| OGLA | Form: (02A)
400618998
03/18/2015 | Notify the COGCC 48 hours prior to start of pad reconstruction/regrading, rig mobilization, spud, start of hydraulic stimulation operations, start of flowback operations (if different than hydraulic stimulation), and pipeline testing using Form 42 (the appropriate COGCC individuals will automatically be email notified, including the LGD for hydraulic stimulation operations). |
| OGLA | Form: (02A)
400618998
03/18/2015 | Operator must ensure secondary containment for any volume of fluids contained at 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 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 significant precipitation events), and maintained in good condition.
The access road will be maintained as to not allow any sediment to migrate from the access road to nearby surface water or any drainages leading to surface water. |
| OGLA | Form: (02A)
400618998
03/18/2015 | As indicated on the drilling mud operations attachment, a closed loop system must be implemented during drilling; or, if a drilling pit is constructed, an amended Form 2A must be submitted and a Form 15 submitted if operator plans on using either oil based mud or high chloride/TDS mud. The pit must be lined. All cuttings generated during drilling with oil based mud or high chloride/TDS mud must be kept in the lined drilling pit (if permitted and constructed), tanks/containers, or placed on a lined/bermed portion of the well pad; prior to disposition. The moisture content of any drill cuttings in a cuttings containment area or pile shall be 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. Any material which does not meet Table 910-1 criteria will either be manifested and disposed offsite at an approved commercial facility, sent to a permitted WPX Cuttings Management Trench for additional amending (Form 4 Sundry must be submitted and approved), or amended further onsite to comply with Table 910-1. After the drill cuttings have been amended (if necessary or applicable) 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. If operator determines that long-term onsite management of oil based mud or high chloride/TDS mud cuttings is necessary, an approved Form 27 remediation plan will be required. 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. All liners associated with oil based or high chloride/TDS drilling mud and cuttings must be disposed of offsite per CDPHE rules and regulations.
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. |
| OGLA | Form: (02A)
400618998
03/18/2015 | 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.
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 and 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. Inspections shall be conducted by viewing the length of the pipeline; operator will endeavor to minimize surface disturbance during pipeline monitoring. In addition, 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. |