COGIS - COA/BMP Information

URSA OPERATING COMPANY LLC           VALLEY FARMS O 43C-09-06-92           Well API # 05-045-22975           Status: XX        Status Date: 08/15/2017           Location ID #:436004       LOT 11 10 6S 92W GARFIELD

COGIS - Conditions of Approval
COA Search Results - 7 record(s) returned.
Source
Document
Conditions of Approval
Form: (02 )
400874032
08/27/2015
(1) Operator shall comply with the most current revision of the Northwest Notification Policy. See attached notice. (2) Operator shall comply with the most current revision of the Garfield County Rulison Field Notice to Operators, with the following exception: All field notice requirements specified in that Notice to Operators are superseded by the requirements of the most current revision of the Northwest Colorado Notification Policy (see Condition of Approval #1). See attached notice. (3) Operator shall comply with the most current revision of the Mamm Creek Field Notice to Operators, with the following exception: All field notice requirements specified in that Notice to Operators are superseded by the requirements of the most current revision of the Northwest Colorado Notification Policy (see Condition of Approval #1). See attached notice. (4) Operator shall comply with the Notice to Operators Drilling Wells in the Buzzard, Mamm Creek, and Rulison fields, Garfield County and Mesa County – Procedures and Submittal Requirements for Compliance with COGCC Order Nos. 1-107, 139-56, 191-22, and 369-2 (July 8, 2010). See attached notice. (5) Operator shall provide cement coverage from the production casing shoe to a minimum of 200' above all Mesa Verde Group (and Ohio Creek Formation, if present) oil, gas, and water-bearing sandstone and coalbed formations. Verify production casing cement coverage with a cement bond log. This requirement shall supersede the top of cement requirements in the Mamm Creek Field Notice to Operators.
Form: (02 )
401355677
03/15/2019
1)Operator shall comply with the most current revision of the Northwest Notification Policy. 2)Operator shall comply with the most current revision of the Garfield County Rulison Field Notice to Operators, with the following exception: All field notice requirements specified in that Notice to Operators are superseded by the requirements of the most current revision of the Northwest Colorado Notification Policy (see Condition of Approval #1). 3)Operator shall comply with the most current revision of the Mamm Creek Field Notice to Operators, with the following exception: All field notice requirements specified in that Notice to Operators are superseded by the requirements of the most current revision of the Northwest Colorado Notification Policy (see Condition of Approval #1). Operator shall submit the primary cement job Cement Bond Log (CBL) with either the Form 4 Sundry Notice - Request to Complete or the Form 5 Drilling Completion Report. 4)Operator shall comply with the Notice to Operators Drilling Wells in the Buzzard, Mamm Creek, and Rulison fields, Garfield County and Mesa County – Procedures and Submittal Requirements for Compliance with COGCC Order Nos. 1-107, 139-56, 191-22, and 369-2 (July 8, 2010). 5)Operator shall provide cement coverage from the production casing shoe (4+1/2" FIRST STRING) to a minimum of 500' above the Lower Wasatch (as defined by COGCC in the report "Casing and Cement Standards for Geologic Isolation Piceance Basin Bradenhead Monitoring Area and Nearby Fields," dated April 18, 2016, COGCC Document No. 2056199, Appendix A Field Scout Cards and Annotated Type Logs) to provide isolation of all Mesaverde Group and underlying formations, if penetrated, the Ohio Creek Formation, and the lower portion of the Wasatch Formation. Verify production casing cement coverage with a cement bond log. This requirement shall supersede the top of cement requirements in the Mamm Creek Field Notice to Operators. 6)The Operator shall monitor the bradenhead pressure of the proposed well and all offset wells under Operator’s control which penetrate the stimulated formation and have a treated interval separation of 300 feet or less. Monitoring shall occur from 24 hours prior to stimulation and shall continue until 24 hours after stimulation is complete. Recording shall be at a frequency of at least once per 24 hours with the capability of recording the maximum pressure observed during each 24 hour period. Operator shall notify COGCC Engineering staff if bradenhead pressures increase by more than 200 psig.
Form: (02 )
401355677
03/15/2019
Operator shall comply with Notice to Operators: Interim Reclamation Procedures for Delayed Operations (dated January 5, 2017).
Form: (02 )
401355677
03/15/2019
This Permit to Drill is approved subject to all the BMP’s and COA’s on the most recently approved Form 2A and any subsequently approved Form 4 for the Oil and Gas Location (Location ID #436004). The most recently approved Form 2A and any subsequent Form 4’s containing applicable COA’s for this location shall be posted onsite during construction, drilling, and completions operations.
Form: (02 )
401355677
03/15/2019
If conductors are preset, operator shall comply with Notice to Operators: Procedures for Preset Conductors (dated September 1, 2016, revised October 6, 2016).
Form: (02 )
401355677
03/15/2019
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. After drilling and completion operations have been completed, if any of the WBM drill cuttings will remain on the well pad location (cuttings management area, the cut portion of the pad, cuttings trench, dry cuttings drilling pit), they must be sampled and 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. 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.
Form: (02 )
401355677
03/15/2019
The COGCC retains its authority to require compliance with the operator provided Best Management Practices (BMPs) and retains its discretion to enforce the BMPs to ensure compliance with the Colorado Oil and Gas Act and COGCC Rules.


COGIS - Best Management Practices
BMPSearch Results - 3 record(s) returned.
Source
Document
BMP TypeBMP
Form: (02 )
400874032
08/27/2015
Drilling/Completion Operations
One of the first wells drilled on the pad will be logged with open-hole Resistivity Log and Gamma Ray Log from TD into the surface casing. 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 on the pad will list all logs run and have those logs attached. The Form 5 for a well without open-hole logs shall clearly state “No open-hole logs were run” and shall clearly identify (by API#, well name & number) the well in which openhole logs were run.
Form: (02 )
401355677
03/15/2019
Planning
Planning: Due to the Location being in a Buffer Zone, the following BMPs will implemented to address potential nuisance issues: • Directional Drilling - Directional drilling will be implemented to avoid the need for additional well pads; reducing habitat loss and fragmentation, noise, and traffic concerns. • Noise - Operator will perform sound monitoring surveys during drilling and completion activities with data collection instruments placed between the Oil and Gas Location and the residential Buildings. Ursa will have a documented process for responding to sound levels that exceed COGCC sound limits. Every phase of operations shall be implemented so that the volume of sound inherently and recurrently generated does not exceed 70 dB(A) from 7:00 AM to 7:00 PM and 65 dB(A) from 7:00 PM to 7:00 AM as measured 350 feet from the edge of the pad. Additional noise monitoring above and beyond COGCC regulations may be conducted if warranted based on public input. Sound barriers may be placed around the generators and drilling equipment, the hydraulic stimulation trucks and equipment, smaller horse power trucks and pumps, and other completions / flowback equipment. • Dust - The pad and access road entrance (immediately adjacent to the well pad) will be graveled to reduce fugitive dust and maintained (through all phase of operations) to prevent sediment migration from the access road to nearby surface water or any drainages or ditches leading to surface water. In addition, operator will have water trucks onsite to reduce fugitive dust and coating of vegetation and deposition in water sources. Water and other dust suppressants are used as required, dependent upon the level of activity, moisture conditions, etc. throughout all phases of operations. Operator shall employ practices for control of fugitive dust caused by other operations, including, but not limited to the use of water and other dust suppressants dependent upon the level of activity and moisture conditions; speed restrictions; and regular road maintenance. Truckloads of dirt, sand, aggregate materials, drilling cuttings, and similar materials will be covered to reduce dust and PM emissions during transport. • Lighting - All lighting, except as demonstrated for safety reasons, shall be directed inward and downward and be shaded in order to prevent direct reflection on adjacent property and residences in the area. LED lights will be used when possible and practical. Workers will be advised when moving light plants to ensure that the light is focused directly on the work being done. The drill rig mast lighting will be downcast and/or shielded to reduce fugitive light outside the well pad. Safety considerations will take precedence. • Odors and Emissions - Odors are seldom related to longterm production. The greatest potential for odors to occur is during the drilling and completion phases of operations (generally a 3 to 4 month period). Operator has incorporated a number of standard operating practices into daily operations to help detect and manage odors which include on-site surveillance by both operator and contractors on a daily basis, filter blankets and controls, using additional tanks and filtering equipment to fully contain potential odors during drilling and completions, newer design screw-down thief hatches, electronic versus manual tank gauging, etc. Well completions will utilize flowback completion technologies and/or flares to reduce odors from plug drillout, and venting of salable and non-salable gas. Combustor controls will be used to mitigate odors from production tanks. • Waste Management - A closed-loop (pitless) drilling system will be used; No cuttings pit will be constructed; cuttings that meet levels in Table 910-1 will be beneficially reused offsite. • Work Hours - Completions will typically be conducted during daylight hours.
Form: (02 )
401355677
03/15/2019
Drilling/Completion Operations
One of the first wells drilled on the pad will be logged with open-hole Resistivity Log and Gamma Ray Log from TD into the surface casing. 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 on the pad will list all logs run and have those logs attached. The Form 5 for a well without open-hole logs shall clearly state “No open-hole logs were run” and shall clearly identify (by API#, well name & number) the well in which open hole logs were run.