| OGLA | Form: (02A)
401380795
01/02/2018 | Operator shall pressure test pipelines (flowlines from wellheads to separators 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, and tested annually, unless agreed to by both parties that the flowlines can be managed under an approved COGCC variance. |
| OGLA | Form: (02A)
401380795
01/02/2018 | 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. The operator has indicated in the ‘DRILLING WASTE MANAGEMENT PROGRAM SECTION’ of the Form 2A; that ‘Cuttings Disposal’ will be “OFFSITE” and that the ‘Cuttings Disposal Method’ will be “Beneficial reuse”, ‘Other Disposal Description’ as “PLEASE SEE ATTACHED WASTE MANAGEMENT PLAN”. Any proposed offsite disposal or beneficial reuse of cuttings to another oil and gas location shall not occur until approval of a Form 4 Sundry Notice specifying disposal or beneficial reuse location and cuttings material sampling and characterization methods. A Form 4 Sundry Notice must also be submitted for any of the WBM drill cuttings that will remain on the well pad location and must be sampled and meet the applicable standards of Table 910-1.
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 or storage vessel; 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.
Potential odors associated with the completions process and/or with long term production operations must be controlled/mitigated. |
| OGLA | Form: (02A)
401380795
01/02/2018 | Operator must ensure secondary containment for any volume of fluids contained at the well site during drilling and completion operations; additional stormwater controls may be required for the existing well pad area of this oil and gas location.
Strategically apply fugitive dust control measures to reduce fugitive dust and coating of vegetation and deposition in water sources. |
| OGLA | Form: (02A)
401380795
01/02/2018 | 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 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 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; permanent buried take away pipelines; 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. |