HomeMy WebLinkAbout1.00 General Application Materials_PartLPage 3 of 10
another river, intermittent or perennial stream, lake, pond, or wetland and discard rinse
water in an approved disposal facility. Disinfection practices will be repeated prior to
completing work and before moving to the next water body.
During operations associated with the development of the proposed Oil and Gas Location,
freshwater trucks used to support construction, drilling, completion, and production
operations will be cleaned by spraying and soaking the tank cavity and all suction hoses with
water greater than 140° Fahrenheit for at least ten (10) minutes when the tank and/or hoses
have been used previously in another river, intermittent or perennial stream, lake, pond, or
wetland. During drilling operations TEP will only utilize trucks assigned directly to the rig.
All suction hoses associated with the water source will remain in place throughout the
duration of drilling operations. Any hoses switched out will be cleaned using the same
guidelines mentioned above.
3. At new and existing Oil and Gas Locations, Operators will not situate new staging, refueling,
or chemical storage areas within 500 feet of the Ordinary High Water Mark (“OHWM”) of
any river, perennial or intermittent stream, lake, pond, or wetland.
TEP will ensure that all staging, refueling, or chemical storage areas are more than 500 feet
from the OHWM of any river, perennial or intermittent stream, lake, pond, or wetland.
4. To prevent access by wildlife, including birds and bats, Operators will fence and net or
install other CPW-approved exclusion devices on new drilling pits, production pits, and other
pits associated with Oil and Gas Operations that are intended to contain fluids.
There are no drilling pits, production pits, or other pits associated with planned operations on
this oil and gas location.
5. For trenches that are left open for more than 5 consecutive days during construction of
pipelines regulated pursuant to the Commission’s 1100 Series Rules, Operators will install
wildlife escape ramps at a minimum of one ramp per ¼ mile of trench.
TEP will install wildlife escape ramps at a minimum of one ramp per ¼ mile of trench if any
trench is left open for more than 5 consecutive days as required by COGCC regulations.
6. When conducting interim and final reclamation pursuant to Rules 1003 and 1004, Operators
will use CPW-recommended seed mixes for reclamation when consistent with the Surface
Owner’s approval and any local soil conservation district requirements.
TEP will ensure a CPW recommended seed mix is used for interim and final reclamation
when approved by the surface owner.
7. Operators will use CPW-recommended fence designs when consistent with the Surface
Owner’s approval and any Relevant Local Government requirements.
TEP is not planning to install a perimeter fence at this oil and gas location. However, if
fencing is required to prohibit cattle grazing and establish a successful reclamation, TEP will
utilize a CPW recommended fence design.
Page 4 of 10
8. Operators will conduct all vegetation removal necessary for Oil and Gas Operations outside
of the nesting season for migratory birds (April 1 to August 31). For any vegetation removal
that must be scheduled between April 1 to August 31, Operators may implement appropriate
hazing or other exclusion measures prior to April 1 to avoid take of migratory birds. If
hazing or other exclusion measures are not implemented, Operators will conduct pre-
construction nesting migratory bird surveys within the approved disturbance area prior to
any vegetation removal during the nesting season. If active nests are located, Operators will
provide work zone buffers around active nests.
As mentioned in the Plan of Development, TEP has tentatively scheduled construction of the
South Leverich 13-09 pad during November of 2022, which is outside the nesting season for
migratory birds described above. However, if the timing of construction operations changes
and are scheduled to occur during the nesting season, TEP will either implement hazing prior
to April 1, or a pre-construction migratory bird survey will be conducted during the nesting
season to determine if nesting migratory birds are present within the project area. If any
active nests are located, TEP will provide work zone buffers around those active nests as
allowed under Rule 1202.a.(8).
9. Operators will treat drilling pits, production pits, and any other pit associated with Oil and
Gas Operations containing water that provides a medium for breeding mosquitoes with Bti
(Bacillus thuringiensis v. israelensis) or take other effective action to control mosquito larvae
that may spread West Nile virus to wildlife resources. Such treatment will be conducted in a
manner which will not adversely affect aquatic wildlife resources.
There are no drilling pits, production pits, or any other pits planned for construction on this
oil and gas location.
10. Operators will employ the following minimum Best Management Practices on new Oil and
Gas Locations with a working pad surface located between 500 feet and 1000 feet
hydraulically upgradient from a High Priority Habitat identified in Rule 1202.c.(1).Q–S:
a. Contain Flowback and Stimulation Fluids in Tanks that are placed on a Working Pad
Surface in an area with downgradient perimeter berming.
The South Leverich 13-09 pad will include construction of a perimeter berm around the
entire working pad surface of the oil and gas location. Additionally, a drive over berm
will be constructed at the entrance to the oil and gas location. Flowback and Stimulation
Fluid storage tanks will be located on pad inside the pad perimeter berm.
b. Construct lined berms or other lined containment devices pursuant to Rule 603.o around
any new crude oil, condensate, and produced water storage Tanks that are installed after
January 15, 2021.
All proposed produced water tanks and condensate tanks on the South Leverich 13-09
pad will be located within a secondary containment structure designed to meet the
requirements of Rule 603.o.
c. Inspect the Oil and Location on a daily basis, unless the approved Form 2A provides for
different inspection frequency or alternative method of compliance.
Page 5 of 10
TEP is requesting a modified inspection frequency for this oil and gas location.
Inspection at this location will occur daily for the first 6 – 9 months of production
operations. Inspection frequency will then drop to once per week (minimum) for the
remaining life of the wells. The oil and gas location will be equipped with Supervisory
Control and Data Acquisition (SCADA) monitoring technology which enables remote
monitoring of individual wells, produced water / condensate tanks, and other production
facilities on the oil and gas location. Please see the Fluid Leak Detection Plan attached to
the Form 2A for additional details on continuous monitoring.
d. Maintain adequate Spill response equipment at the Oil and Gas Location during drilling
and completion operations.
Spill response equipment will be provided on site during drilling and completion
operations. Additional spill response equipment will be staged at a nearby location that
can be accessed quickly as needed during drilling and completion operations as well as
during long-term production operations.
e. Not construct or utilize any Pits, except that Operators may continue to utilize existing
Pits that were properly permitted, constructed, operated, and maintained in compliance
prior to January 15, 2021.
There are no drilling pits, production pits, or any other pits planned for construction on
this oil and gas location.
Rule 1202.b.: As stated in Rule 1202.b, “operators will bore, rather than trench, flowline and utility
crossings of perennial streams identified as aquatic High Priority Habitat unless the Operator obtains a
signed waiver from CPW and the Director or Commission approves a Form 4 or Form 2A documenting
the relief. When installing culverts or bridges, such structures will not impact or prevent the passage of
fish unless otherwise directed by CPW.”
The proposed natural gas gathering pipeline and produced water pipeline will not cross perennial streams;
therefore, the proposed project complies with Rule 1202.b.
Rule 1202.c.: As stated in Rule 1202.c., “Except as specified pursuant to Rule 1202.c.(2), Operators will
not conduct any new ground disturbance and Well work, including access road and pad construction,
drilling and completion activities, and Flowline/utility corridor clearing and installation activities in the
High Priority Habitats listed in Rule 1202.c.(1).”
New ground disturbance activities for the South Leverich 13-09 OGDP will be limited to reconstruction
and expansion of the South Leverich 13-09 pad, installation of the proposed natural gas pipeline, and
installation of the proposed produced water pipeline.
South Leverich 13-09 Pad: The South Leverich 13-09 pad is not located within High Priority Habitat
listed under Rule 1202.c.(1) and therefore complies with Rule 1202.c.
Proposed Natural Gas Pipeline: New disturbance associated with construction and installation of the
proposed natural gas pipeline will not be located within High Priority Habitat listed under Rule 1202.c.(1)
and therefore complies with Rule 1202.c.
Proposed Produced Water Pipeline: New disturbance associated with construction and installation of the
proposed produced water pipeline will not be located within High Priority Habitat listed under Rule
1202.c.(1) and therefore complies with Rule 1202.c.
Page 6 of 10
CPW CONSULTATION
TEP conducted two (2) pre-application consultation meetings with Colorado Parks and Wildlife (“CPW”)
to discuss the proposed development plan for the South Leverich 13-09 pad and the potential impacts to
wildlife as a result of construction and operations of the proposed facility. The South Leverich 13-09 pad
and associated permanent pipelines are not located within High Priority Habitat. However, based on the
proximity of the oil and gas location to High Priority Habitat, TEP held a pre-application consultation
meeting with CPW to discuss potential impacts associated with the facility and the existing access road.
The first pre-application consultation meeting occurred on April 28, 2021, and was held at the South
Leverich 13-09 pad. This meeting was the initial site review meeting by CPW, which provided CPW with
the opportunity to review the staked oil and gas location and associated pipeline corridors and provide
initial feedback on the development plan. The second pre-application consultation meeting occurred on
June 23, 2022. During this meeting TEP provided updates to the proposed development plan, reviewed
the draft Wildlife Protection Plan, discussed potential impacts to sensitive wildlife in the area, reviewed
proposed best management practices, and discussed any necessary waivers needed for planned operations.
Please see Appendix A, Colorado Parks and Wildlife Pre-application Consultation, for a detailed
summary of CPW consultation.
CPW Waivers
During pre-application consultation, TEP requested a waiver to the “daily” inspection frequency best
management practice under COGCC Rule 1202.a.(10).C., which is required for “Oil and Gas Locations
with a Working Pad Surface located between 500 feet and 1000 feet hydraulically upgradient from a High
Priority Habitat identified in Rule 1202.c.(1).Q-S”. Please see Appendix B, South Leverich 13-09 Drill
Pad Colorado Parks and Wildlife Correspondence June 30, 2022, for CPW’s approval of this waiver
request.
WILDLIFE BEST MANAGEMENT PRACTICES
The following wildlife Best Management Practices will be employed by TEP during development of the
South Leverich 13-09 pad:
1. TEP will inform and educate all employees and contractors on wildlife conservation practices,
including no harassment or feeding of wildlife.
2. TEP will install a proposed water pipeline from the Oil and Gas Location to TEP’s existing water
management system to minimize truck traffic to the location and minimize the potential impacts
to wildlife.
3. TEP will minimize direct impact to wildlife habitat by utilizing existing infrastructure and
disturbance corridors whenever possible.
4. Well telemetry equipment will be installed to minimize site visitation through remote monitoring
of production operations.
5. Black Bear BMPs:
a. Wildlife – Avoidance: The operator agrees to report bear conflicts immediately to CPW staff.
b. Wildlife – Avoidance: TEP will install and utilize bear proof dumpsters and trash receptacles
for food- related trash at all facilities that generate trash.
6. Raptors BMPs:
a. Wildlife – Minimization: Exclusionary devices will be installed to prevent birds and other
wildlife from accessing equipment stacks, vents, and openings.
b. Wildlife - Avoidance: TEP will conduct vegetation removal activities outside the migratory
bird nesting season (April 1 - August 30). If vegetation removal must occur during the
Page 7 of 10
nesting season, TEP will implement hazing or other exclusionary measures prior to April 1 to
avoid take of migratory birds. Alternatively, TEP may conduct a migratory bird survey prior
to vegetation removal as required by COGCC Rule 1202.a.(8) to avoid take of migratory
birds.
7. Mule Deer and Elk BMPs:
a. Wildlife - Avoidance: The operator agrees to reclaim mule deer and elk habitats with CPW
identified native shrubs, grasses, and forbs appropriate to the ecological site disturbed.
b. Wildlife - Minimization: To minimize the potential for wildlife related traffic accidents, TEP
has implemented speed restrictions for all lease roads and requires that all TEP employees
and contractors adhere to these posted speed restrictions.
c. Wildlife - Minimization: Certified weed-free native seed in seed mixes, except for non-native
plants that benefit wildlife will be used. TEP will use certified, weed free grass hay, straw,
hay or other mulch materials used for the reseeding and reclamation of disturbed areas.
8. Cutthroat Trout BMPs:
a. Wildlife - Minimization: TEP will utilize fresh water from Beaver Creek if available or
potable water from a nearby source for dust suppression within cutthroat trout designated
crucial habitat and native fish and other native aquatic species conservation waters. If
feasible, dust suppression in proximity to Beaver Creek shall utilize potable water from a
nearby source instead of raw water to avoid the spread of disease organisms and aquatic
nuisance species. Potable water will be purchased from the City of Rifle Bulk Water Station
or another local source of potable water.
b. Wildlife - Minimization: TEP will stage a spill response trailer at the RU 31-12V pad
adjacent to Beaver Creek, which will have supplies available for immediate response to spills
or releases during operations on the oil and gas location.
APPENDIX A
SOUTH LEVERICH 13-09 DRILL PAD
COLORADO PARKS AND WILDLIFE
PRE-APPLICATION CONSULTATION
CPW CONSULTATION
TEP conducted two (2) pre-application consultation meetings with Colorado Parks and Wildlife (“CPW”)
to discuss the proposed development plan for the South Leverich 13-09 pad and the potential impacts to
wildlife as a result of construction and operations of the proposed facility. The South Leverich 13-09 pad
and associated permanent pipelines are not located within High Priority Habitat. However, based on the
proximity of the oil and gas location to High Priority Habitat, TEP held a pre-application consultation
meeting with CPW to discuss potential impacts associated with the facility and the existing access road.
The first pre-application consultation meeting occurred on April 28, 2021 and was held at the South
Leverich 13-09 pad. This meeting was the initial site review meeting by CPW, which provided CPW with
the opportunity to review the staked oil and gas location and associated pipeline corridors and provide
initial feedback on the development plan. The second pre-application consultation meeting occurred on
June 23, 2022. During this meeting TEP provided updates to the proposed development plan, reviewed
the draft Wildlife Protection Plan, discussed potential impacts to sensitive wildlife in the area, reviewed
proposed best management practices, and discussed any necessary waivers needed for planned operations.
Pre-application Consultation April 28, 2021
On April 28, 2021, TEP, CPW, and others met onsite to discuss the proposed development plan for the
South Leverich 13-09 pad. During the onsite TEP provided an overview of proposed development
activities such as pad reconstruction, drilling and completion operations, facility installation (i.e. proposed
pipeline), and a preliminary development schedule. Additionally, TEP provided details on potential
impacts to wildlife:
1. Proximity to Beaver Creek: Pad location is within 1,000 feet of Beaver Creek, which is identified
as Cutthroat Trout Designated Crucial Habitat and Aquatic Native Species Conservation Waters.
Rule 1202.a.(10) best management practices will apply.
2. Existing Access Road: Road crosses Beaver Creek. Dust suppression methods will be evaluated.
3. Temporary Surface Frac Lines: Temporary lines will cross through Cutthroat Trout Designated
Crucial Habitat.
TEP stated that best management practices would be implemented to protect sensitive wildlife species
during operations on the oil and gas location and installation and operation of the proposed pipelines. Best
management practices would also be implemented to minimize potential impacts to Beaver Creek from
vehicular traffic to and from the oil and gas location. BMPs would be further discussed during a pre-
application meeting scheduled prior to submittal of the Oil and Gas Development Plan.
Pre-application Consultation June 23, 2022
On June 23, 2022, TEP and CPW meet to review the updated proposed development plan, review the
draft Wildlife Protection Plan, discuss potential impacts to sensitive wildlife in the area, review proposed
best management practices, and discuss any necessary waivers needed for planned operations.
Following review of the proposed development plan TEP and CPW reviewed the draft Wildlife Protection
Plan and discussed the operating requirements under Rule 1202.a., 1202.b, and 1202.c. TEP stated that all
operating requirements listed under 1202.a. will be adhered to during planned activities on the South
Leverich 13-09 pad with the exception of Rule 1202.a.(10).C, which requires daily inspection of the oil
and gas location if the working pad surface is between 500 feet and 1000 feet of High Priority Habitat
listed in Rule 1202.c.(1).Q-S. TEP formally requested a waiver to Rule 1202.a.(10).C, which included a
request to modify the inspection frequency. Daily inspection would occur during drilling, completion, and
the first 6 – 9 months of production operations, followed by weekly inspection for the remaining life of
the wells. TEP would install remote monitoring equipment on the oil and gas location to minimize site
visitation, while also monitoring for potential operations issues.
TEP has tentatively scheduled construction of the South Leverich 13-09 pad during November of 2022,
which is outside the nesting season for migratory birds described above. However, if the timing of
construction operations changes and are scheduled to occur during the nesting season, TEP will either
implement hazing prior to April 1, or a pre-construction migratory bird survey will be conducted during
the nesting season to determine if nesting migratory birds are present within the project area. If any active
nests are located, TEP will provide work zone buffers around those active nests as allowed under Rule
1202.a.(8).
TEP stated that all proposed permanent natural gas and produced water pipelines would not be installed
within High Priority Habitat. Additionally, TEP will be in compliance with Rule 1202.b since there are no
planned flowlines or utility crossings of perennial streams identified as aquatic High Priority Habitat.
TEP also stated the proposed development plan would be in compliance with Rule 1202.c, as all ground
disturbance activities would be located outside of the High Priority Habitats listed under Rule 1202.c.(1).
TEP and CPW discussed installation and operation of the proposed temporary surface frac lines, and the
best management practices being implemented during installation. The proposed temporary surface frac
lines will be installed between the South Leverich 13-09 pad and the Youberg RU 44-7 pad and will be
installed following existing pipeline corridors and the access road. The temporary surface frac lines will
cross through approximately 1,000 feet of the Cutthroat Trout Designated Crucial Habitat boundary near
the existing Youberg RU 44-7 pad. The temporary surface pipeline will be installed within the existing
access road right-of-way. No new surface disturbance will occur from installation of the proposed
temporary surface frac lines; therefore Rule 1202.c does not apply. However, TEP will implement best
management practices such as integrity testing and inspections to minimize the potential for a spill or leak
that may impact cutthroat trout habitat downstream of the temporary surface frac lines.
TEP and CPW also reviewed the best management practices listed in the draft Wildlife Protection Plan,
which includes dust suppression methods along the existing access road within Cutthroat Trout
Designated Crucial Habitat. TEP stated that fresh water from Beaver Creek or potable water from a local
source will be utilized for dust suppression near Beaver Creek to minimize the potential for introducing
undesirable aquatic organisms.
TEP and CPW reviewed the topographic map of the area and agreed that potential impacts to elk during
development of the South Leverich 13-09 pad is unlikely based on the distance and topography of the
area. Elk Production Area and Elk Winter Concentration Area boundaries are topographically isolated by
a ridge line southeast and northwest of the oil and gas location. Furthermore, CPW agreed that noise and
light impacts from operations at the South Leverich 13-09 pad are unlikely to impact wildlife resources
and that a noise mitigation plan would not be necessary for the protection of wildlife.
APPENDIX B
SOUTH LEVERICH 13-09 DRILL PAD
COLORADO PARKS AND WILDLIFE
CORRESPONDENCE
JUNE 30, 2022
From:Taylor Elm - DNR
To:Adam Tankersley
Cc:molly.west@state.co.us; Jeff Kirtland; Trevor Burrell
Subject:Re: South Leverich 13-09 Pad - Wildlife Protection Plan & Rule 1202.a.(10).C Waiver Request
Date:Thursday, June 30, 2022 1:43:52 PM
CAUTION: This email originated from outside of the organization. Do not click links or open attachments unless you
recognize the sender and know the content is safe.
Adam,
Thank you for the email and detailed information regarding the proposed activities at the South
Leverich 13-09 Pad. I have reviewed the information within the Wildlife Protection Plan and
Development Plan and prepared the following responses to include in your pre-application consultation
summary and permit application package.
Waiver to Rule 1202.a.(10).C. (Variation to the daily inspection frequency)Colorado Parks and Wildlife understands that the working pad surface for the S. Leverich 13-
09 Pad is within 1,000 feet and upgradient of a 1202.c.(1).Q-S habitat and requires adherence
to the best management practices outlined under Rule 1202.a.(10). One of the listed BMPs
requires daily inspections of the facility unless a different inspection frequency or alternate
method of compliance is identified. CPW agrees that with the use of remote monitoring (i.e.,
SCADA) and weekly visits after the first 6-9 months, there is no need for daily inspections at
this facility. Furthermore, reducing the frequency of inspections will reduce overall vehicle
traffic and disturbance to terrestrial wildlife species inhabiting this area. Consider this
correspondence as CPW's written approval to waive the daily inspection frequency
requirement under Rule 1202.a.(10).C.
Noise and Light Impacts
CPW attended the on-site tour of the S. Leverich 13-09 Pad on April 28, 2021 to discuss
potential wildlife concerns and recommendations to avoid and minimize adverse impacts.
CPW did not recommend any additional noise limits or monitoring requirements pursuant to
Rule 423.b.(4)., because the location is not within a CPW-mapped High Priority Habitat
(HPH). Additionally, CPW did not recommend any additional measures for lighting pursuant
to Rule 424.c.(3).C., because there are no terrestrial HPH habitats within 2,000 feet of the
location. CPW concurs that the applicable noise and light standards in the 400 series
regulations, and the topographic barriers between the site and nearest terrestrial HPH are
sufficient to avoid wildlife impacts associated with noise and light.
If there are any questions or if we can supply additional information, please feel free to call or
email.
Thank you,
Taylor Elm
NW Region Energy Liaison
P (970) 947-2971 | C (970) 986-9767
711 Independent Ave., Grand Junction, CO
taylor.elm@state.co.us | cpw.state.co.us
On Wed, Jun 29, 2022 at 2:37 PM Adam Tankersley <ATankersley@terraep.com> wrote:DI
Good Afternoon Taylor,
Thanks for meeting on June 23, 2022, to review the development pan for the South Leverich
13-09 pad and the Wildlife Protection Plan associated with the Form 2A. The Wildlife
Protection Plan for this location has been updated per our discussion and has been attached
for your review. Please review and let me know if you have any questions.
As discussed during our meeting, the working pad surface of the Honea 19-05 pad is located
within 1,000 feet of High Priority Habitat identified in Rule 1202.c.(1).Q-S and will be
subject to the best management practices listed under Rule 1202.a.(10). However, TEP is
requesting a waiver to the daily inspection frequency required under Rule 1202.a.(10).C.
TEP is requesting a modified inspection frequency for this oil and gas location. Inspection at
this location will occur daily for the first 6 – 9 months of production operations. Inspection
frequency will then drop to once per week (minimum) for the remaining life of the wells.
The oil and gas location will be equipped with Supervisory Control and Data Acquisition
(SCADA) monitoring technology which enables remote monitoring of individual wells,
produced water / condensate tanks, and other production facilities on the oil and gas
location.
As discussed, TEP has included the following best management practice to minimize
potential for introduction of undesirable aquatic organisms into Beaver Creek: “TEP will
utilize fresh water from Beaver Creek if available or potable water from a nearby source for
dust suppression within cutthroat trout designated crucial habitat and native fish and other
native aquatic species conservation waters. If feasible, dust suppression in proximity to
Beaver Creek shall utilize potable water from a nearby source instead of raw water to avoid
the spread of disease organisms and aquatic nuisance species.”
For the South Leverich 13-09 pad, TEP is not requesting a Lesser Impact Area Exemption
for the Noise Mitigation Plan and Lighting Mitigation plan, and will be submitted these
plans with the Form 2A. TEP’s evaluation of noise and lighting impacts associated with our
proposed operations indicated that the proposed activities would be in compliance with
noise standards outlined in Rule 423 and with lighting standards outlined in Rule 424.
During initial planning, TEP reviewed topographic maps, aerial imagery, and completed a
site visit to evaluate siting considerations and potential impacts to wildlife. During this
review TEP determined that it is unlikely for noise and light generated during construction,
drilling, completion, or production operations to adversely impact wildlife resource. This is
based on the overall distance and the topographic barrier between the oil and gas location
and High Priority Habitat boundaries. The working pad surface of the South Leverich 13-09
pad is location 4,456’ from the Elk Production Area boundary and 5,244’ from the Elk
Winter Concentration Area boundary. Furthermore, there are two topographic barriers
between the working pad surface and the High Priority Habitat boundaries, one to the
northwest and one to the southeast, minimizing the potential for noise and light impact on
terrestrial wildlife. Due to these factors it is unlikely for noise and light generated during
operations at this location to adversely impacts wildlife. As a best management practice TEP
will direct all lighting on site during drilling and completion operations downward and
inward toward operations to further minimize potential lighting impacts. TEP is not request
a variance to the noise standards listed in COGCC Rule 423. Please let us know if you agree
with this assessment.
Attached is the Plan of Development, Wildlife Protection Plan, and Wildlife Habitat
Drawing for you review. Please let me know if CPW has any question regarding the waiver
request or BMPs listed in the Wildlife Protection Plan. Additionally, please let me know if
CPW agrees with TEP assessment on noise and lighting impacts associated with activities
planned at the South Leverich 13-09 pad.
Thanks,
Adam Tankersley | Planning Manager | TEP Rocky Mountain LLC | 1058 CR215 Parachute, CO 81635
( (Office) 970-623-8994 | ( (Mobile) 970-589-6277 | * ATankersley@terraep.com
This message and any related attachments are intended only for the use of the addressee(s)
and may contain information that is PRIVILEGED and CONFIDENTIAL. If you are not the
intended recipient(s), you are hereby notified that any dissemination of this communication
is strictly prohibited. If you have received this communication in error, please erase all
copies of the message and its attachments and notify the sender immediately.
TE8~
Water Plan – 304.c.(18)
South Leverich 13-09 Oil and Gas Location
Loc ID #335045
July 2022
Table of Contents
TER
INTRODUCTION
The purpose of this Water Plan is to provide COGCC with specific information regarding the source and
quantity of water that will be used during drilling and completion activities at the South Leverich 13-09
Pad. The sources of water to be used, the volumes, and the water take-out points are described in greater
detail below. This Water Plan has been prepared in accordance with, and to comply with COGCC Rule
304.c.(18).
SITE DESCRIPTION
The South Leverich 13-09 Oil and Gas Development Plan (“OGDP”) is located within Lot 3 and Lot 4 of
Section 13 of Township 7 South, Range 94 West, 6th P.M., which includes the reconstruction of the
existing South Leverich 13-09 pad and associated pipeline infrastructure. TEP is proposing to reconstruct
the South Leverich 13-09 pad to support drilling, completion, and production operations for twenty-one
(21) proposed natural gas wells. The South Leverich 13-09 pad is located within Lot 3 and Lot 4 of
Section 13, Township 7 South, Range 94 West, 6th P.M. on private land owned by Gordman Leverich,
LLP and overlies private minerals. The land on which the pad would be located is classified as non-crop
land, rangeland and recreation and is primarily used for grazing cattle.
The South Leverich 13-09 OGDP involves reconstruction and expansion of one (1) existing Oil and Gas
Location, construction of new pipeline corridors for natural gas transport, and the utilization of other
existing facilities to support well completion and production operations. The pad location would have a
constructed pad elevation of 8,007.1 feet.
The proposed 6.43-acre South Leverich 13-09 pad will be reconstructed for drilling and completions
operations of the twenty-one (21) proposed directional wells. The long-term disturbance following
interim reclamation attributed to the South Leverich 13-09 pad would be approximately 1.74-acres. The
existing access road will be utilized for development of the South Leverich 13-09 pad. Minor
maintenance activities may occur along the existing access road; however, no new disturbance would
occur. The proposed pipeline corridors would account for an additional 1.83-acres of disturbance with
approximately 0.69-acres (existing roads) remaining after reclamation. The total South Leverich 13-09
OGDP disturbance will be approximately 16.11-acres. Approximately 4.79-acres of disturbance would
remain long-term (include the Youberg SR 43-12 support pad and Youberg RU 44-7 remote frac pad)
following interim reclamation of the proposed facilities and pipeline corridors. All proposed disturbance
would be located on private surface. Please see the Plan of Development attached to the Form 2A for a
detailed breakdown of disturbance acreage for all project components associated with the South Leverich
13-09 OGDP.
WATER SOURCES AND VOLUMES
Dust Control
Fresh water will be required for dust control during site construction, drilling operations, and during long-
term production operations. The primary fresh water sources to be used for dust control activities will be
from the Giles Loadout Station. The Giles Loadout Station is a freshwater loadout located on private
property along the Colorado River. All fresh water will be transported by private contract water hauling
trucks equipped with 80 bbls tanks.
The water hauling trucks will utilize existing county roads and lease roads and will follow existing truck
routes where applicable. The intake on the water pumps at the source locations will be fitted with a
quarter-inch (0.25”) mesh screen to prevent impacts to aquatic wildlife in the pond. TEP estimates that
approximately 3,000 bbls (142.85 bbls per well) of fresh water will be used for dust control during
construction.
Dust control measures will be implemented as required per COGCC Rule 427.b-c. Only fresh water
(potable or non-potable) will be used to conduct dust suppression activities within 300 feet of the ordinary
high-water mark of any water body. Only potable water will be used to conduct dust suppression on
sections of lease roads that are within high priority habitat for Cutthroat Trout Designated Crucial Habitat
or other Native Aquatic Species Conservation Waters (within 500 feet of the ordinary high-water mark).
On average, TEP estimates that approximately 500 bbls per well of fresh water will be used to control
dust during drilling operations. Dust control measures are described in greater detail in the Dust
Mitigation Plan attached to the Form 2A. The sources and volumes of fresh water required for dust
control activities are summarized in Table 1, Water Source Table below.
Drilling Operations
Fresh water will be required for drilling operations (surface, intermediate, and production casing). The
primary fresh water sources to be used for drilling activities will be from the Giles Fresh Water Takeout
or the Airport Land Partners Limited Takeout. The Giles Fresh Water Takeout is located on the Colorado
River on TEP property north of County Road 320 near Spruce Creek. The Airport Land Partners Limited
Takeout is located on the Last Chance Ditch north of the Garfield County Airport along Garfield County
Road 346. All fresh water will be transported by private contract water hauling trucks equipped with 80
bbls tanks.
The water hauling trucks will utilize existing county, state, and lease roads and will follow existing truck
routes where applicable. The intake on the water pumps at the source locations will be fitted with a
quarter-inch (0.25”) mesh screen to prevent impacts to aquatic wildlife in the river or ditch. TEP estimates
that approximately 4,000 bbls per well of fresh water will be used for drilling operations.
Well Completions Operations
Well completion operations will be conducted via simultaneous operations (SIMOPS), which utilizes
recycled produced water from other producing wells operated by TEP. Recycled produced water will be
transported from TEP’s existing water management facilities and staged at the Beaver Creek Pit 11-7-793
(COGCC Loc ID# 432702). From there, water will be pumped to a remote frac pad (Youberg RU 44-7
pad: COGCC Loc ID# 439173) via existing pipeline infrastructure. Fluids for well completion operations
will then be pumped from the Youberg RU 44-7 remote frac pad to the wells on the South Leverich 13-09
pad via proposed temporary surface steel frac pipelines. The sources and volumes of recycled produced
water required for completion activities are summarized in the Table 1, Water Source Table, below.
WATER SOURCING INFORMATION
Water to support dust control, drilling, and completion activities as described above will be obtained from
the following sources:
Surface water (Primary source): Water will be supplied from Giles Loadout Station, private water
rights owned by TEP Rocky Mountain, LLC., 1058 CR 215, Parachute, CO, 81635.
Surface water (secondary source): Water will be purchased from shares in the Last Chance Ditch that
is owned by Airport Land Partners (Rifle Airpark), 312 AABC Suite A, Aspen, CO, 81611.
Fresh water (potable water): Water will be purchased from City of Rifle, Bulk Water Station, 2515
West Centennial Parkway, Rifle, CO 81650.
Recycled / Produced Water: Water will be provided from produced water supplies that are treated and
recycled by TEP Rocky Mountain LLC., 1058 CR 215, Parachute, CO, 81635.
Table 1, Water Source Table
Name / Water
Source Type Water Source Use
Water Take-Out
Point Permit
Type
Transport
Method
Volume Per
Well (bbls)
Latitude Longitude
Surface Water -
Primary Source:
Giles Load Out
Station - TEP
Drilling activities:
Surface Casing;
Intermediate/
Production Casing;
Dust Control
39.4866 -107.8839 Private
Contract Trucking 3,643
Surface Water -
Secondary
Source: Airport
Land Partners
Takeout (Last
Chance Ditch)
Drilling activities:
Surface Casing;
Intermediate/
Production Casing;
Dust Control
39.5294 -107.7336 Private
Contract Trucking 500
Surface Water -
City of Rifle,
Bulk Water
Station
Potable water for
Dust Control (as
needed around
Beaver Creek
stream crossings)
39.5258 -107.81143 City of
Rifle Trucking 500
Recycled /
Produced Water
Beaver Creek Pit
11-7-93
Completions,
fracing, stimulation 39.4593 -107.82296 Private Pipeline 120,000
REUSE AND RECYCLING PLAN
The South Leverich 13-09 OGDP and the twenty-one (21) proposed wells will benefit from reuse and
recycling of produced water during hydraulic fracturing operations. Produced water generated from
existing wells operated by TEP would be transported from one of TEP’s existing Centralized E&P Waste
Management Facilities to the Youberg RU 44-7 pad for use during well completion operations. Produced
water is collected, transported to, and treated at one of TEP’s Centralized E&P Waste Management
Facilities. After treatment, the recycled water will be pumped via TEP’s existing waterline infrastructure
and staged at the Beaver Creek Pit 11-7-793. From there, water will be pumped to the remote frac pad
(Youberg RU 44-7 pad: COGCC Loc ID# 439173) via existing pipeline infrastructure where the water
will be stored in six (6) Minion Tanks (aka. Modular Large Volume Tanks or MLVTs), each with a
working capacity of approximately 9,000 bbls. Fluids for well completion operations will then be pumped
from the Youberg RU 44-7 remote frac pad into the proposed wells on the South Leverich 13-09 pad via
proposed temporary surface steel frac lines.
Produced water, if not re-used or recycled during well completion operation, would otherwise require
disposal via the methods described in the Waste Management Plan attached to the Form 2A, which
includes (1) natural evaporation, (2) underground injection, (3) re-use/recycling in hydraulic fracturing
operations, and/or (4) third party disposal. Reuse and recycling of produced water for well completion
operations provides several benefits, including:
1) Decreases freshwater withdrawals from surface water sources,
2) Decreases reliance on injection wells for disposal of production/flowback water,
3) Decreases well completion costs versus alternative sources,
4) Increases operational efficiencies from re-using local supplies of production / flowback water to
meet water demands for drilling, completion, and workover activities,
5) Reduces volume of truck traffic, versus alternatives that could involve trucking water from other
sources.
Proposed Volume
TEP is currently planning to utilize approximately 120,000 barrels of produced water per well during well
completion operations. With twenty-one (21) proposed wells, this totals approximately 2.52MM barrels
of produced water that would be pumped to the Youberg RU 44-7 pad and utilized for hydraulic
fracturing operations. The actual volume of water to be pumped during completion operations may vary
depending on characteristics of the geologic formations and other factors.
Method of Waste Treatment and Storage
Treatment of Recycled Produced Water
All water delivered to the Youberg RU 44-7 pad during well completion operations will generally be
preprocessed and recycled produced water from one or more of TEP’s existing Centralized E&P Waste
Management Facilities. Generally, produced water from these facilities is processed through gun barrels
and other separation equipment to minimize the hydrocarbon concentration within the produced water.
The produced water is then stored in a pit where it is treated with biocides, when necessary.
Storage Tanks
Recycled produced water delivered to the RU 44-7 pad for use during well completion operations will be
stored in Minion Tank prior to being pumped to operations on the proposed wells at the South Leverich
13-09 pad. TEP’s contractor will erect six (6) ten-thousand-barrel (10,000bbl) Minion Tanks with an
individual working capacity of nine thousand barrels (9,000bbls). The total capacity of the six (6) Minion
Tanks is sixty thousand barrels (60,000bbls) with a total working capacity of fifty-four thousand barrels
(54,000bbls).
The Minion Tank is comprised of a ridged steel frame structure bolted together to form a cylindrical shell
with an internal synthetic bladder secured to the steel frame. Each tank is 48.9 feet in diameter and thirty-
two feet (32’) high. The bladder system is designed in accordance with API Standard 650 – Welded
Tanks for Oil Storage.
Containment System
Each Minion Tank includes a synthetic bladder installed within the steel frame shell, which will serve as
the primary containment for recycled water stored at the RU 44-7 pad during well completion operations.
A secondary containment structure will be erected along the north side of the pad to provide one hundred
and fifty percent (150%) containment of the largest tank. The secondary containment structure will be
comprised of a Muscle Wall containment structure with an interior liner. The Muscle Wall is a portable,
low-density polyethylene hollow plastic four-foot (4’) high barrier, which interlock to provide a ridged
containment structure. Each section of Muscle Wall is six foot (6’) in length. Approximately 130 sections
of Muscle Wall will be required to form the containment structure. The interior liner will be a thirty
millimeter (30mil) reinforced polyethylene liner, which will be attached to the Muscle Wall using straps
and clips as specified by the manufacture.
The RU 44-7 pad has been constructed with a minimum one foot (1’) high pad perimeter earthen berm
which has been constructed utilizing excavated subsurface material. The pad perimeter berm will be the
tertiary containment for the proposed Minion Tanks providing approximately 224% containment of the
largest tank.
Please see the Preliminary Well Completion and Stimulation Layout Drawing in the Layout Drawing
package attached to the Form 2A for a depiction of the preliminary layout of the proposed completions
equipment on the Youberg RU 44-7 pad.
Containment Calculation
The total capacity of the six (6) Minion Tanks is approximately sixty thousand barrels (60,000bbls). The
volume of the largest tank within the secondary containment structure will be ten thousand barrels
(10,000bbls). Per COGCC Rule 603.o.(1), “[o]perators will design secondary containment structures to be
sufficiently sized to contain at least 150% of the volume of the largest single [t]ank within the
containment”. The total required holding capacity of the secondary containment must be a minimum of
15,000bbls plus tank displacement.
With the displacement factored in for the additional five tanks, secondary containment should be:
150% of Largest Tank + (((π x r2 x containment high) x oil barrel conversion) x add’l tanks)
1.5 x 10,000bbls + (((π x 24.452 x 4’) x 0.17811) x 5)
Total Secondary Containment = 21,446 bbls
The proposed Muscle Wall secondary containment will be “L” shaped and was calculated as two
individual rectangles, one approximately 188 feet in length by 92 feet, and the other approximately 184
feet in length by 80 feet in width by 4 feet in height. The secondary containment will have a total capacity
of approximately 22,809 bbls.
A minimum one foot (1’) high earthen perimeter berm will be used for tertiary containment. The tertiary
containment is estimated to contain approximately 22,453 bbls, equating to 224% containment of the
largest tank.
Produced Water Quality and Quality Assurance
Produced water delivered to the RU 44-7 pad for storage in the proposed Minion Tanks will be pre-
treated at one of TEP’s existing water management facility. Produced water is generally processed
through gun barrels and other hydrocarbon separating equipment to minimize the hydrocarbon content
within the produced water.
TEP does not use any of the chemicals identified in Table 437-1 as additives in any of our completion
fluids. There are trace concentrations of some organic compounds (e.g., Benzene, Ethylbenzene, Xylene,
etc.), but these are naturally occurring chemicals found within the formation water that is collected and
treated. TEP complies with COGCC Rule 437.b, which does not prevent operators from recycling or
reusing produced water that has naturally occurring, trace amounts of the chemicals listed in Table 437-1.
TEP also complies with Rule 437.c, which allows for the use of those chemical constituents at either the
Table 915-1 standard, or the unconcentrated naturally occurring background level, whichever is greater.
Please see Table 2, Recycled Produced Water – Table 437-1 Concentrations, for detailed water sampling
results.
Flowback water may be stored in the proposed tanks following completion of initial well completion
operations. All flowback water will go through a four-phase separator prior to storage in the Minion
Tanks to separate gas, water, condensate, and sand that may return from the well following well
completion. Flowback water processed and stored in the Minion Tank will be pumped back into TEP’s
water management system during flowback operations.
Table 2, Recycled Produced Water - Table 437-1 Concentrations
Water Quality Sampling Results Data Summary - Table 437-1
Rulison Centralized E&P Waste Management Facility
Facility ID: 149006
Date: October 8, 2021
Chemical Name Units
Analytic
Method Result Qual RL MDL DF
Table
915-1
Levels
Metals
Arsenic MG/L 6010C 0.0055 U 0.01 0.0055 1
Cadmium MG/L 6010C 0.00243 U 0.005 0.00243 1
Chromium MG/L 6010C 0.000916 J, B 0.01 0.000811 1
Lead MG/L 6010C 0.00237 U 0.01 0.00237 1
Mercury MG/L 7470A 0.0000263 U 0.0002 2.63E-05 1
Volatile Organic Compounds
Benzene UG/L SW8260C 0.13 U 1 0.13 1 5
Ethylbenzene UG/L SW8260C 0.5 U 1 0.5 1 700
m-Xylene & p-Xylene UG/L SW8260C 0.63 U 5 0.63 1
o-Xylene UG/L SW8260C 0.6 U 5 0.6 1
Xylenes, Total UG/L SW8260C 1.6 U 10 1.6 1
1400 to
10000
2-Ethylhexanol UG/L SW8260C 200 U 200 200 1
1,3,5-Trimethylbenzene UG/L SW8260C 0.56 U 1 0.56 1 67
1,4-Dioxane UG/L SW8260C 200 U 400 200 1
Semi-volatile Organic Compounds
N,N-dimethylformamide UG/L SW8270D 1.13 J*_ 20.4 0.815 2
Method 8015D - Glycols - Direct Injection (GC/FID)
2-Butoxyethanol UG/L SW8015D 5 U 5 5 1
Method 8015D - Nonhalogenated Organic Compounds - Direct Injection (GC/FID)
1-Butanol UG/L SW8015D 2.77 U 5 2.77 1
Field Parameters
Water temp, field deg C YSI 556 18.6
pH, field s.u. YSI 556 7.15
Specific cond., field uS/cm YSI 556 34276
Conductivity, field uS/cm YSI 556 ---
DO saturation, field % YSI 556 154.1
DO, field mg/L YSI 556 ---
ORP, field mv YSI 556 8.8
Turbidity, field ntu Micro TPI 47.05
Discharge cfs NA
Color nu Light Brown
Odor nu Low
Effervescense nu None
Field Parameters (cont.)
Sediment nu None
Bubbles nu None
VOA Headspace nu None
Table 437-1 Compounds Not Analyzed
2-mercaptoethanol
benzene, 1,1’-oxybis-,tetrapropylene derivatives, sulfonated sodium salts (BOTS)
butylglycidyl ether
Quaternary ammonium compounds, dicoco alkyldimethyl chlorides (QAC)
Bis hexamethylene tiamine penta methylene phosphonic acid (BMPA)
Diethylenetriamine penta (methylene-phosphonic acid) (DMPA)
FD&C blue no. 1
Tetrakis (triethanolaminato)
Notes: U = not detected at the method detection limit; J = result between RL and MDL, estimated; H = hold time exceeded; NM = not measured;
AV = result averaged; VAR = variable; *_ LCS and/or LCSD is outside of acceptable limit, low biased; --- = no standard for this parameter; SS
= Suspended solids
Proposed Timeline for Reuse and Recycling
Produced water will be utilized during well completion operations on the South Leverich 13-09 pad,
which is scheduled to occur between March 2023 and December 2023.
Anticipated Method of Transport
Produced water is transported from existing oil and gas locations to TEP’s existing Centralized E&P
Waste Management Facilities via existing pipelines when existing pipelines are available. Produced water
from other oil and gas locations that do not have existing water pipeline infrastructure is transported via
truck to existing facilities closest to the source location. Water collected and stored at existing Centralized
E&P Waste Management Facilities will be transported via pipeline to Youberg RU 44-7 pad for
temporary storage prior to well completion operations. When well completion operations begin, produced
water will be pumped through the five (5) proposed four-and one-half inch (4.5”) temporary surface steel
frac lines from the Youberg RU 44-7 pad to the well or well(s) being completed.
Final Disposition of the Waste
Produced water will be utilized during well stimulation operations for the proposed wells by pumping the
produced water downhole to stimulate the target formation. Any produced water that is returned during
flowback operations will be reused and recycled at the Youberg RU 44-7 pad for completion of the
remaining wells. Following well completion operations, flowback / produced water will be handled as
described in the Produced Water section of the Waste Management Plan, which has been attached to the
Form 2A.
RATIONALE FOR USING FRESH WATER
Drilling Operations: Fresh water (non-potable) is required for drilling operations to ensure that
consistent drilling mud densities and compositions are achieved. Generally, recycled produced water
contains Total Dissolved Solids (TDS) and chloride concentrations that are too high, and therefore
unsuitable for use when drilling through shallow, fresh-water aquifers.
Completion Operations: TEP is using recycled produced water for completion activities which is by far
the most water-intensive aspect of well development. Fresh water will not be used for well completion
operations.
Dust Control: Many of the access roads in this area run parallel to or are near surface water features
(Beaver Creek, Colorado River, etc.). The use of fresh water for dust control purposes is safer (i.e., more
environmentally friendly) than using recycled produced water that typically contains higher
concentrations of organic and inorganic compounds than fresh water. Use of fresh water for dust control
on these roads will minimize any residual pollutants that could accumulate in soils, and which could
potentially be transported to nearby surface waters.
SITE SPECIFIC BEST MANAGEMENT PRACTICES
The following Best Management Practices will be utilized during development of the South Leverich 13-
09 Oil and Gas Location:
1. Recycled produced water will be utilized for well completion operations minimizing the amount
of fresh water required for development of the proposed wells on this location.
2. Only potable fresh water will be used on access roads within the high priority habitat buffers for
Cutthroat Trout Designated Crucial Habitat and other Native Aquatic Species Conservation
Waters.
Edge Environmental, Inc.
Cumulative Impacts Plan
for the
TEP Rocky Mountain LLC
South Leverich 13-09
Oil and Gas Development Plan
Prepared by
Edge Environmental, Inc.
203 South Devinney Street
Golden, CO 80401
303-988-8844
July 2022
Table of Contents
1
Edge Environmental, Inc.
INTRODUCTION
Edge Environmental, Inc. (Edge) was asked by TEP Rocky Mountain LLC (TEP) to prepare a
Cumulative Impacts Plan pursuant to Colorado Oil and Gas Commission’s (COGCC’s) Rule
304.c.(19). This plan documents how the Operator (TEP) would address cumulative impacts to
resources identified pursuant to Rule 303.a.(5).
This Cumulative Impacts Plan for the South Leverich 13-09 Oil and Gas Development Plan
(OGDP) was prepared based on the preliminary Oil and Gas Location Assessment (Form 2A)
and Cumulative Impacts Data Identification (Form 2B) documentation provided by TEP. The
South Leverich 13-09 pad (COGCC Location ID #335045) is an existing Oil and Gas Location
on private surface owned by Gordman Leverich, LLP which would be reconstructed and slightly
expanded to accommodate the drilling, completion, and production of 21 proposed directional
natural gas wells. The existing South Leverich 13-09 pad is located within Lots 3 and Lot 4 of
Section 13, Township 7 South, Range 94 West, 6th P.M., within Garfield County, Colorado. The
existing access road from Garfield County Road 317/317A would continue to be used to access
the existing Oil and Gas Location. Of the 21 proposed wells planned on this location, 2 wells
would be directionally drilled into Federal Lease COC 63721, and 19 wells would be
directionally drilled into the underlying Fee lease or adjacent Fee leases. The South Leverich
13-09 pad would be reconstructed and slightly expanded to accommodate the development of
the proposed wells. The existing access road from Garfield County Road 317/317A will continue
to be used to access the Oil and Gas Location. TEP would utilize three existing Oil and Gas
Locations, the Youberg RU 44-7 well pad, the Youberg SR 43-12 well pad, and the Beaver
Creek Pit, as support facilities during drilling, completion, and production operations associated
with the proposed wells on the South Leverich 13-09 pad.
The existing Youberg RU 44-7 (COGCC Location ID #439173) pad would be utilized as a
remote frac support location for well stimulation operations for the proposed new directional
wells on the South Leverich 13-09 pad. The Youberg RU 44-7 pad is located on private surface
(Youberg Beaver Creek Ranch L.P.) in the SE¼SE¼ of Section 7, Township 7 South, Range 93
West, 6th P.M. It currently supports production operations for 13 natural gas wells and has been
utilized to support remote well completion operations for multiple Oil and Gas Locations in
recent years.
The existing Youberg SR 43-12 (COGCC Location ID #413683) pad would be utilized as a
produced water storage and transport facility where produced water would be temporarily stored
and pumped before entering TEP’s water management system. It is located on private surface
(Youberg Beaver Creek Ranch L.P.) in Lot 6 of Section 12, Township 7 South, Range 94 West
and Lot 3 of Section 7, Township 7 South, Range 93 West, 6th P.M. The Youberg SR 43-12 pad
currently supports production operations for 20 natural gas wells.
The Beaver Creek Pit would be utilized for temporary storage and transport of recycled
produced water for well completion operations for the 21 proposed wells on the South Leverich
13-09 pad. The Beaver Creek Pit is an existing Oil and Gas Location located on private surface
(Youberg Beaver Creek Ranch, L.P.) in Lot 1 Section 7, Township 7 South, Range 93 West, 6th
P.M.
To support production operations on the South Leverich 13-09 pad, Summit Midstream
(Summit) would install an 8-inch steel natural gas pipeline (approximately 2,125 feet in length)
from the proposed meter on the South Leverich 13-09 pad to their existing/proposed gas
gathering system located south of the South Leverich 13-09 pad. The proposed tie-in point
2
Edge Environmental, Inc.
would be located on TEP surface south of the South Leverich 13-09 pad. TEP would install a 4-
inch FlexPipe water pipeline (approximately 450 feet in length) from the separators on the South
Leverich 13-09 pad to the existing pipeline corridor adjacent to the pad. The proposed water
pipeline would tie-into infrastructure located in the pipeline corridor adjacent to the Oil and Gas
Location. TEP would install several on-location pipelines to support onsite production
operations. The proposed off-location pipelines would be installed within a 50-foot pipeline
Right-of-Way located on property owned by TEP and Gordman Leverich, LLP.
Well completion operations associated with the proposed wells on the South Leverich 13-09 pad
would be conducted via simultaneous operations (SIMOPS) from the existing Youberg RU 44-7
pad. Water would be transported to the Youberg RU 44-7 pad via existing water pipelines
operated and maintained by TEP. TEP would install five 4.5-inch steel temporary surface frac
lines from the Youberg RU 44-7 pad to the South Leverich 13-09 pad to support remote frac and
flowback operations. Temporary surface frac lines would be installed following the existing
access road toward the Federal RU 23-17 pad, an existing pipeline ROW to the Caerus O-18
pad, and then the existing access roads to the South Leverich 13-09 pad. Recycled produced
water would be pumped from existing TEP operated water management facilities to the Youberg
RU 44-7 pad during completion operations. Flowback would be processed through four-phase
separation equipment and transported via pipeline either to the Youberg RU 44-7 pad for
recycle for future well completion operations, or transported to TEP’s water management
facilities for processing, reuse, recycling, and/or disposal.
Construction for the South Leverich 13-09 pad and the pipeline infrastructure is scheduled to
begin in November 2022 and is expected to take approximately 60 days (±8.5 weeks) to
complete. Drilling operations for the 21 proposed directional wells would begin in March 2023.
Because SIMOPS is planned for development of these wells, well completion operations would
begin in May 2023. Drilling is expected to take approximately 121 days (±17 weeks) and should
be completed in July 2023. Well completion is expected to take approximately 210 days (±30
weeks) and should be completed in December 2023. Reclamation of the South Leverich 13-09
pad would be completed by May 2024, within 6 months following completion of well construction
and stimulation activities. Site reclamation is dependent on weather conditions and project
scheduling. The estimated productive life of the 21 proposed natural gas wells is approximately
30 years (360 months). Development may be accelerated or delayed based on market
conditions and company constraints.
SUMMARY OF RESOURCE IMPACTS
Air Resources
Air emissions produced during the pre-production and production phases of development have
been evaluated based on the scale and scope of the proposed development plan for the
following pollutants: oxides of nitrogen (NOx), carbon monoxide (CO), volatile organic
compounds (VOCs), methane (CH4), ethane (C2H6), carbon dioxide (CO2), and nitrous oxide
(N2O).
A quantitative evaluation of the incremental increase in pollutants has been estimated for the
entire proposed development plan for the South Leverich 13-09 OGDP. The emissions estimate
includes both stationary and mobile sources of emissions during all pre-production activities
(see Table 1) and both stationary and mobile sources of emissions for the first year of
production based on all proposed wells and equipment (see Table 2). All pre-production
activities are expected to be completed during 2023 and production would occur beginning in