| OGLA | Form: (02A)
400598395
07/16/2014 | 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 using Form 42 (the appropriate COGCC individuals will automatically be email notified, including the LGD for hydraulic stimulation operations). |
| OGLA | Form: (02A)
400598395
07/16/2014 | 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 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 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 enforcing established speed limits on private roads, to reduce fugitive dust and coating of vegetation and deposition in water sources. |
| OGLA | Form: (02A)
400598395
07/16/2014 | 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, the drill cuttings must also meet the applicable standards of table 910-1.
If the wells are to be hydraulically stimulated, 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)
400598395
07/16/2014 | 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 (if installed) and following any reconfiguration of the pipeline network. |
| OGLA | Form: (02A)
400958033
02/09/2016 | A closed loop system must be implemented during drilling. All cuttings generated during drilling of the horizintal portion of the wellbore through the oil-producing zone must be kept in containers, a lined cuttings trench, or on a lined/bermed portion of the well pad; prior to amending and final disposition. The moisture content of any drill cuttings in a cuttings trench 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). All 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.
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)
400958033
02/09/2016 | Berms or other containment devices shall be constructed to be sufficiently impervious (corrugated steel with poly liner or equivalent protection) to contain any spilled or released material around permanent crude oil and produced water storage tanks. |
| OGLA | Form: (02A)
400958033
02/09/2016 | Operator must adhere to all COAs that were previously agreed to by EE3 for this location - OGCC ID#414127 (previously submitted and approved [10-31-14] Form 2A#400598395). These include notification, fluid containment, spill/release BMPs, sediment and dust control access road, cuttings low moisture content, flowback to tanks, and pipeline testing. |