Plan (submitted via a Form 4 Sundry Notice) and/or a Beneficial Reuse Plan specifying disposal/reuse location and waste characterization method. 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). Any liners associated with drilling mud and drill cuttings must be disposed of offsite per CDPHE rules and regulations.
If operator changes disposal options for drill cuttings, then a “Waste Management Plan” will be required (submitted via a Form 4 Sundry Notice; detailing cuttings sampling, amending where the cuttings will be placed on this location). All water/bentonite-based mud- (WBM-) generated 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 be representatively sampled (to be determined by the operator), analyzed in accordance with the rules, and meet the concentration levels listed in Table 910-1.
If operator determines that long-term (beyond the timeframe allowed for interim reclamation) onsite management of WBM-generated drill cuttings is necessary, a Form 27 remediation plan (submitted via a Form 4 Sundry Notice; detailing amendment procedures and how and where these cuttings will be reused at this location) will be required. After the drill cuttings have been amended to meet the levels listed in Table 910-1, and placed/reused on the well pad, sampling frequency (to be determined by the operator) of these drill cuttings shall be representative of the material left on location.
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.
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)
400877885
02/08/2016 | Operator must ensure secondary containment for any volume of fluids contained at the well site during drilling and completion 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 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. |
| OGLA | Form: (02A)
400877885
02/08/2016 | In addition to the notifications required by COGCC listed in the Northwest Notification Policy 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. |
| OGLA | Form: (02A)
401738274
09/25/2018 | Material Handling and Spill Prevention: The following COA will apply:
• All onsite flowlines and pipelines and offsite pipelines will be constructed, maintained, registered, and integrity tested in accordance with the new COGCC 1100 Series Rules (1101, 1102, 1103, and 1104) updated on May 1, 2018.
• Any temporary surface lines used for hydraulic stimulation and/or flowback operations will be pressure tested and will require to be registered if in use for longer than 12 months. |
| OGLA | Form: (02A)
401738274
09/25/2018 | Emissions Mitigation: The following COAs will apply:
• Operator shall comply with COGCC’s current NOTICE TO OPERATORS: Rule 912. VENTING OR FLARING PRODUCED NATURAL GAS – STATEWIDE. |
| OGLA | Form: (02A)
401738274
09/25/2018 | Drilling/Completions: The following COAs will apply:
• All cuttings generated during drilling with oil based mud (OBM) must be kept in tanks or containers or placed on a lined and bermed portion of the well pad prior to disposition.
• The moisture content of all cuttings managed onsite or transported offsite shall be kept as low as practicable to prevent accumulation of liquids greater than de minimis amounts.
• Light sources will be directed downwards and away from occupied structures.
• Flowback and stimulation fluids must be sent to enclosed tanks, separators, or other containment or 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. |
| OGLA | Form: (02A)
401738274
09/25/2018 | Construction: The following COAs will apply:
• Secondary containment for flowback storage tanks shall meet the requirements of Rule 906.d.(1).
• No construction or routine maintenance activities will be performed during periods when the soil is too wet to adequately support construction equipment.
• Keep well site location, road and pipeline easement free of noxious weeds, litter and debris. |
| OGLA | Form: (02A)
401738274
09/25/2018 | Planning: The following COA will apply:
•Since oil and produced water storage tanks are not planned to be constructed on the nearby well pad location(s), operator shall submit a scaled as-built drawing (plan view with distances) of this central tank battery facility location, showing onsite flowlines, offsite and onsite pipelines, truck loadout (if constructed), and production facilities (separators, combustor, etc.) and the nearby well pad location(s) to which the oil and produced water will be sent from via underground pipelines, showing wellheads, onsite flowlines, offsite pipelines, pumping jacks, oil and produced water storage tanks, and other production facilities, within 60 calendar days of construction of the production equipment on all locations. |
| OGLA | Form: (02A)
401738274
10/27/2018 | Planning: The following COA will apply:
• Provide Notices as described in the most current version of the Northwest Notification Policy. |
| OGLA | Form: (04)
402018516
04/23/2019 | Prior to first use of the combustors, operator shall have received any required governmental approvals for gas combustion at this location or wells. |
| OGLA | Form: (02A)
402017579
11/07/2019 | • Provide Notices as described in the most current version of the Northwest Notification Policy.
• Prior to first use of the combustors, operator shall have received any required governmental approvals for gas combustion at this location or wells.
• Since oil and produced water will be sent offsite from this well pad (Surprise 0680 S9 Location OGCC ID #445005), operator shall submit a scaled as-built drawing (plan view with distances) of this well pad from which the oil and produced water will be sent from via underground pipelines (showing wellheads, storage tanks, onsite flowlines, offsite pipelines, pumping jacks, and any other ancilliary equipment). The product receiving location (Surprise Central Facility OGCC ID #436676) will also require a scaled as-built drawing (plan view with distances), showing offsite and onsite pipelines, truck load out (if constructed), and production facilities (separators, combustors, heater treaters, etc.) within 60 calendar days of construction of the production equipment on location. |
| OGLA | Form: (04)
403509180
10/11/2023 | Operator will submit the annual gas analysis via F4 Sundry within 60 days of approval of this Form 4 Sundry. |