HomeMy WebLinkAboutMathis 6HZ Pad - Activity Notice - Mathis - 3/15/2019Location#:
State of Colorado
Oil and Gas Conservation Commission
1120 Lincoln Street, Suite 801, Denver, Colorado 80203
Phone: (303) 894-2100 Fax: (303) 894-2109
Oil and Gas Location Assessment
FORM
2A
Rev
02/19
New Location Amend Existing Location
This Oil and Gas Location Assessment is to be submitted to the COGCC for approval prior to any ground disturbance
activity associated with oil and gas operations. Approval of this Oil and Gas Location Assessment will allow for the
construction of the below specified Location; however, it does not supersede any land use rules applied by the local
land use authority. Please see the COGCC website at http://cogcc.state.co.us/ for all accompanying information
pertinent this Oil and Gas Location Assessment.
Document Number:
401968859
Expiration Date:
Location ID:
03/15/2019
Date Received:
Refile
This location includes a Rule 306.d.(1)A.ii. variance request.
This location is in a wildlife restricted surface occupancy area.
This location is in a sensitive wildlife habitat area.
CONSULTATION
This location is included in a Comprehensive Drilling Plan. CDP #
info@mathisoil.com
(720) 475-6429
( )
Aiden Durham
email:
Fax:
Phone:
Contact Information
Name:
80222 CO Zip:State:DENVER
6300 E HAMPDEN AVE
MATHIS OIL AND GAS LLC
10727
City:
Address:
Name:
Operator
Operator Number:
FINANCIAL ASSURANCE
Plugging and Abandonment Bond Surety ID (Rule 706):20190038 Gas Facility Surety ID (Rule 711):
Waste Management Surety ID (Rule 704):
This location assessment is included as part of a permit application.
WELD
feet
feet
40.168191
Instrument Operator's Name:
02/19/20191.9
-104.924334
Monty Wallace
Date of Measurement:PDOP Reading:
Longitude:Latitude:
FEL230
2595
4843667W 2N 6 Ground Elevation:Meridian:Township:SENE
from East or West section line
from North or South section lineFootage at surface:
Define a single point as a location reference for the facility location. When the location is to be used as a well site then the point shall be
a well location.
QuarterQuarter:
6HZ Pad Number:Mathis
Section:
County:
Name:
LOCATION IDENTIFICATION
Range:
FNL
Page 1 of 10Date Run: 3/20/2019 Doc [#401968859]
RELATED REMOTE LOCATIONS
(Enter as many Related Locations as necessary. Enter the Form 2A document # only if there is no established COGCC Location ID#)
This proposed Oil and Gas Location is:LOCATION ID #FORM 2A DOC #
Wells
Indicate the number of each type of oil and gas facility planned on location
FACILITIES
12
Drilling Pits
Pump Jacks
Gas or Diesel Motors*
Dehydrator Units*
Oil Tanks*10
Production Pits*
Separators*3
Electric Motors 12
Vapor Recovery Unit*1
Condensate Tanks*
Special Purpose Pits
Injection Pumps*
Electric Generators*
VOC Combustor*
Water Tanks*2
Multi-Well Pits*
Cavity Pumps*2
Fuel Tanks*
Flare*1
Buried Produced Water Vaults*
Modular Large Volume Tanks
Gas Compressors*
LACT Unit*3
Pigging Station*
Other Facility Type Number
heater treater 1
pumps 12
OTHER FACILITIES*
Flowlines from each wellhead to the production manifold will be NPS 3, designed to API/ASME B31.3. These flowlines will be
externally coated and buried from the wellhead area to the production manifold. They are expected to carry three-phase fluids
from the wells. Oil leaving the facility will be by truck until the field is proven to LACT connect it. When LACT connected, the
export pipeline is expected to be NPS 6 and will be built to API/ASME B31.4, and all feeder lines to the LACT will be designed to
API/ASME B31.3. The line is expected to be a single phase hydrocarbon liquid line. Gas from the production operations enters
the local existing DCP gathering system. The line from the production separators to the DCP system will be designed to
API/ASME B31.3. The line from the LACT will be provided by DCP. This line is expected to be a single phase gas line. All piping
on-lease will be designed to API/ASME B31.3 and will range in size from NPS 1 up to NPS 12.
Per Rule 303.b.(3)C, description of all oil, gas, and/or water pipelines:
*Those facilities indicated by an asterisk (*) shall be used to determine the distance from the Production Facility to the nearest
cultural feature on the Cultural Setbacks Tab.
Will a closed loop system be used for drilling fluids:
Is H2S anticipated?
Will salt based mud (>15,000 ppm Cl) be used?
4842
5.15Size of location after interim reclamation in acres:
Will salt sections be encountered during drilling:
Estimated post-construction ground elevation:
Estimated date that interim reclamation will begin:
6.1503/02/2020 Size of disturbed area during construction in acres:Date planned to commence construction:
CONSTRUCTION
09/02/2020
DRILLING PROGRAM
Yes
No
No
Will oil based drilling fluids be used?Yes
No
Page 2 of 10Date Run: 3/20/2019 Doc [#401968859]
Drilling Fluids Disposal:
DRILLING WASTE MANAGEMENT PROGRAM
OFFSITE Commercial DisposalDrilling Fluids Disposal Method:
Cutting Disposal:OFFSITE Commercial DisposalCuttings Disposal Method:
Other Disposal Description:
Please See Waste Management Plan Attached.
Beneficial reuse or land application plan submitted?No
Reuse Facility ID:or Document Number:
Centralized E&P Waste Management Facility ID, if applicable:
The right to construct this Oil and Gas Location is granted by:
is the applicant
has signed the Oil and Gas Lease
is committed to an oil and Gas Lease
is the mineral ownerCheck all that apply. The Surface Owner:
IndianFederalStateFee
IndianFederalStateFee
80302Zip:COState:
Boulder
Suite 314-C
1942 Broadway
Denmore, LLC
Email:
Fax:
Phone:
The Mineral Owner beneath this Oil and Gas Location is:
Surface Owner:
City:
Address:
Address:
Name:
SURFACE & MINERALS & RIGHT TO CONSTRUCT
The Minerals beneath this Oil and Gas Location will be developed from or produced to this Oil and Gas Location:Yes
Surface Use Agreement
Surface damage assurance if no agreement is in place:Surface Surety ID:
Date of Rule 306 surface owner consultation 03/05/2019
CURRENT AND FUTURE LAND USE
Other (describe):
Residential
RecreationalTimber
CommercialIndustrial
Rangeland
CRPHay MeadowImproved PastureDry landIrrigated
Subdivided:
Non-Crop Land:
Crop Land:
Current Land Use (Check all that apply):
Other (describe):
Residential
RecreationalTimber
CommercialIndustrial
Rangeland
CRPHay MeadowImproved PastureDry landIrrigated
Subdivided:
Non-Crop Land:
Crop Land:
Future Land Use (Check all that apply):
Page 3 of 10Date Run: 3/20/2019 Doc [#401968859]
Provide the distance to the nearest cultural feature as measured from Wells or
Production Facilities onsite.
Building:524 Feet
Building Unit:524 Feet
High Occupancy Building Unit:5280 Feet
Designated Outside Activity Area:5280 Feet
Public Road:221 Feet
Above Ground Utility:200 Feet
Railroad:5280 Feet
Property Line:230 Feet
INSTRUCTIONS:
- All measurements shall be provided from
center of nearest Well or edge of nearest
Production Facility to nearest of each
cultural feature as described in Rule 303.b.
(3)A.
- Enter 5280 for distance greater than 1
mile.
- Building - nearest building of any type. If
nearest Building is a Building Unit, enter
same distance for both.
- Building Unit, High Occupancy Building
Unit, Designated Outside Activity Area,
School Facility, and Child Care Center – as
defined in 100 Series Rules.
-For measurement purposes only,
Production Facilities should only include
those items with an asterisk(*) on the
Facilities Tab.
CULTURAL DISTANCE INFORMATION
From WELL
347 Feet
347 Feet
5280 Feet
5280 Feet
221 Feet
207 Feet
5280 Feet
240 Feet
From PRODUCTION
FACILITY
School Facility::5280 Feet
School Property Line:5210 Feet
Child Care Center:5280 Feet
5280 Feet
5190 Feet
5280 Feet
SCHOOL SETBACK INFORMATION
Was Notice required under Rule 305.a.(4)?Yes No
Buffer Zone
Exception Zone
Urban Mitigation Area
DESIGNATED SETBACK LOCATION INFORMATION
Check all that apply. This location is within a:
Pre-application Notifications (required if location is within 1,000 feet of a building unit):
Date of Rule 305.a.(1) Urban Mitigation Area Notification to Local Government:
Date of Rule 305.a.(2) Buffer Zone Notification to Building Unit Owners:03/05/2019
- Buffer Zone - as described in Rule 604.a.
(2), within 1,000' of a Building Unit.
- Exception Zone - as described in Rule
604.a.(1), within 500' of a Building Unit.
- Urban Mitigation Area - as defined in 100-
Series Rules.
- Large UMA Facility – as defined in 100-
Series Rules.
FOR MULTI-WELL PADS AND PRODUCTION FACILTIES WITHIN DESIGNATED SETBACK
LOCATIONS ONLY:
&KHFNWKLVER[LIWKLV2LODQG*DV/RFDWLRQKDVRUZLOOKDYH3URGXFWLRQ)DFLOLWLHVWKDWVHUYHPXOWLSOHZHOOV RQ RURIIVLWH DQGWKH
Production Facilities are proposed to be located less than 1,000 feet from a Building Unit. (Pursuant to Rule 604.c.(2)E.i., the operator
must evaluate alternative locations for the Production Facilities that are farther from the Building Unit, and determine whether those
alternative locations were technically feasible and economically practicable for the same proposed development.)
In the space below, explain rationale for siting the multi-well Production Facility(ies) that supports your Rule 604.c.(2)E.i determination.
Attach documentation that supports your determination to this Form 2A.
The parcel owner of the proposed Mathis 6HZ Pad owns the only bulding and building unit within 1000' of the proposed oil and gas
location. Moving the location further to the north would place the location less than 1000' from the adjacent building unit. Moving the
pad location to the south and west would not be technically feasible for drilling the northern laterals. The pad is located as east as
possible constrained by the public roadway.
By checking this box, I certify that no alternative placements for the Production Facilities, farther from the nearest Building Unit, were
available based on the analysis conducted pursuant to Rule 604.c.(2)E.i.
SOIL
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List all soil map units that occur within the proposed location. attach the National Resource Conservation Service (NRCS)
report showing the "Map Unit Description" report listing the soil typical vertical profile. This data is to used when
segregating topsoil.
Other (describe):
Alpine (above timberline)
Wetlands Aquatic (Bullrush, Sedge, Cattail, Arrowhead)
Forest Land (Spruce, Fir, Ponderosa Pine, Lodgepole Pine, Juniper, Pinyon, Aspen)
Mountain Riparian (Cottonwood, Willow, Blue Spruce)
Plains Riparian (Cottonwood, Willow, Aspen, Maple, Poplar, Russian Olive, Tamarisk)
Shrub Land (Mahogany, Oak, Sage, Serviceberry, Chokecherry)
Native Grassland (Bluestem, Grama, Wheatgrass, Buffalograss, Fescue, Oatgrass, Brome)
Disturbed Grassland (Cactus, Yucca, Cheatgrass, Rye)
Check all plant communities that exist in the disturbed area.
List individual species:
NoYes
Date of observation:field observationNRCS or,Plant species from:
Are noxious weeds present:
Complete this section only if any portion of the disturbed area of the location's current land use is on non-crop land.
PLANT COMMUNITY:
NRCS Map Unit Name:
Vona loamy sand, 0 to 3 percent slopesNRCS Map Unit Name:
Vona loamy sand, 3 to 5 percent slopes
The required information can be obtained from the NRCS web site at http://soildatamart.nrcs.usda.org/ or from the
COGCC web site GIS Online map page found at http://colorado.gov/cogcc. Instructions are provided within the COGCC
web site help section.
NRCS Map Unit Name:
Page 5 of 10Date Run: 3/20/2019 Doc [#401968859]
No
WATER RESOURCES
Is this a sensitive area:No Yes
Distance to nearest
downgradient surface water feature:
water well:
1520 Feet
Feet
Estimated depth to ground water at Oil and Gas Location 72 Feet
Basis for depth to groundwater and sensitive area determination:
Distance to nearest water well is owned by Arlo Boda with the Permit number 78835- receipt number 9065535. This water well
was used to determine depth to groundwater.
Is the location in a riparian area:No Yes
Was an Army Corps of Engineers Section 404 permit filed No Yes If yes attach permit.
Is the location within a Rule 317B Surface Water Supply Area buffer
zone:
1130
If the location is within a Rule 317B Surface Water Supply Area buffer have all public water supply systems
within 15 miles been notified:
GROUNDWATER BASELINE SAMPLING AND MONITORING AND WATER WELL SAMPLING
Water well sampling required per Rule 318A
Is the Location within a
Floodplain?
No Yes Floodplain Data Sources Reviewed (check all that apply)
Federal (FEMA)
State
County
Local
Other
DESIGNATED SETBACK LOCATION EXCEPTIONS
Check all that apply:
Rule 604.a.(1)A. Exception Zone (within 500’ of a Building Unit) and is in an Urban Mitigation Area
Rule 604.b.(1)A. Exception Location (existing or approved Oil & Gas Location now within a Designated Setback as a result of
Rule 604.b.(1)B. Exception Location (existing or approved Oil & Gas Location is within a Designated Setback due to Building Unit
construction after Location approval)
Rule 604.b.(2) Exception Location (SUA or site-specific development plan executed on or before August 1, 2013)
Rule 604.a.)
WILDLIFE
This location is included in a Wildlife Mitigation Plan
This location was subject to a pre-consultation meeting with CPW held on
No BMP
CPW Proposed Wildlife BMPs
No BMP
Operator Proposed Wildlife BMPs
Page 6 of 10Date Run: 3/20/2019 Doc [#401968859]
No BMP/COA Type Description
1 Planning A permeant fencing plan will be reviewed by the surface owner and applicant
2 Planning 604c.(2).B. Operator will use a closed loop system for drilling and fluid management.
No pits will be dug.
3 Planning 604c.(2).C. Green Completion: Test separators and associated flow lines and sand
traps shall be installed on-site to accommodate Green completions techniques
pursuant to COGCC Rules. The wells are expected to be connected to gathering
within 60-180 days of completion. Prior to a sales line connection, flowback gas shall
be thermally oxidized in an emissions control device (ECD), which will be installed and
kept in operable condition for least the first 90-days of production pursuant to CDPHE
rules. This ECD shall have an adequate capacity for 1.5 times the largest flow-back
within a 10-mile radius, will be flanged to route gas to other or permanent oxidizing
equipment and shall be provided with the equipment needed to maintain combustion
where noncombustible gases are present.
4 Planning Well heads will be restaked and measured after pad construction.
Best Management Practices
COA Type Description
Conditions Of Approval
All representations, stipulations and conditions of approval stated in this Form 2A for this location shall
constitute representations, stipulations and conditions of approval for any and all subsequent operations on
the location unless this Form 2A is modified by Sundry Notice, Form 4 or an Amended Form 2A.
Rule 604.b.(3) Exception Location (Building Units constructed after August 1, 2013 within setback per an SUA or site-specific
development plan)
ALL exceptions and variances require attached Request Letter(s). Refer to applicable rule for additional required attachments (e.g.
waivers, certifications, SUAs).
Rule 502.b. Variance Request from COGCC Rule or Spacing Order Number
RULE 502.b VARIANCE REQUEST
jdesmond@vanococonsulting.com
Project Manager
03/15/2019
Jack Desmond
COGCC Approved:Director of COGCC Date:
Based on the information provided herein, this Application for Permit-to-Drill complies with COGCC Rules and applicable orders
and is hereby approved.
Title:
Email:Date:
Print Name:
Signed:
I hereby certify that the statements made in this form are, to the best of my knowledge, true, correct and complete.
The Mathis 6HZC #1 is the reference well used for the location identification. The distances for the cultural setbacks were
provided from the nearest proposed well and production facility on the pad.
The parcel owner of the proposed Mathis 6HZ Pad owns the only bulding or building unit within 1000' of the proposed oil
and gas location. The owner has waived the 305.a, 305.c, 306.a, and 306.e notifications and meetings in the attached
305.a.(3) Waiver. We have included this waiver in lieu of a 30 day notification letter.
There are no surface water features within 1000' of the pad location.
Operator will provide a land application Facility # or beneficial reuse ID prior to drilling and disposal of water based
cuttings or fluids via a Form 4 Sundry. The Waste Management Plan attached addresses disposal for both Commercial
and land application procedures following COGCC Rule 907.
Mathis is planning to obtain demolition permits to take down abandoned barns where the pad location is being located.
Comments
OPERATOR COMMENTS AND SUBMITTAL
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5 Traffic control 604c.(2).D. Traffic Plan: Prior to the commencement of operations, the operator will
obtain access and ROW permits per Weld County Code and implement COAs or traffic
control plans as required.
6 Traffic control 604.c (2).E. To reduce footprint, the pad is planned as a multiwell pad. The pad will
have all-weather access and noise mitigation measures (sound walls) will be installed
and removed without disturbing landscape.
7 General Housekeeping Cleanup of trash, scrap, and discarded materials will be conducted at the end of each
workday.
8 General Housekeeping Mud control: when conditions exist that roads are excessively muddy, additional fill
material will be added in order to dehydrate the environment and reduce the amount of
material that is transported from the wells roads and location to off-site areas.
9 Storm Water/Erosion
Control
Stormwater management plans (SWMP) will be in place to address construction,
drilling, and operations associated with CDPHE permits. BMPs for stormwater will be
implemented around the perimeter of the pad prior to or during construction and will
vary according to the location. These BMPs will remain in place and maintained
throughout operations until final reclamation.
10 Material Handling and Spill
Prevention
Drip pans will be used during fueling of equipment to contain spills and leaks. Visual
inspections of pipe and connections will be performed frequently to detect leaks which
will be immediately corrected, repaired and reported to COGCC as required. Spill
prevention Control Countermeasure (SPCC) will be in place to address any possible
spill associated with oil and gas operations.
11 Material Handling and Spill
Prevention
604c.(2).N. Control of Fire Hazards: Mathis and its contractors will employ best
management practices during the drilling and production of its wells and facilities and
will comply with appropriate COGCC rules concerning safety and fire. Company will
ensure that any material that might be deemed a fire hazard will remain no less than
25 feet from the wellhead(s), tanks and separator(s). A County approved Emergency
Response Plan will be created for this site.
12 Material Handling and Spill
Prevention
General housekeeping will consist of neat and orderly storage of materials and fluids.
Wastes will be temporarily stored in sealed containers and regularly collected and
disposed of at offsite, suitable facilities. If spills occur cleanup will be implemented
within 24-48 hours, as appropriate, to minimize any commingling of waste materials
with storm water runoff. Routine maintenance will be limited to fueling and lubrication
of equipment. Drip pans will be used during routine fueling and maintenance to contain
spills or leaks. Any waste product from maintenance will be containerized and
transported offsite for disposal or recycling. There will be no major equipment
overhauls conducted onsite. Equipment will be transported offsite for major overhauls.
Cleanup will consist of patrolling the roadways, access areas, and other work areas to
pick up trash, scrap debris, other discarded materials, and any contaminated soil.
These materials will be disposed of properly.
13 Material Handling and Spill
Prevention
Oil-based drilling fluids (OBDF) will be separated from the cuttings at surface. At the
end of its use on a particular well, the liquid oil-based mud will be reused for additional
drilling operations or it will be returned to then vendor who originally supplied the mud.
Transportation will occur on a daily basis as required to facilitate on ongoing drilling
operations.
Oil-based drill cuttings (OBDC) will be separated from liquid mud onsite and the
cuttings will be temporarily stored onsite in steel bins. Accumulated cuttings will be
transported for permanent disposal to a licensed solid waste disposal facility. The
actual solid waste disposal facility that will be used will depend on geographic
proximity to the well being drilled. Transportation will occur on a daily basis as required
to facilitate ongoing drilling operations.
14 Dust control To prevent dust from becoming a nuisance to the public, water trucks will be utilized to
spread water across any dust problem areas.
15 Construction All newly installed or replaced crude oil and condensate storage tanks shall be
designed, constructed, and maintained in accordance with National Fire Protection
Association (NFPA) Code 30 (2008 version). MATHIS shall maintain written records
verifying proper design, construction, and maintenance, and shall make these records
available for inspection by the Director. Only the 2008 version of NFPA Code 30
applies to this rule.
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16 Construction All access roads are designed, constructed, and maintained such that heavy
equipment, including emergency response vehicles, can readily access and exit the
location. The pad has all weather access roads to allow for operator and emergency
response.
17 Noise mitigation Operator will consult with owners of residents and occupied structures and other
stakeholders to reduce impact of noise and light during drilling and completion
operations. The direction of prevailing winds is considered when planning the location
in order to mitigate odor and noise from being a nuisance to the surrounding residents
and occupied structures. In order to minimize sound levels during drilling operations at
nearby residences, rig generators will be located as far as possible from the residence
by rig orientation. Rig lighting will also be directed away from residential units. As
necessary, temporary straw bale walls or sound walls will be constructed to dampen
noise in the direction of residential units.
18 Emissions mitigation Test separators and associated flow lines, sand traps and emission control systems
shall be installed on-site to accommodate green completions techniques. When
commercial quantities of salable quality gas are achieved at each well, the gas shall be
immediately directed to a sales line or shut in and conserved. If a sales line is
unavailable or other conditions prevent placing the gas into a sales line, the operator
shall not produce the wells without an approved variance per Rule 805.b.(3)C.
19 Emissions mitigation 604c.(2} F. Leak Detection Plan: Mathis personnel will conduct weekly Audio, Visual
and Olfactory (AVO) inspections of well heads, separation equipment, tanks, valves,
fittings and thief hatches to identify potential leaks and correct promptly. Once per
month personnel will conduct additional inspections of facilities with a FLIR camera to
ensure no leaks from well heads, separation equipment, tanks valves, fittings, thief
hatches, and other potential sources of fugitive emissions.
20 Odor mitigation Hydrocarbon odors from production facilities are minimized and eliminated by keeping
produced fluid hydrocarbons and natural gas contained within pipes, separators, tanks,
and combustors. All tanks will be sealed with thief hatches and gaskets. Tank vapors
are captured with properly sized piping and combustors.
Total: 20 comment(s)
User Group Comment Comment Date
Permit Passed completeness.03/19/2019
Permit Referred to OGLA supervisor for buffer zone review.03/18/2019
Permit •Returned to Draft at Operator's Request.03/15/2019
Total: 3 comment(s)
General Comments
Attachment Check List
Att Doc Num Name
401968859 FORM 2A SUBMITTED
401968873 ACCESS ROAD MAP
401968874 LOCATION DRAWING
401968878 LOCATION PICTURES
401968880 RULE 305.a.(3) EVIDENCE OF COMPLIANCE
401968905 NRCS MAP UNIT DESC
401968906 NRCS MAP UNIT DESC
401971699 FACILITY LAYOUT DRAWING
401973148 SURFACE AGRMT/SURETY
401973168 WASTE MANAGEMENT PLAN
401974543 MULTI-WELL PLAN
Total Attach: 11 Files
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Public Comments
No public comments were received on this application during the comment period.
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