HomeMy WebLinkAbout1.00 General Application Materials
Temporary Surface Layflat Freshwater Pipeline
Associated Pipeline for the SKR 698-10-BV Well Pad
(Approved under Garfield County Resolution No. 2024-23, File No. OGDA-03-24-9012)
Township 6 South, Range 98 West, 6th PM
Sections 10 & 15: Tract 72
Garfield County, Colorado
Contents
1. Introduction .......................................................................................................................................... 1
2. Project Description ............................................................................................................................... 1
3. Purpose and Need ................................................................................................................................ 1
4. Access and Rights-of-Way .................................................................................................................... 2
5. Ancillary Facilities, Staging and Crossings ........................................................................................... 2
6. Pipeline Installation ............................................................................................................................. 2
7. Traffic Impacts ...................................................................................................................................... 3
8. Installation Schedule and Primary Project Participants...................................................................... 3
9. Pre-Application Meeting ...................................................................................................................... 3
10. Application Submittal Requirements ............................................................................................. 4
10.1 General Application Requirements (Article 9-102.A and Article 4-203.B) .................................. 4
10.2 Vicinity Map (Article 9-102.B and Article 4-203.C) ...................................................................... 4
10.3 Site Plan (Article 9-102.C and Article 4-203.D) ............................................................................ 4
10.4 Project Overview (Article 9-102.D) .............................................................................................. 4
10.5 Property Ownership and Authority to File (Article 9-102.E) ....................................................... 4
10.6 Adjacent Properties (Article 9-102.F) .......................................................................................... 5
10.7 Regulatory Permit Requirements (Article 9-102.G) .................................................................... 5
10.8 Primary Project Participants (Article 9-102.H) ............................................................................ 5
10.9 Associated Facilities (Article 9-102.I) ........................................................................................... 5
10.10 Construction Schedule (Article 9-102.J) .................................................................................. 5
10.11 Sensitive Area Study (Article 9-102.K) ..................................................................................... 5
10.12 Reclamation, Revegetation and Soil Plan (Article 9-102.L) ..................................................... 6
10.13 Weed Management Plan (Article 9-102.M) ............................................................................ 6
10.14 Emergency Response Plan (Article 9-102.N) ........................................................................... 6
10.15 Traffic Impacts (Article 9-102.O) ............................................................................................. 7
10.16 Staging Areas (Article 9-102.P) ................................................................................................ 7
10.17 Pressure Testing (Article 9-102.Q) .......................................................................................... 7
10.18 Review Criteria (Article 9-104 (A-G)) ....................................................................................... 7
11. Appendices
Appendix A – General Application Requirements
Appendix B – Vicinity Maps
Appendix C – Pipeline Route Maps
Appendix D – Surface Use Agreement/BLM ROW
Appendix E – Pre-applicaton Meeting Summary
Appendix F – Regulatory Agency Permit Approvals
Appendix G – Piceance Basin Emergency Response Plan
Appendix H – Pipeline Review Criteria
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GENERAL PROJECT NARRATIVE
1. Introduction
Chevron U.S.A. Inc. (“Chevron”) requests approval of a Land Use Change Permit for pipeline
development in accordance with Section 9-101 of the Garfield County Land Use and Development
Code (“LUDC”), which requires permitting for pipelines greater than five (5) miles in length. The
proposed temporary freshwater layflat SKR 698-10-BV pipeline (the 10 BV line) will be
approximately 17.9 acres in length. The 10BV line is a temporary surface-laid freshwater-only
pipeline that is not regulated by the Colorado Energy & Carbon Management Commission (ECMC)
and therefore requires no permitting with ECMC.
The BV line is necessary to supply freshwater for completion operations associated with the
upcoming development of two horizontal wells on the SKR 698-10-BV (10BV pad). The 10BV pad is
an existing location and is fully permitted as reflected below with both ECMC and Garfield County.
The Garfield County Assessor’s parcel number for the pad location is 2137-321-00-008 and the
parcel size is 4331.71 acres. The parcel is zoned Resource Lands – Gentle Slopes.
Agency Approval ID No. Approval Date Comments
ECMC OGDP ID: 486609
Location ID: 336056
8/23/2024
Garfield County OGDA-03-24-9012 12/1/2025 Final Recorded Order was
dated 8/5/24; Resolution
2024-23
2. Project Description
The 10BV line will transport freshwater utilizing booster pumps along the pipeline route, beginning
at two 60,000-barrel modular large volume tanks (MLVTs, also referred to as Hydrotowers) at the
Kobe Pump Station in Section 18, T8S-R97W north of the Town of De Beque, along existing
disturbances and/or rights-of-way, to the existing Skinner Ridge 66S98W 22NENW Pad in Section
22, T6S-R98W, where water will be staged in two 25,000-barrel MLVTs. From this location, water
will be pumped north and east to the 10BV Pad and stored in a 25,000-barrel MLVT. The 10BV line
will also extend north and east to Chevron’s freshwater pond in Section 36, T5SR98W, allowing
supplemental supply if operational needs increase or are necessary due to weather conditions.
The 10BV line will be up to 16-inches in diameter and will traverse along existing disturbances and
rights-of-way (ROW) approximately 94,774 feet (17.9 miles).
3. Purpose and Need
The purpose of the proposed 10BV line is to provide a reliable, efficient, and environmentally
responsible source of freshwater to support completion needs. The project is needed to ensure
that Chevron can safely and effectively deliver the freshwater volumes necessary for operations
while adhering to the directives to minimize truck traffic, reduce emissions, and lessen cumulative
impacts to surrounding communities and environmental resources.
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This temporary line is essential to eliminating the need for high volume freshwater hauling by truck.
Relying on trucked water would require approximately 10,603 individual truck trips during the
completion operations, resulting in substantially increased dust, noise, road degradation, traffic
conflicts, air emissions, and safety risks.
4. Access and Rights-of-Way
Access to the 10BV line will be at various locations along CR 204 and CR 211 and adjacent roads that
intersect with the proposed pipeline corridor. See Appendix C for the proposed pipeline route.
The majority of the 10BV line, approximately 82,514 feet (15.6 miles), is on Chevron-owned surface.
The additional approximate 12,260 feet (2.32 miles) is on surface owned by Mahogany Energy
Resources, LLC and the Bureau of Land Management (BLM). Chevron holds the required surface use
agreement with Mahogany and an approved ROW from the BLM. See Appendix D.
5. Ancillary Facilities, Staging and Crossings
Ancillary facilities, culverts, staging and crossings for the 10BV line include the following key
elements and are included on the plat exhibits in Appendix C:
• One designated staging and storage area will be used to house backup pumps, additional
layflat, and other support materials. Layflat reels will also be positioned incrementally along
and adjacent to the ROW to support installation and operation
• Three existing permitted culverts will be utilized. In addition, the 10BV pipeline will be
placed along a ditch on Chevron surface under the bridge on CR204.
• All project components, including construction workspace and pipeline installation will
utilize Chevron surface as well as existing ROWs. Installation will be confined to a 30-foot
ROW corridor. Pump locations shown on the plat exhibits may be adjusted as needed to
meet hydraulic requirements.
• No permanent Chevron owned facilities are associated with the 10BV line. The only delivery
point is a 12-inch hydrant connection at the Kobe Pump Station, and no additional long-term
infrastructure is required.
6. Pipeline Installation
The 10BV line will be installed entirely within existing disturbed areas, and no new surface
disturbance is required for construction or operation.
Typical vehicles used for layflat pipeline installation include standard pickup trucks, some of which
tow small dual-axle flatbed trailers carrying the layflat spools. Whenever possible, these vehicles
will remain on existing roads and previously disturbed rights-of-way, while the layflat is deployed
from a telehandler along the proposed pipeline route.
Layflat spool dimensions vary by vendor, with larger spools measuring approximately 9-foot in
diameter and 2-foot in width. Staging areas will be used only where direct deployment is not
feasible and will be limited to existing disturbed locations or approved rights-of-way.
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Once the 10BV line is installed and filled with water, no additional stabilization is typically required.
However, on slopes or areas adjacent to roadways, Chevron will secure the line using tee-posts and
pipe braces to prevent movement.
For removal, a telehandler equipped with a spool attachment will rewind the layflat, and the spools
will be reloaded onto flatbed trailers for transport off-site.
Booster pumps utilized to push water through the 10BV line will have muffled internal combustion
engines.
7. Traffic Impacts
Traffic associated with the installation and removal of the 10BV line are minimal as depicted in the
table below, especially when compared to the approximate 10,603 truck trips that would otherwise
be required to haul freshwater to the 10BV pad. This limited traffic generated for pipeline
installation and demobilization represents only a fraction of impacts that would occur during a
truck hauling scenario. Note that after construction is complete, light truck traffic will continue
throughout the course of the completions operation.
Type of Traffic Trips Per Day Total Trips
Construction ~5 ~140
Light Truck Traffic
(during operations)
~5 ~140
Heavy Truck Traffic ~4 ~20
Personnel will travel to the project area from Rifle and Grand Junction via CR 204 and CR 211.
8. Installation Schedule and Primary Project Participants
Installation of the 10BV line is expected to begin in July 2026 with removal occurring December of
2026, with each stage taking approximately four weeks. Installation will occur during daylight hours
only and could include weekends. In the event of inclement weather conditions, removal may be
delayed until favorable weather conditions are observed.
Primary contacts for the installation of this project are as follows:
Chevron Personnel:
• Tyler Barnes, Project Engineer: (970) 986-2389
• Dean Derby, Ranch Representative, (970) 270-1017
Construction Company: Craig Horn, Elevate Energy Services: (701) 495-1255
ECMC: Not applicable, no permitting required.
CDPHE: Not applicable, no permitting required.
9. Pre-Application Meeting
Pursuant to LUDC Article 9-103.A and Article 4-101.A, Chevron requested a pre-application
conference with Garfield County prior to submitting this Land Use Change Permit on October 2,
2025. The pre-application meeting conference summary is attached as Appendix E.
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10. Application Submittal Requirements
10.1 General Application Requirements (Article 9-102.A and Article 4-203.B)
This application has been prepared in accordance with the Garfield County Land Use and
Development Code, as amended. Copies of the required permit application forms and agreements
are below and included in Appendix A.
• Pipeline Application Submittal Requirements Overview
• Land Use Change Permit Application Form
• Payment Agreement Form
• Statement of Authority Form – Power of Attorney attached along with a letter
authorizing additional personnel and contractors to represent Chevron in regulatory and
permitting matters.
• Ownership Deed
• Notification Package Names and Mailing Addresses
10.2 Vicinity Map (Article 9-102.B and Article 4-203.C)
A Vicinity Map is included as Appendix B.
10.3 Site Plan (Article 9-102.C and Article 4-203.D)
Chevron requests a waiver from the detailed Site Plan requirements outlined in Article 4-203.D. The
proposed 10BV line does not involve excavation, grading, permanent structures, or any new
surface disturbance. As a result, many of the required Site Plan elements, such as topographic
grading, structural footprints, utility placements, finished grades, parking areas, and construction of
permanent facilities, are not applicable to this type of temporary, above-ground pipeline
installation.
The project consists solely of placing a temporary layflat pipeline within existing disturbed areas
and approved rights-of-way to transport freshwater.
Supporting project details, including pipeline routing, access points, staging areas, and temporary
facility locations, are provided in Appendix B and Appendix C. Given the temporary and
non-invasive nature of the 10BV line, Chevron requests approval to satisfy the Site Plan
requirement through these appendices in lieu of the full Article 4-203.D Site Plan specifications.
10.4 Project Overview (Article 9-102.D)
This narrative provides project overview details.
10.5 Property Ownership and Authority to File (Article 9-102.E)
See Appendix A and D.
Page | 5
10.6 Adjacent Properties (Article 9-102.F)
See Appendix B.
10.7 Regulatory Permit Requirements (Article 9-102.G)
No permits are required by ECMC or any other agency (other than Garfield County) to lay a
temporary surface layflat freshwater pipeline. Chevron has included the Form 2A approval for the
10BV Pad in Appendix F.
10.8 Primary Project Participants (Article 9-102.H)
See Section 8 above.
10.9 Associated Facilities (Article 9-102.I)
See Section 5 above.
10.10 Construction Schedule (Article 9-102.J)
See Section 8 above.
10.11 Sensitive Area Study (Article 9-102.K)
Chevron requests a waiver from the Article 9 Sensitive Area Survey requirement. This temporary
layflat line does not trigger the intent or necessity of a Sensitive Area Survey because:
• No Ground Disturbance or Construction Activities
The project involves only the temporary placement of a surface-laid freshwater layflat
pipeline. As documented in this project narrative, the 10 BV line does not involve
excavation, grading, permanent structures, or any new surface disturbance for its
installation or operation. The 10 BV line is placed on the ground surface and removed once
completions operations conclude.
• Minimal and Short-Duration Operational Activity
Traffic and access demands are extremely limited. The operation consists only of light-truck
ROW monitoring traffic, with no construction equipment or heavy vehicle use other than
initial placement and removal of the spools.
• The project’s operational window is short (roughly September–December), and activities
are limited to freshwater transfer with no earthwork.
• This project involves freshwater only, no hydrocarbon or produced water handling.
• Use of Existing Access and Previously Disturbed Areas
The pipeline alignment utilizes existing rights-of-way and/or established access corridors,
including county-permitted culverts and previously installed Chevron crossings, which
minimizes any interaction with undisturbed lands.
• Temporary Nature and Full Removal After Use
The system is temporary and fully removable. No long-term surface impacts remain after
the project.
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10.12 Reclamation, Revegetation and Soil Plan (Article 9-102.L)
Chevron respectfully requests a waiver from the Article 9 reclamation, revegetation, and soil
management plan requirements.
The 10BV line creates no soil disturbance, as it “does not involve excavation, grading, permanent
structures, or any new surface disturbance” and is placed entirely on the existing ground surface.
Installation and operation require no vegetation removal, trenching, or grading, and the line is fully
removed at the end of the short operational period with no lasting effects.
The project is located primarily on Chevron-owned surface, using existing access corridors, prior
disturbance, and previously permitted culverts and crossings. Because the 10BV line will transport
freshwater only, it presents no risk of soil contamination or impacts associated with produced
water or hydrocarbons.
Given the lack of ground disturbance, the temporary and fully reversible nature of the activity, and
its location on Chevron-owned and previously utilized operational areas, a detailed reclamation,
revegetation, and soil plan is not applicable to this project.
10.13 Weed Management Plan (Article 9-102.M)
Chevron requests a waiver from the Article 9 Weed Management Plan requirement. The project
creates no new surface disturbance, as the line does not involve excavation, grading, permanent
structures, or any new surface disturbance, and is placed entirely on existing ground conditions.
The corridor lies primarily on Chevron-owned surface and uses existing access routes and
previously disturbed operational areas, further minimizing any interaction with vegetation. The
10BV is temporary, fully removable, and generates no vegetation clearing or soil disruption, weed
establishment or spread is not anticipated.
10.14 Emergency Response Plan (Article 9-102.N)
In response to Garfield County’s requirement for an Emergency Response Plan, Chevron notes that
the proposed temporary 10BV line will be used exclusively for freshwater and does not involve
hazardous materials of any kind, chemical storage, hydrocarbons, or activities that present typical
fire or spill-related risks. As described in the project narrative, the 10BV line creates no new
disturbance, includes no permanent facilities, and performs only short-term freshwater
conveyance.
Although the project does not introduce materials or operations that would normally necessitate a
Fire Protection and Hazardous Materials Spills Plan, Chevron will fully comply with the intent of the
rule by implementing and adhering to its Piceance Emergency Response Plan included as Appendix
G for the duration of this temporary activity. This plan outlines Chevron’s notification procedures,
emergency communication structure and access provisions for emergency responders.
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Chevron will ensure that county emergency services and the appropriate fire district have access to
all necessary contact information and can reach Chevron personnel at any time should an
unforeseen emergency occur
10.15 Traffic Impacts (Article 9-102.O)
See Section 7 above.
10.16 Staging Areas (Article 9-102.P)
See Section 5 above.
10.17 Pressure Testing (Article 9-102.Q)
This is a freshwater layflat pipeline, no pneumatic pressure testing will occur.
10.18 Review Criteria (Article 9-104 (A-G))
APPENDIX A
GENERAL APPLICATION
REQUIREMENTS
SKR 698-10-BV
Temporary Surface
Freshwater Layflat
Pipeline
Garfield County, Colorado
34
Article 9-102 - Pipeline Application Submittal Requirements
Rule Reference Comments
9-102.A See Appendix A
9-102.B See Appendix B
9-102.C N/A - The temporary pipeline does not involve excavation, grading, or permanent structures. Most of
the site plan required elements are irrelevant to a temporary surface laid pipeline (elevation drawings,
sewer lines, etc.)
9-102.D See Project Overview Narrative
9-102.E -
9-102.E(1)See Appendix B for Parcel Ownership
9-102.E(2)-
9-102.E(2)(a)See Appendix A for Statement of Authority
9-102.E(2)(b)See Appendix A for Authorization to File
9-102.E(2)(c)See Appendix D for surface use and BLM ROW agreements.
9-102.E(3)See Appendix A for Payment Agreement Form
9-102.F See Appendix B.
9-102.G See Appendix F for Form 2A associated with well pad
No permits are needed from ECMC for a surface layflat freshwater pipeline.
9-102.H See Project Narrative - Section 8
9-102.I See Project Narrative - Section 5
9-102.J See. Project Narrative - Section 8
9-102.K N/A - Article 4, Section 4-202 Waiver
9-102.L N/A - Article 4, Section 4-202 Waiver
9-102.M N/A - Article 4, Section 4-202 Waiver
9-102.N See Appendix G
Vicinity Map (section 4-203.C.)
Site Plan (section 4-203.D)
Project Overview
Property Ownership and Authority to File Application
Letter of Authorization signed by the property owner authorizing Applicant to file the application
Any permanent project facilities such as permanent rights-of-way, widths, meter stations, valve sets, etc., and any temporary rights-of-way,
width during construction, construction facilities, etc.
Weed Management Plan
Emergency Response Plan - A Fire Protection and Hazardous Materials Spills Plan that specifies planned actions for possible emergency
events, a listing of persons to be notified of an emergency event, proposed signage, and provisions for access by emergency response teams.
The emergency plan must be acceptable to the appropriate fire district or the County Sheriff, as appropriate. The plan shall include a provision
for the operator to reimburse the appropriate emergency service provider for costs incurred in connection with emergency response for the
Operator’s activities at the site.
Reclamation, Revegetation and Soil Plan
Sensitive Area Survey - A Sensitive Area Survey shall be submitted by a qualified professional and shall provide the type and area of concern
within and adjacent to the pipeline right-of-way, including but not limited to sensitive plant and animal populations and wildlife critical
habitat, as such populations are defined by state and federal referral agencies, and Waterbodies. The Survey shall provide a method or plan for
compliance with protection measures and state and federal laws as identified by these agencies pertaining to the identified sensitive areas. This
submittal requirement does not apply in previously-disturbed corridors or rights-of-way and/or areas permitted by the ECMC.
Construction Schedule - The estimated start and end dates for construction, days of the week in which construction will occur, and hours of
day during which construction will occur.
Article 9 - Pipelines Application Requirements
Payment Agreement Form
Adjacent Properties - A diagram showing adjacent properties and the approximate location of buildings and their uses within a distance of 350'
of any proposed structure, facility, or area to be disturbed.
Regulatory Permit Requirements - Any associated permits needed from other agencies for the pipeline.
Primary Project Participants - The names, address, and phone numbers of the company representative; company and individual acting as an
agent for the company; construction company contacts; and Federal and State agency contacts.
General Application Materials (section 4-203.B) including the Application Form (signed), payment of Fees and signed Payment Agreement
Form , Owners within 200'
Identify Parcel Ownership (can be a map or Plat showing the parcel with pipeline easement)
Evidence of Authority of Applicant to File
Statement of Authority
Deed, easement, surface use agreement, or BLM right-of-way
Article 9-102 - Pipeline Application Submittal Requirements
Rule Reference Comments
9-102.O See Project Narrative - Section 7
9-102.P See Project Narrative - Section 5
9-102.Q N/A - No pneumatic testing; some air in the line to keep inflated; don't run at MAOP (200 psi)
Three hard copies and one digital copy (on a USB drive, for example) of the application are required. Both versions should be split into
individual sections. Community Development Staff is available to meet with the Applicant to provide additional information and clarification
Pressure Testing - Indicate the quantity of water or other fluid required, legal source of water if utilized, and the disposition of the water or
other fluid after testing.
Traffic Impact - For construction traffic that will use a County road, the anticipated types of vehicles, number of each type, anticipated number
of trips per day per each type, County roads to be used, and the percentage of the construction traffic that will travel on each road.
Staging Areas - The general location of the staging areas required for pipeline construction
Article 9 - Pipelines Application Requirements
Land Use Change ApplicaƟon Form
Community Development Department
108 8th Street, Suite 401
Glenwood Springs, CO 81601
(970) 945-8212
www.garfield-county.com
LAND USE CHANGE PERMIT
APPLICATION FORM
TYPE OF APPLICATION
Administrative Review Development in 100-Year Floodplain
Limited Impact Review Development in 100-Year Floodplain Variance
Major Impact Review Code Text Amendment
Amendments to an Approved LUCP
LIR MIR SUP
Rezoning
Zone District PUD PUD Amendment
Minor Temporary Housing Facility Administrative Interpretation
Vacation of a County Road/Public ROW Appeal of Administrative Interpretation
Location and Extent Review Areas and Activities of State Interest
Comprehensive Plan Amendment Accommodation Pursuant to Fair Housing Act
Pipeline Development Variance
Time Extension (also check type of original application)
INVOLVED PARTIES
PROJECT NAME AND LOCATION
Project Name:
_____________________________________________________________________________________
Assessor’s Parcel Number: ___ ___ ___ ___ - ___ ___ ___ - ___ ___ - ___ ___ ___
Physical/Street Address: ________________________________________________________________
Legal Description: ______________________________________________________________________
_____________________________________________________________________________________
Zone District: ___________________________________ Property Size (acres): __________________
Owner/Applicant
Name: ________________________________________________ Phone: (______)_________________
Mailing Address: ______________________________________________________________________
City: _______________________________________ State: _______ Zip Code: ____________________
E-mail:_______________________________________________________________________
Representative (Authorization Required)
Name: ________________________________________________ Phone: (______)_________________
Mailing Address: ______________________________________________________________________
City: _______________________________________ State: _______ Zip Code: ____________________
E-mail:_______________________________________________________________________________
PROJECT DESCRIPTION
REQUEST FOR WAIVERS
Submission Requirements
The Applicant requesting a Waiver of Submission Requirements per Section 4-202. List:
Section: ______________________________ Section: _________________________________
Section: ______________________________ Section: _________________________________
Waiver of Standards
The Applicant is requesting a Waiver of Standards per Section 4-118. List:
Section: ______________________________ Section: _________________________________
Section: ______________________________ Section: _________________________________
I have read the statements above and have provided the required attached information which is
correct and accurate to the best of my knowledge.
______________________________________________________ __________________________
Signature of Property Owner or Authorized Representative, Title Date
OFFICIAL USE ONLY
File Number: __ __ __ __ - __ __ __ __ Fee Paid: $_____________________________
Existing Use:
__________________________________________________________________________
Proposed Use (From Use Table 3-403): ____________________________________________________
Description of Project:
Article 4-202 - Waivers
Rule Reference Comments
9-102.K N/A - Article 4, Section 4-202 Waiver
9-102.L N/A - Article 4, Section 4-202 Waiver
9-102.M N/A - Article 4, Section 4-202 Waiver
Reclamation, Revegetation and Soil Plan
Weed Management Plan
Sensitive Area Survey - A Sensitive Area Survey shall be submitted by a qualified professional and shall provide the type and area of concern
within and adjacent to the pipeline right-of-way, including but not limited to sensitive plant and animal populations and wildlife critical
habitat, as such populations are defined by state and federal referral agencies, and Waterbodies. The Survey shall provide a method or plan for
compliance with protection measures and state and federal laws as identified by these agencies pertaining to the identified sensitive areas. This
submittal requirement does not apply in previously-disturbed corridors or rights-of-way and/or areas permitted by the ECMC.
Article 9 - Pipelines Application Requirements
Payment Agreement Form
PAYMENT AGREEMENT FORM
GARFIELD COUNTY (“COUNTY”) and Property Owner (“APPLICANT”) ______ ____
______________________________________________________________________ agree as follows:
1. The Applicant has submitted to the County an application for the following Project:
__________________.
2. The Applicant understands and agrees that Garfield County Resolution No. 2014-60, as
amended, establishes a fee schedule for each type application, and the guidelines for the
administration of the fee structure.
3. The Applicant and the County agree that because of the size, nature or scope of the
proposed project, it is not possible at this time to ascertain the full extent of the costs
involved in processing the application. The Applicant agrees to make payment of the Base
Fee, established for the Project, and to thereafter permit additional costs to be billed to the
Applicant. The Applicant agrees to make additional payments upon notification by the
County, when they are necessary, as costs are incurred.
4. The Base Fee shall be in addition to and exclusive of any cost for publication or cost of
consulting service determined necessary by the Board of County Commissioners for the
consideration of an application or additional County staff time or expense not covered by
the Base Fee. If actual recorded costs exceed the initial Base Fee, the Applicant shall pay
additional billings to the County to reimburse the County for the processing of the Project.
The Applicant acknowledges that all billing shall be paid prior to the final consideration by
the County of any Land Use Change or Division of Land.
I hereby agree to pay all fees related to this application:
Billing Contact Person:_____________________________________ Phone: (_____)___________________
Billing Contact Address: ___________________________________________________________________
City: ______________________________________________ State: _______ Zip Code: ________________
Billing Contact Email: _____________________________________________________________________
Printed Name of Person Authorized to Sign: ___________________________________________________
______ ________________________________
(Signature) (Date)
Tracey Fallang 1/15/2026
Statement of Authority
Revised 4-26-24
Revised 4-26-24
Revised 4-26-24
Brian DeRose
Attorney-in-Fact
Chevron U.S.A. Inc.
Shale & Tight Business
2115 117th Avenue, Greeley, Colorado 80634
September 19, 2025
Garfield County
Community Development
108 8th Street, Suite 401
Greeley, Colorado 81601
RE: Authorization to Represent Chevron for Garfield County Permitting Matters
To Whom it May Concern:
This letter is being submitted to authorize the following Chevron U.S.A. Inc. personnel and/or
contractors to represent Chevron in regulatory and permitting matters in Garfield County, Colorado
John Gruber
Senior Manager, W&TB Permitting-Rockies
Shale & Tight Business
1099 18th Street, Suite 1500, Denver, CO 80202
661-654-7144
john.gruber@chevron.com
Tracey Fallang
Contract Regulatory Specialist
Rockies Business Unit
2115 117th Ave, Greeley, CO, 80634
303-596-4818
tracey.fallang@chevron.com
Andrew Olson
Operations Superintendent
Shale & Tight Business
760 Horizon Drive, Suite 401
Grand Junction, CO 81506
970-257-6004
andrewolson@chevron.com
If you should have any questions regarding this notice, please feel free to contact the undersigned
at 970-342-0135 or via email at brian.derose@chevron.com.
Thank you for your consideration of this matter.
Respectfully,
Brian DeRose
Attorney-in-Fact
Ownership
OWNERSHIP DEED
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NoƟficaƟon Package Names and Mailing Addresses
(Adjacent Property Owners within 200')
CHEVRON U.S.A. INC.
ENGINEERING & LAND SURVEYING
UELS, LLC
Corporate Office * 85 South 200 East
Vernal, UT 84078 * (435) 789-1017
DRAWN BY
SURVEYED BY
SKR 698-10-BV TEMPORARYSURFACE FRESHWATER PIPELINET5S, R98W & T6S, R98W & T7S, R98W & T7S, R97W &T8S, R97W, 6th P.M. GARFIELD COUNTY, COLORADO
D.P.11-07-25
TEMPORARY SURFACE PIPELINE MAP
LAND OWNER
CHEVRON USA INC
BUREAU OF LAND MANAGEMENT2300 RIVER FRONTAGE ROADSILT CO 81652
BUREAU OFLAND MANAGEMENT
CHEVRON USA INC
MAHOGANY ENERGY RESOURCES LLC420 FIFTH AVENUE, 5TH FLOOR,NEW YORK NY 10018
MAHOGANY ENERGYRESOURCES LLC
BUREAU OFLAND MANAGEMENT
TEMPORARY SURFACE PIPELINE - 200' BUFFER OWNERSHIP TABLE
PARCEL ID #STREET ADDRESS / APPROXIMATEDISTANCE FROM DeBEQUEMAILING ADDRESS
CHEVRON USA INCPO BOX 285HOUSTON TX 77001
APPROXIMATELY 14.4 MILESNW OF DeBEQUE, CO 81630
0 211 COUNTY RDDeBEQUE, CO 81630
APPROXIMATELY 8.5 MILESNW OF DeBEQUE, CO 81630
6398 204 COUNTY RDDeBEQUE, CO 81630
2704 204 COUNTY RDDeBEQUE, CO 81630
678 204 COUNTY RDDeBEQUE, CO 81630
APPROXIMATELY 2.0 MILESNORTH OF DeBEQUE, CO 81630
213916300014
216704400952
216709400953
216716100007
216721200008
216734100963
241304100002
241310200015
216736200023
241336200017
241325100016
244510100951
244312400006
213732100008
CHEVRON USA INC APPROXIMATELY 15.9 MILESNW OF DeBEQUE, CO 81630
APPROXIMATELY 16.4 MILESNW OF DeBEQUE, CO 81630
BUREAU OFLAND MANAGEMENT APPROXIMATELY 15.4 MILESNW OF DeBEQUE, CO 81630
APPROXIMATELY 14.9 MILESNW OF DeBEQUE, CO 81630
CHEVRON USA INC
BUREAU OFLAND MANAGEMENT216722200956 APPROXIMATELY 13.5 MILESNW OF DeBEQUE, CO 81630
BUREAU OFLAND MANAGEMENT APPROXIMATELY 11.7 MILESNW OF DeBEQUE, CO 81630
9722 204 COUNTY RDDeBEQUE, CO 81630CHEVRON USA INC
CHEVRON USA INC APPROXIMATELY 8.9 MILESNW OF DeBEQUE, CO 81630
BUREAU OFLAND MANAGEMENT241311200951 APPROXIMATELY 7.1 MILESNW OF DeBEQUE, CO 81630
CHEVRON USA INC
CHEVRON USA INC
CHEVRON USA INC
CHEVRON USA INCPO BOX 285HOUSTON TX 77001
CHEVRON USA INCPO BOX 285HOUSTON TX 77001
CHEVRON USA INCPO BOX 285HOUSTON TX 77001
CHEVRON USA INCPO BOX 285HOUSTON TX 77001
CHEVRON USA INCPO BOX 285HOUSTON TX 77001
CHEVRON USA INCPO BOX 285HOUSTON TX 77001
CHEVRON USA INCPO BOX 285HOUSTON TX 77001
CHEVRON USA INCPO BOX 285HOUSTON TX 77001
BUREAU OF LAND MANAGEMENT2300 RIVER FRONTAGE ROADSILT CO 81652
BUREAU OF LAND MANAGEMENT2300 RIVER FRONTAGE ROADSILT CO 81652
BUREAU OF LAND MANAGEMENT2300 RIVER FRONTAGE ROADSILT CO 81652
BUREAU OF LAND MANAGEMENT2300 RIVER FRONTAGE ROADSILT CO 81652
BUREAU OF LAND MANAGEMENT2300 RIVER FRONTAGE ROADSILT CO 81652
TEMPORARY SURFACE
FRESHWATER PIPELINE
EXISTING LOCATION:
SKR #698-10-BV PAD
MATCH LINE
SEE SHEET 2 OF 2
200' OFFSET FROM TEMPORARY
SURFACE FRESHWATER PIPELINE
T6S
T5S
R
98
W
R
97
W
EXISTING LOCATION:
PICEANCE BASIN SKINNER
RIDGE WATER MANAGEMENT
FACILITY (FRESH WATER POND)
EXISTING SKINNER RIDGE-
66S98W/ 22NENW PAD
CHEVRON U.S.A. INC.
ENGINEERING & LAND SURVEYING
UELS, LLC
Corporate Office * 85 South 200 East
Vernal, UT 84078 * (435) 789-1017
DRAWN BY
SURVEYED BY SCALE
SKR 698-10-BV TEMPORARYSURFACE FRESHWATER PIPELINET5S, R98W & T6S, R98W & T7S, R98W & T7S, R97W &T8S, R97W, 6th P.M. GARFIELD COUNTY, COLORADO
D.P.11-07-25 1" = 5000'
PIPELINE
LOCATION
CountyMesa
TEMPORARY SURFACE PIPELINE MAP
CountyGarfield
R
98
W
R
99
W
CHEVRON USA INC
PARCEL ID#213732100008
MAHOGANY ENERGY
RESOURCES LLC
PARCEL ID#216736200023
CHEVRON USA INC
PARCEL ID#
213916300014
CHEVRON USA INC
PARCEL ID#
216721200008
BLM PARCEL ID#
241311200951
BLM PARCEL ID#
216704400952
BLM PARCEL ID#
216709400953
CHEVRON USA INC
PARCEL ID#
216716100007
BLM PARCEL ID#
216722200956
BLM PARCEL ID#
216734100963
CHEVRON USA INC
PARCEL ID#
241304100002
CHEVRON USA INC
PARCEL ID#
241310200015
MATCH LINE
SEE SHEET 1 OF 2
R
98
W
R
97
W
T8S
T7S
GARFIELD CO.
MESA CO.
TEMPORARY SURFACE
FRESHWATER PIPELINE
EXISTING LOCATION:
KOBE PUMP & TANKS
CHEVRON U.S.A. INC.
ENGINEERING & LAND SURVEYING
UELS, LLC
Corporate Office * 85 South 200 East
Vernal, UT 84078 * (435) 789-1017
DRAWN BY
SURVEYED BY SCALE
SKR 698-10-BV TEMPORARYSURFACE FRESHWATER PIPELINET5S, R98W & T6S, R98W & T7S, R98W & T7S, R97W &T8S, R97W, 6th P.M. GARFIELD COUNTY, COLORADO
D.P.11-07-25 1" = 5000'
PIPELINE
LOCATION
CountyMesa
TEMPORARY SURFACE PIPELINE MAP
CountyGarfield
MAHOGANY ENERGY
RESOURCES LLC
PARCEL ID#216736200023
BLM PARCEL ID#
241311200951
CHEVRON USA INC
PARCEL ID#
241310200015
CHEVRON USA INC
PARCEL ID#
241325100016
CHEVRON USA INC
PARCEL ID#
241336200017
CHEVRON USA INC
PARCEL ID#
244312400006
BLM PARCEL ID#
244510100951
200' OFFSET FROM TEMPORARY
SURFACE FRESHWATER PIPELINE
APPENDIX B
PIPELINE VICINITY
MAPS
SKR 698-10-BV
Temporary Surface
Freshwater Layflat
Pipeline
Garfield County, Colorado
34
CHEVRON U.S.A. INC.
ENGINEERING & LAND SURVEYING
UELS, LLC
Corporate Office * 85 South 200 East
Vernal, UT 84078 * (435) 789-1017
DRAWN BY
SURVEYED BY SCALE
SKR 698-10-BV TEMPORARYSURFACE FRESHWATER PIPELINET5S, R98W & T6S, R98W & T7S, R98W & T7S, R97W &T8S, R97W, 6th P.M. GARFIELD COUNTY, COLORADO
D.P.11-07-25 1" = 5000'
PIPELINE
LOCATION
CountyMesa
TEMPORARY SURFACE PIPELINE MAP
TEMPORARY SURFACE
FRESHWATER PIPELINE
CountyGarfield
EXISTING LOCATION:
SKR #698-10-BV PAD
D1
A2 A1
C
B2
B1
A4
A3
B3
A5
B7
D2 A8
A8
A9 A10
A6
B4
B6
E1
B10
A7
B5A1
B8
B9
MATCH LINE
SEE SHEET 2 OF 9 A11
3 MILE OFFSET FROM TEMPORARY
SURFACE FRESHWATER PIPELINE
T6S
T5S
R
98
W
R
97
W
EXISTING LOCATION:
PICEANCE BASIN SKINNER
RIDGE WATER MANAGEMENT
FACILITY (FRESH WATER POND)
OWNERSHIP DESIGNATION
SEE LAND OWNERSHIP DESIGNATION TABLE
CHEVRON U.S.A. INC.
ENGINEERING & LAND SURVEYING
UELS, LLC
Corporate Office * 85 South 200 East
Vernal, UT 84078 * (435) 789-1017
DRAWN BY
SURVEYED BY SCALE
SKR 698-10-BV TEMPORARYSURFACE FRESHWATER PIPELINET5S, R98W & T6S, R98W & T7S, R98W & T7S, R97W &T8S, R97W, 6th P.M. GARFIELD COUNTY, COLORADO
D.P.11-07-25 1" = 5000'
TEMPORARY SURFACE PIPELINE MAP
PIPELINE
LOCATION
CountyMesa
CountyGarfield
MATCH LINE
SEE SHEET 1 OF 9
EXISTING LOCATION:
SKR #698-10-BV PAD
D2
A9
A10 A6
B6
E1
B10B9
A11
E1
E1
D1
B11
B12
B13
B14
A12 F1
F1
B15
B16
A13
B17
A14
B18
B19
B20
B20
G
H1
I
J
K
L
MN1
N2OP1
P2
Q
R1
B21
S
S
T
R
98
W
R
97
W
R
98
W
R
97
W
T7S
T6S
MATCH LINE
SEE SHEET 3 OF 9
OWNERSHIP DESIGNATION
SEE LAND OWNERSHIP DESIGNATION TABLE
TEMPORARY SURFACE
FRESHWATER PIPELINE
3 MILE OFFSET FROM
TEMPORARY SURFACE
FRESHWATER PIPELINE
R
99
W
R
98
W
EXISTING SKINNER RIDGE-
66S98W/ 22NENW PAD
CHEVRON U.S.A. INC.
ENGINEERING & LAND SURVEYING
UELS, LLC
Corporate Office * 85 South 200 East
Vernal, UT 84078 * (435) 789-1017
DRAWN BY
SURVEYED BY SCALE
SKR 698-10-BV TEMPORARYSURFACE FRESHWATER PIPELINET5S, R98W & T6S, R98W & T7S, R98W & T7S, R97W &T8S, R97W, 6th P.M. GARFIELD COUNTY, COLORADO
D.P.11-07-25 1" = 4000'
TEMPORARY SURFACE PIPELINE MAP
PIPELINE
LOCATION
CountyMesa
CountyGarfield
MATCH LINE
SEE SHEET 2 OF 9 E1 F1B17
A14B20Q1
R1
B21
S
S
TR
98
W
R
97
W
MATCH LINE
SEE SHEET 4 OF 9
T8S
T7S
S
B22
E2
R2
R3
B23
B24
U1U2
A15
A16
A17
B25 B26
A44
B26
B27
CG
OWNERSHIP DESIGNATION
SEE LAND OWNERSHIP DESIGNATION TABLE
TEMPORARY SURFACE
FRESHWATER PIPELINE
3 MILE OFFSET FROM
TEMPORARY SURFACE
FRESHWATER PIPELINE
CHEVRON U.S.A. INC.
ENGINEERING & LAND SURVEYING
UELS, LLC
Corporate Office * 85 South 200 East
Vernal, UT 84078 * (435) 789-1017
DRAWN BY
SURVEYED BY SCALE
SKR 698-10-BV TEMPORARYSURFACE FRESHWATER PIPELINET5S, R98W & T6S, R98W & T7S, R98W & T7S, R97W &T8S, R97W, 6th P.M. GARFIELD COUNTY, COLORADO
D.P.11-07-25 1" = 5000'
TEMPORARY SURFACE PIPELINE MAP
GARFIELD CO.
MESA CO.
R
98
W
R
97
W
PIPELINE
LOCATION
CountyMesa
CountyGarfield
MATCH LINE
SEE SHEET 3 OF 9
A17
B25
B26
A44
B27
U3U4
R4
R5R6R7
R8
R7
B28
A18
B29 B30
B31
A20
A19
A21
H2 H3
H4H5
H6
A22
A23
A24
W
F2
A25
SEE SHEET 5 OF 9
A25
A26
X U5
Y Z
V1
AB AC
AD
AE AF
AG
AH1AI F3
T9S
T8S
CG
OWNERSHIP DESIGNATION
SEE LAND OWNERSHIP DESIGNATION TABLE
TEMPORARY SURFACE
FRESHWATER PIPELINE
3 MILE OFFSET FROM TEMPORARY
SURFACE FRESHWATER PIPELINE
EXISTING LOCATION:
KOBE PUMP & TANKS
CountyGarfield
CHEVRON U.S.A. INC.
ENGINEERING & LAND SURVEYING
UELS, LLC
Corporate Office * 85 South 200 East
Vernal, UT 84078 * (435) 789-1017
DRAWN BY
SURVEYED BY SCALE
SKR 698-10-BV TEMPORARYSURFACE FRESHWATER PIPELINET5S, R98W & T6S, R98W & T7S, R98W & T7S, R97W &T8S, R97W, 6th P.M. GARFIELD COUNTY, COLORADO
D.P.11-07-25 1" = 1000'
TEMPORARY SURFACE PIPELINE MAP
R
97
W
PIPELINE
LOCATION
CountyMesa
SEE SHEET 6 OF 9
T8S
B30
A23
A24
F2
A25
A25
A26
U5
Y Z
V1
AD
F3
AJ1
A27 AJ2
AK1
AL
AM
AN AO
AP AQ AR
A28
A28
A29
A30
AT
AS1
A31A32 A33
A28
A28 A34 A31
A35
A36 A37
A38 A38
A39
A40 A41 A42
A43
AU
AH2
AH3
AV1 AV2
AW
AA1
AS2
OWNERSHIP DESIGNATION
SEE LAND OWNERSHIP DESIGNATION TABLE
3 MILE OFFSET FROM
TEMPORARY SURFACE
FRESHWATER PIPELINE
CH
CountyGarfield
CHEVRON U.S.A. INC.
ENGINEERING & LAND SURVEYING
UELS, LLC
Corporate Office * 85 South 200 East
Vernal, UT 84078 * (435) 789-1017
DRAWN BY
SURVEYED BY SCALE
SKR 698-10-BV TEMPORARYSURFACE FRESHWATER PIPELINET5S, R98W & T6S, R98W & T7S, R98W & T7S, R97W &T8S, R97W, 6th P.M. GARFIELD COUNTY, COLORADO
D.P.11-07-25 1" = 300'
TEMPORARY SURFACE PIPELINE MAP
R
97
W
T8S
PIPELINE
LOCATION
CountyMesa
V1
AO
AS1
A33
AW
AA2
AS2
AA
3
AA
4
AA5
AY
V2
V3
AZ
AK2BA
BB
BC
BD
BE
BF
BG1
BG2
BG3
BG4
BG5 BG6
BH1
BH2
BH3
BH4
BH5 BH6 BH6
BI1
BI2
BI1
BJ BK
BL
BM
BN
BOBP1
BQ
BR
BS
BT
BUBG7
BG8
BG9
BG10BG11
BG12
BG13
BG14BG15
BG16
BG17
BG18
BG19
BG20
BG21
BG22
BG23
BG24
BV
1
BV
2
BV
3
BV
4
BW1
BW2
BX1
BX2
BX
3
BY1
BY2
BZ
CA
CB
CC
CD
CE
CF
AX
BP2
OWNERSHIP DESIGNATION
SEE LAND OWNERSHIP DESIGNATION TABLE
3 MILE OFFSET FROM TEMPORARY
SURFACE FRESHWATER PIPELINE
CHEVRON U.S.A. INC.
ENGINEERING & LAND SURVEYING
UELS, LLC
Corporate Office * 85 South 200 East
Vernal, UT 84078 * (435) 789-1017
DRAWN BY
SURVEYED BY
D.P.11-07-25
TEMPORARY SURFACE PIPELINE MAP
LAND OWNERSHIP TABLE
DESIGNATION LAND OWNER
A1 CHEVRON USA INC
PARCELL ID#
213916300014
A2 CHEVRON USA INC213917400016
A3 CHEVRON USA INC213913100005
A4 CHEVRON USA INC213715300009
A5 CHEVRON USA INC213728300004
A6 CHEVRON USA INC213732100008
A7 CHEVRON USA INC216701400020
A8 CHEVRON USA INC216708100002
A9 CHEVRON USA INC216721200008
A10 CHEVRON USA INC216716100007
A11 CHEVRON USA INC216715100022
A12 CHEVRON USA INC216727100010
A13 CHEVRON USA INC241304100002
A14 CHEVRON USA INC241310200015
A15 CHEVRON USA INC241325100016
A16 CHEVRON USA INC241336200017
A17 CHEVRON USA INC244312400006
A18 CHEVRON USA INC244517200009
A19 CHEVRON USA INC2445-173-00-030
A20 CHEVRON USA INC2445-184-00-031
A21 CHEVRON USA INC2445-174-00-032
A22 CHEVRON USA INC2445-201-00-033
A23 CHEVRON USA INC2445-201-00-034
A24 CHEVRON USA INC2445-213-00-151
A25 CHEVRON USA INC2445-213-00-178
A26 CHEVRON USA INC2445-294-00-140
A27 CHEVRON USA INC2445-204-00-128
A28 CHEVRON USA INC2445-282-00-001
A29 CHEVRON U S A INC ETAL2445-282-00-002
A30 CHEVRON USA INC2445-282-00-004
A31 CHEVRON USA INC2445-282-00-014
A32 CHEVRON USA INC2445-282-00-006
A33 CHEVRON USA INC2445-281-00-010
A34 CHEVRON USA INC2445-282-00-007
A35 CHEVRON USA INC2445-282-00-008
A36 CHEVRON USA INC2445-294-00-048
A37 CHEVRON USA INC2445-283-00-009
A38 CHEVRON USA INC2445-283-00-012
A39 CHEVRON USA INC2445-284-00-020
A40 CHEVRON USA INC2445-294-00-050
A41 CHEVRON USA INC2445-294-00-049
A42 CHEVRON USA INC2445-283-00-010
A43 CHEVRON USA INC2445-283-00-011
LAND OWNERSHIP TABLE
DESIGNATION LAND OWNERPARCELL ID#
B1 BUREAU OF LAND MANAGEMENT213921400953
B2 BUREAU OF LAND MANAGEMENT213911100952
B3 BUREAU OF LAND MANAGEMENT213707100951
B4 BUREAU OF LAND MANAGEMENT216703300951
B5 BUREAU OF LAND MANAGEMENT216704400952
B6 BUREAU OF LAND MANAGEMENT216709400953
B7 BUREAU OF LAND MANAGEMENT213935300956
B8 BUREAU OF LAND MANAGEMENT216512100954
B9 BUREAU OF LAND MANAGEMENT216512400955
B10 BUREAU OF LAND MANAGEMENT216711300954
B11 BUREAU OF LAND MANAGEMENT216715400955
B12 BUREAU OF LAND MANAGEMENT216722200956
B13 BUREAU OF LAND MANAGEMENT216723300957
B14 BUREAU OF LAND MANAGEMENT216727200958
B15 BUREAU OF LAND MANAGEMENT216734100963
B16 BUREAU OF LAND MANAGEMENT216734300964
B17 BUREAU OF LAND MANAGEMENT241311200951
B18 BUREAU OF LAND MANAGEMENT216734200962
B19 BUREAU OF LAND MANAGEMENT216733400961
B20 BUREAU OF LAND MANAGEMENT216732100960
B21 BUREAU OF LAND MANAGEMENT241108200954
B22 BUREAU OF LAND MANAGEMENT241134200956
B23 BUREAU OF LAND MANAGEMENT241322200953
B24 UNITED STATES OF AMERICA241321400007
B25 BUREAU OF LAND MANAGEMENT244303300951
B26 BUREAU OF LAND MANAGEMENT244510100951
B27 BUREAU OF LAND MANAGEMENT244507200952
B28 BUREAU OF LAND MANAGEMENT244518200953
B29 BUREAU OF LAND MANAGEMENT2443-164-00-002
B30 BUREAU OF LAND MANAGEMENT2445-194-00-002
B31 BUREAU OF LAND MANAGEMENT2445-153-00-001
C EV RANCH LLLP213915300006
D1 BRANDED ROCK CANYON LLC213934200009
D2 BRANDED ROCK CANYON LLC216502400001
E1 MAHOGANY ENERGY RESOURCES LLC216736200023
E2 MAHOGANY ENERGY RESOURCES LLC241110100015
F1 LARAMIE ENERGY LLC216921400026
F2 LARAMIE ENERGY LLC2445-204-00-271
F3 LARAMIE ENERGY LLC2445-293-00-282
G 241304200003
H1 CROSSEN, TAMMIE LEE216733300018
QB ENERGY OPERATING LLC
PRAIRIE ENERGY PARTNERS LLC
NOTE: PARCEL DATA SHOWN HAS BEEN OBTAINED FROM VARIOUS
SOURCES AND SHOULD BE USED FOR MAPPING, GRAPHIC AND
PLANNING PURPOSES ONLY. NO WARRANTY IS MADE BY UINTAH
ENGINEERING AND LAND SURVEYING (UELS) FOR ACCURACY OF
THE PARCEL DATA.
SKR 698-10-BV TEMPORARYSURFACE FRESHWATER PIPELINET5S, R98W & T6S, R98W & T7S, R98W & T7S, R97W &T8S, R97W, 6th P.M. GARFIELD COUNTY, COLORADO
A44 CHEVRON USA INC244504300002
CHEVRON U.S.A. INC.
ENGINEERING & LAND SURVEYING
UELS, LLC
Corporate Office * 85 South 200 East
Vernal, UT 84078 * (435) 789-1017
DRAWN BY
SURVEYED BY
D.P.11-07-25
TEMPORARY SURFACE PIPELINE MAP
R2 HIGH LONESOME RANCH LLC241316200006
241513400002
244311300012
244310400010
244310100009
244309100001
244310200008
241108200011
241108200012
241327400014
241327200009
244312300004
U4 FURR, DAVID L244311400011
U5 FURR, DAVID LEWIS2445-214-00-196
W DONALD, JAMES PAUL, ETAL2445-212-00-018
X PRITCHARD, DELBERT L, ETAL2445-213-00-120
Y JOHNSON, KAYTLYNN SHILLING & THOMAS MIKE 2445-214-00-027
Z SHILLING, SAMUEL2445-214-00-026
AA1 BUMGARDNER, RICHARD W & THOMAS, REBECCA C 2445-281-00-011
AA2 BUMGARDNER, RICHARD W & THOMAS, REBECCA C2445-281-00-034
AA3 BUMGARDNER, RICHARD W & THOMAS, REBECCA C2445-281-00-033
AA4 BUMGARDNER, RICHARD W & THOMAS, REBECCA C2445-281-13-002
AA5 BUMGARDNER, RICHARD W & THOMAS, REBECCA C2445-281-13-003
R3 HIGH LONESOME RANCH LLC
R4 HIGH LONESOME RANCH LLC
R5 HIGH LONESOME RANCH LLC
R6 HIGH LONESOME RANCH LLC
R7 HIGH LONESOME RANCH LLC
R8 HIGH LONESOME RANCH LLC
U3 FURR, DAVID L
U2 FURR, DAVID L
U1 FURR, DAVID L
T SAVAGE LIMITED PARTNERSHIP I & ANDERSON
S JOJO PROPERTIES LLC
V1 TOWN OF DEBEQUE2445-223-00-001
V2 TOWN OF DEBEQUE2445-272-19-004
V3 TOWN OF DEBEQUE2445-281-00-039
LAND OWNERSHIP TABLE
DESIGNATION LAND OWNERPARCELL ID#
H3 CROSSEN, TAMMIE LEE, ETAL2445-171-00-230
H4 CROSSEN, TAMMIE LEE, ETAL2445-174-00-238
H5 CROSSEN, TAMMIE LEE, ETAL2445-172-00-235
H6 CROSSEN, TAMMIE LEE, ETAL2445-174-00-237
I PRITCHARD, CHARLES E & REBECCA A216733300017
J VAUGHN, WANETA A216732400016
K GRECO, AUSTEN SIMPSON216732200025
L REED, JEFFREY A216732300028
M EASTWOOD, JEFFERY S216732200027
N1 HOHENBERGER, EVELYN M216731100032
N2 HOHENBERGER, EVELYN M216731100031
O BARKER, KENNETH C & TERRI LYNN216731100030
P1 RAMTHUN, LOWELL E & REBECCA MARIA216730300029
P2 RAMTHUN, LOWELL E & REBECCA MARIA216730300033
Q ISLAND MOUNTAIN FARM LLC241504100001
R1 HIGH LONESOME RANCH LLC241309400004
AC VONGOGH, ERIC A, ETAL2445-304-00-227
AD KAUPP REAL ESTATE LLC2445-293-00-218
AE KUHN, DARREL LOYD & SUZANNE CHERI2445-304-00-228
AF GUERRA, JORGE R & RASCON, JESSICA I2445-304-00-280
AG VON DREELE, JAMES A2445-304-00-279
AH1 RED ROCK GATHERING COMPANY LLC2445-293-00-172
AH2 RED ROCK GATHERING COMPANY LLC2445-293-00-284
AH3 RED ROCK GATHERING COMPANY LLC2445-294-03-002
AI HEIDEL, KIM2445-293-00-283
AJ1 SHARON FAMILY TRUST2445-204-00-275
AJ2 SHARON FAMILY TRUST2445-204-00-277
AK1 JOINT SCHOOL DISTRICT NO 492445-213-00-281
AK2 JOINT SCHOOL DISTRICT NO 492445-272-00-205
AL MCATLIN, KAREN SUE2445-214-00-197
AM ROAN CREEK LAND AND CATTLE TRUST2445-213-00-278
AN ROSE, JAMES LAVERNE2445-213-00-188
AO ROAN CREEK LAND TRUST2445-214-00-148
AP BENJAMIN J DESIMONE TRUST2445-214-00-024
AQ SHELEY, BRIAN CHRISTOPHER2445-214-00-165
AR KN GAS GATHERING INC2445-214-00-163
AS1 BOHL, KENNETH P, ETAL 2445-214-00-180
AS2 BOHL, KENNETH P, ETAL2445-214-00-179
AT STEWART RANCH LTD2445-282-00-003
AU HOWELL, DANIEL & KAYLA L2445-293-00-270
AV1 MORROW, MICHAEL A2445-294-00-046
AV2 MORROW, MICHAEL A2445-294-00-047
AW ROAN CREEK ASSOC2445-281-00-038
AX KISER, BENETT, ETAL2445-281-10-006
AY GRAHAM, CORI E2445-281-00-031
AZ SPH INVESTMENTS LLC2445-272-20-001
BA 2445-281-00-018
BB DILLON, REBECCA & BRENDAN P2445-281-00-036
BC CHRISTEN, SARA JANE2445-281-00-035
BD ANDERSON DAVID W2445-281-24-001
BE 2445-281-24-002
BF HENDERSON, HARVEY JAMES & DONNA LEE2445-281-24-003
BG1 JONES-DEBEQUE PROPERTIES LLC 2445-281-25-001
BG2 2445-281-25-002
BG3 2445-281-25-003
BG4 2445-281-25-004
SALAZAR, RAUDEL JR &
ORTA, SAMANTHA VALERIA PAREDES
GOMEZ, JERONIMO CID &
GALLEGOS, ELIZABETH MARTINEZ
JONES-DEBEQUE PROPERTIES LLC
JONES-DEBEQUE PROPERTIES LLC
JONES-DEBEQUE PROPERTIES LLC
LAND OWNERSHIP TABLE
DESIGNATION LAND OWNERPARCELL ID#
NOTE: PARCEL DATA SHOWN HAS BEEN OBTAINED FROM VARIOUS
SOURCES AND SHOULD BE USED FOR MAPPING, GRAPHIC AND
PLANNING PURPOSES ONLY. NO WARRANTY IS MADE BY UINTAH
ENGINEERING AND LAND SURVEYING (UELS) FOR ACCURACY OF
THE PARCEL DATA.
SKR 698-10-BV TEMPORARYSURFACE FRESHWATER PIPELINET5S, R98W & T6S, R98W & T7S, R98W & T7S, R97W &T8S, R97W, 6th P.M. GARFIELD COUNTY, COLORADO
H2 CROSSEN, TAMMIE LEE, ETAL2445-172-00-236 AB ORTEGO, NICKIE LEE & SMITH, REBECCA LYNNE2445-304-00-229
CHEVRON U.S.A. INC.
ENGINEERING & LAND SURVEYING
UELS, LLC
Corporate Office * 85 South 200 East
Vernal, UT 84078 * (435) 789-1017
DRAWN BY
SURVEYED BY
D.P.11-07-25
TEMPORARY SURFACE PIPELINE MAP
BV4 ZENTCO PROPERTIES & INVESTMENTS LLC2445-281-26-001
BW1 LAW, NICHOLAS W & CAROLYN A2445-281-26-004
BW2 2445-281-26-005
BX1 MARTINEZ, GARY E & SONJA R2445-281-09-005
BX2 MARTINEZ, GARY E & SONJA R2445-281-09-002
BX3 MARTINEZ, GARY E & SONJA R2445-281-09-004
BY1 SOTO, ADELA & JORGE A2445-281-09-014
BY2 SOTO, ADELA & JORGE A2445-281-09-013
BZ ARVIZO, RITA2445-281-09-015
CA TWDD ENTERPRISES LLC2445-281-10-010
CB HOCKINS, THOMAS W & DANETTE D2445-281-10-009
CC HALL, BRIAN2445-281-10-011
CD RICE, JONATHAN DAVID2445-281-10-012
CE LEBEAU, KIRSTEN & VAN POOLLEN, MAARTEN2445-281-10-003
CF MALOTT, KARLY D2445-281-10-013
LAND OWNERSHIP TABLE
DESIGNATION LAND OWNERPARCELL ID#
BG6 2445-281-25-006
BG7 2445-281-26-019
BG8 2445-281-26-020
BG9 2445-281-26-021
BG10 2445-281-26-022
BG11 2445-281-26-015
BG12 2445-281-26-016
BG13 2445-281-26-017
BG14 2445-281-26-018
BG15 2445-281-26-011
BG16 2445-281-26-012
BG17 2445-281-26-013
BG20 2445-281-26-006
BG21 2445-281-26-007
BG22 2445-281-26-008
BG23 2445-281-26-023
BG24 2445-281-26-003
BH1 LAKE FAMILY REVOCABLE TRUST2445-281-00-014
BH2 LAKE FAMILY REVOCABLE TRUST2445-281-00-012
BH3 LAKE FAMILY REVOCABLE TRUST2445-281-00-004
BH4 LAKE FAMILY REVOCABLE TRUST2445-281-00-013
BH5 LAKE FAMILY REVOCABLE TRUST2445-281-01-002
BH6 LAKE FAMILY REVOCABLE TRUST2445-281-02-001
BI1 GENTRY, DIANE2445-281-03-001
BI2 GENTRY, DIANE2445-281-03-003
BJ ADAMS, DILLON 2445-281-03-002
BK SAVOCA, BOONE WHETSEL & SARAH ROSE2445-281-03-004
BL BERRY, JERRY D & CHERRIE L2445-281-04-007
BM DIXON, ZACH2445-281-04-006
BN RIGSBY, BRENNAN2445-272-01-033
BG18 2445-281-26-014
BG19 2445-281-26-024
JONES-DEBEQUE PROPERTIES LLC
JONES-DEBEQUE PROPERTIES LLC
JONES-DEBEQUE PROPERTIES LLC
JONES-DEBEQUE PROPERTIES LLC
JONES-DEBEQUE PROPERTIES LLC
JONES-DEBEQUE PROPERTIES LLC
JONES-DEBEQUE PROPERTIES LLC
JONES-DEBEQUE PROPERTIES LLC
JONES-DEBEQUE PROPERTIES LLC
JONES-DEBEQUE PROPERTIES LLC
JONES-DEBEQUE PROPERTIES LLC
JONES-DEBEQUE PROPERTIES LLC
JONES-DEBEQUE PROPERTIES LLC
JONES-DEBEQUE PROPERTIES LLC
JONES-DEBEQUE PROPERTIES LLC
JONES-DEBEQUE PROPERTIES LLC
JONES-DEBEQUE PROPERTIES LLC
JONES-DEBEQUE PROPERTIES LLC
JONES-DEBEQUE PROPERTIES LLC
BO GREENING, RICHARD W2445-281-08-020
BP1 OPEN BIBLE FELLOWSHIP2445-281-07-015
BP2 OPEN BIBLE FELLOWSHIP2445-281-07-016
BQ RIDDLE, DAVID A & GAYLE M2445-281-07-006
BR COLLINS, CORRINNA A2445-281-07-012
BS REEL, WINFREAD DAVID2445-281-07-011
BT HERNANDEZ, BRYAN J2445-281-07-010
BU SEARCY, MICHELLE L & HERWICK, VICKIE L2445-281-07-009
BV1 ZENTCO PROPERTIES & INVESTMENTS LLC2445-281-26-010
BV2 ZENTCO PROPERTIES & INVESTMENTS LLC2445-281-26-009
BV3 ZENTCO PROPERTIES & INVESTMENTS LLC2445-281-26-002
LAND OWNERSHIP TABLE
DESIGNATION LAND OWNERPARCELL ID#
CG KN ENERGY, INC244506400006
NOTE: PARCEL DATA SHOWN HAS BEEN OBTAINED FROM VARIOUS
SOURCES AND SHOULD BE USED FOR MAPPING, GRAPHIC AND
PLANNING PURPOSES ONLY. NO WARRANTY IS MADE BY UINTAH
ENGINEERING AND LAND SURVEYING (UELS) FOR ACCURACY OF
THE PARCEL DATA.
SKR 698-10-BV TEMPORARYSURFACE FRESHWATER PIPELINET5S, R98W & T6S, R98W & T7S, R98W & T7S, R97W &T8S, R97W, 6th P.M. GARFIELD COUNTY, COLORADO
BG5 2445-281-25-005 JONES-DEBEQUE PROPERTIES LLC
CH KOEHLER, DUSTIN R & ANTHONY L2445-294-03-001
LAW, NICHOLAS W & CAROLYN A
APPENDIX C
PIPELINE ROUTE
MAPS
SKR 698-10-BV
Temporary Surface
Freshwater Layflat
Pipeline
Garfield County, Colorado
34
CHEVRON U.S.A. INC.
ENGINEERING & LAND SURVEYING
UELS, LLC
Corporate Office * 85 South 200 East
Vernal, UT 84078 * (435) 789-1017
EXISTING LOCATION
LEGEND:
C
L
E
A
R
C
R
E
E
K
R
D
DRAWN BY
SURVEYED BY SCALE
D.R.B.02-27-24
R
98
W
C
O
U
N
T
Y
R
O
A
D
2
1
1
1" = 2000'
TEMPORARY SURFACE PIPELINE MAP
T6S
T5S
MAHOGANY ENERGY
RESOURCES LLC
PARCEL ID#216736200023
CHEVRON USA INC
PARCEL ID#213732100008
CH
E
V
R
O
N
U
S
A
I
N
C
PA
R
C
E
L
I
D
#
2
1
6
7
2
7
1
0
0
0
1
0
EXISTING LOCATION:
SKR #698-10-BV PAD
BRANDED ROCK CANYON LLC
BL
M
Existing CHEVRON USA INC
SKR-65S98W #35NWNE
Location ID: 336045
Existing CHEVRON USA INC
PRODUCED WATER MGMT TANKS
Location ID: 420402
Existing CHEVRON USA INC
SKR-65S98W #35SENE
Location ID: 324427
Existing CHEVRON USA INC
SKR-65S98W #36NWSW
Location ID: 336048
EXISTING LOCATION:
PICEANCE BASIN SKINNER
RIDGE WATER MANAGEMENT
FACILITY (FRESH WATER POND)
EXISTING SKINNER RIDGE-
66S98W/ 22NENW PAD
Existing CHEVRON USA INC
SKR-66S98W #4NESW
Location ID: 336049
CHEVRON USA INC
PARCEL ID
#216716100007
CHEVRON USA INC
PARCEL ID#213732100008
CHEVRON USA INC
PARCEL ID#213715300009
BL
M
BLM BLM
BLM
PARCEL ID#
216722200956
BL
M
P
A
R
C
E
L
I
D
#
21
6
7
2
7
2
0
0
9
5
8
MAHOGANY ENERGY
RESOURCES LLC
PARCEL ID#216736200023
MA
H
O
G
A
N
Y
E
N
E
R
G
Y
RE
S
O
U
R
C
E
S
L
L
C
PA
R
C
E
L
I
D
#
2
1
6
7
3
6
2
0
0
0
2
3
MAHOGANY ENERGY
RESOURCES LLC
PARCEL ID#216736200023
BOOSTER PUMP-5
CHEVRON USA INC
PARCEL ID#216715100022
R
98
W
R
97
W
SKR 698-10-BV TEMPORARYSURFACE FRESHWATER PIPELINET5S, R98W & T6S, R98W & T7S, R98W & T7S, R97W &T8S, R97W, 6th P.M. GARFIELD COUNTY, COLORADO
APPROXIMATE TOTAL TEMPORARY SURFACE PIPELINE "A", "B" & "C" DISTANCE = 94,774' +/-
TEMPORARY SURFACE PIPELINE
TEMPORARY SURFACE PIPELINE "A" (91,605)
NOTE: PARCEL DATA SHOWN HAS BEEN OBTAINED FROM VARIOUS SOURCES AND SHOULD BE USED FOR MAPPING, GRAPHIC AND PLANNING
PURPOSES ONLY. NO WARRANTY IS MADE BY UINTAH ENGINEERING AND LAND SURVEYING (UELS) FOR ACCURACY OF THE PARCEL DATA.
MATCH LINE
SEE SHEET 1 OF 3
BRANDED
ROCK
CANYON
LLC
BLM
PARCEL ID#
216715400955
BL
M
BL
M
BLM
BRANDED
ROCK
CANYON
LLC
PROPERTY LINE / TRACT LINE (APPROX.)
CHEVRON USA INC
PARCEL ID
#213916300014
BOOSTER PUMP-6
BOOSTER PUMP-7
REV: 3 01-14-26 D.P. (DESIGNATE PIPELINES AS "A", "B" & "C")
CHEVRON USA INC
PARCEL ID
#216708100002
CHEVRON USA INC
PARCEL ID
#216708100002 25K HYDRO
TOWER
EXISTING CULVERT
EXISTING COUNTY CULVERT
(2) 25K HYDRO TOWER
TEMPORARY SURFACE PIPELINE "B" (2,501')
TEMPORARY SURFACE PIPELINE "C" (668')
CHEVRON USA INC
PARCEL ID#
216721200008
MAHOGANY ENERGY
RESOURCES LLC
PARCEL ID#216736200023
CHEVRON U.S.A. INC.
ENGINEERING & LAND SURVEYING
UELS, LLC
Corporate Office * 85 South 200 East
Vernal, UT 84078 * (435) 789-1017
LEGEND:
DRAWN BY
SURVEYED BY SCALE
R
98
W
COU
N
T
Y
R
O
A
D
2
1
1
C
O
U
N
T
Y
R
D
2
0
4
T7S
T6S
CO
U
N
T
Y
R
D
2
0
4
CHEVRON USA INC
PARCEL ID#216721200008
QB ENERGY
OPERATING LLC
BLM
BLM
PARCEL ID#
216734100963
BLM
BLM
BLM
BLM
PARCEL ID#
241311200951
BLM
PARCEL ID#
241311200951
BLM
PARCEL ID#
241311200951
BLM
PARCEL ID#
241311200951
CHEVRON
USA INC
CHEVRON
USA INC
PARCEL ID#
241304100002
CHEVRON
USA INC
PARCEL ID#
241310200015
BOOSTER PUMP-4
BOOSTER PUMP-3
BOOSTER PUMP-2
SKR 698-10-BV TEMPORARYSURFACE FRESHWATER PIPELINET5S, R98W & T6S, R98W & T7S, R98W & T7S, R97W &T8S, R97W, 6th P.M. GARFIELD COUNTY, COLORADO
D.R.B.02-27-24 1" = 2000'
TEMPORARY SURFACE PIPELINE MAP
NOTE: PARCEL DATA SHOWN HAS BEEN OBTAINED FROM VARIOUS SOURCES AND SHOULD BE USED FOR MAPPING, GRAPHIC AND PLANNING
PURPOSES ONLY. NO WARRANTY IS MADE BY UINTAH ENGINEERING AND LAND SURVEYING (UELS) FOR ACCURACY OF THE PARCEL DATA.
MATCH LINE
SEE SHEET 1 OF 3
MATCH LINE
SEE SHEET 3 OF 3
TEMPORARY SURFACE PIPELINE "A" (91,605)
APPROXIMATE TOTAL TEMPORARY SURFACE PIPELINE "A", "B" & "C" DISTANCE = 94,774' +/-
MAHOGANY ENERGY
RESOURCES LLC
PARCEL ID#216736200023
MAHOGANY ENERGY
RESOURCES LLC
PARCEL ID#216736200023
MAHOGANY ENERGY
RESOURCES LLC
PARCEL ID#216736200023
CHEVRON
USA INC
PARCEL ID#
241310200015
CHEVRON
USA INC
PARCEL ID#
241325100016
CH
E
V
R
O
N
U
S
A
I
N
C
PA
R
C
E
L
I
D
#
2
1
6
7
2
7
1
0
0
0
1
0
BLM
PARCEL ID#
216732100960
BLM
PARCEL ID#
241322200953
BLM
PARCEL ID#
241322200953
HIGH LONESOME RANCH LLC
PARCEL ID# 241309400004
HIGH LONESOME
RANCH LLC
LAY-FLAT PIPE IN DITCH UNDER BRIDGE
EXISTING COUNTY CULVERT
EXISTING LOCATION
TEMPORARY SURFACE PIPELINE
PROPERTY LINE / TRACT LINE (APPROX.)
RESIDENTIAL
BUILDING UNIT
BUILDING
REV: 3 01-14-26 D.P. (DESIGNATE PIPELINES AS "A", "B" & "C")
CHEVRON U.S.A. INC.
ENGINEERING & LAND SURVEYING
UELS, LLC
Corporate Office * 85 South 200 East
Vernal, UT 84078 * (435) 789-1017
LEGEND:
DRAWN BY
SURVEYED BY SCALE
R
98
W
R
97
W
C
O
U
N
T
Y
R
D
2
0
4
T8S
T7S
EXISTING LOCATION:
KOBE PUMP & TANKS
BLM
PARCEL ID#
244507200952
BOOSTER PUMP-2
BOOSTER PUMP-1
SKR 698-10-BV TEMPORARYSURFACE FRESHWATER PIPELINET5S, R98W & T6S, R98W & T7S, R98W & T7S, R97W &T8S, R97W, 6th P.M. GARFIELD COUNTY, COLORADO
D.R.B.02-27-24 1" = 2000'
TEMPORARY SURFACE PIPELINE MAP
EXISTING LOCATION
TEMPORARY SURFACE PIPELINE
NOTE: PARCEL DATA SHOWN HAS BEEN OBTAINED FROM VARIOUS SOURCES AND SHOULD BE USED FOR MAPPING, GRAPHIC AND PLANNING
PURPOSES ONLY. NO WARRANTY IS MADE BY UINTAH ENGINEERING AND LAND SURVEYING (UELS) FOR ACCURACY OF THE PARCEL DATA.
MATCH LINE
SEE SHEET 2 OF 3
BLM
TEMPORARY SURFACE PIPELINE "A" (91,605')
BLM
PARCEL ID#
244518200953
GARFIELD CO.
MESA CO.
CHEVRON
USA INC
PARCEL ID#
241325100016
CHEVRON
USA INC
PARCEL ID#
241336200017
CHEVRON
USA INC
PARCEL ID#
241325100016
CHEVRON
USA INC
PARCEL ID#
241336200017
CHEVRON
USA INC
PARCEL ID#
244312400006
CHEVRON
USA INC
PARCEL ID#
244312400006
DAVID L FURR
JO
J
O
P
R
O
P
E
R
T
I
E
S
L
L
C
DA
V
I
D
L
F
U
R
R
BLM
PARCEL ID#
241322200953
BLM
PARCEL ID#
241322200953
BLM
PARCEL ID#
241322200953
BLM
PARCEL ID#
241322200953
BLM
PARCEL ID#
241134200956
BLM
PARCEL ID#
244303300951
BLM
PARCEL ID#
244303300951
BLM
PARCEL ID#
244510100951
BLM
PARCEL ID#
241134200956
BLM
PARCEL ID#
241108200954
BLM
PARCEL ID#
241311200951
DAVID L FURR
DAVID L FURR
PARCEL ID#
244312300004
HIGH LONESOME
RANCH LLC
CH
E
V
R
O
N
US
A
I
N
C
STORAGE AREA
(2) 60K MLVT
PUMP
RESIDENTIAL
BUILDING UNIT
BUILDING
KN ENERGY, INC
PARCEL ID#
244506400006
APPROXIMATE TOTAL TEMPORARY SURFACE PIPELINE "A", "B" & "C" DISTANCE = 94,774' +/-
PROPERTY LINE / TRACT LINE (APPROX.)
REV: 3 01-14-26 D.P. (DESIGNATE PIPELINES AS "A", "B" & "C")
CHEVRON U.S.A. INC.
DRAWN BY
SURVEYED BY SCALE
SKR 698-10-BV TEMPORARYSURFACE FRESHWATER PIPELINET5S, R98W & T6S, R98W & T7S, R98W & T7S, R97W &T8S, R97W, 6th P.M. GARFIELD COUNTY, COLORADO
D.P.11-07-25 NONE
TEMPORARY SURFACE PIPELINE TABLE
UELS, LLC
Corporate Office * 85 South 200 East
Vernal, UT 84078 * (435) 789-1017ENGINEERING & LAND SURVEYING
TEMPORARY SURFACE PIPELINE "A" - LENGTH TABLE
FEETSECTIONPARCEL ID #LAND OWNER
213732100008 ±618'CHEVRON USA INCSECTION 36, T5S, R98W
CONTINUES ON SHEET 2 OF 2
SECTION 35, T5S, R98W 213732100008 ±540'CHEVRON USA INC
QTR QTR
SW 1/4 NW 1/4 (TRACT 103)
SE 1/4 NE 1/4 (TRACT 103)
SECTION 35, T5S, R98W 213732100008 ±508'CHEVRON USA INCNE 1/4 SE 1/4 (TRACT 103)
SECTION 36, T5S, R98W 213732100008 ±1,214'CHEVRON USA INCNW 1/4 SW 1/4 (TRACT 103)
SECTION 36, T5S, R98W 213916300014 ±67'CHEVRON USA INCNW 1/4 SW 1/4 (TRACT 110)
SECTION 36, T5S, R98W 213916300014 ±675'CHEVRON USA INCSW 1/4 SW 1/4 (TRACT 110)
SECTION 36, T5S, R98W 213732100008 ±197'CHEVRON USA INCSW 1/4 SW 1/4 (TRACT 108)
SECTION 36, T5S, R98W 213732100008 ±801'CHEVRON USA INCSE 1/4 SW 1/4 (TRACT 108)
SECTION 4, T6S, R98W 213732100008 ±441'CHEVRON USA INCSW 1/4 NW 1/4 (TRACT 108)
SECTION 4, T6S, R98W 213732100008 ±548'CHEVRON USA INCNW 1/4 SW 1/4 (TRACT 108)
SECTION 4, T6S, R98W 213732100008 ±690'CHEVRON USA INCSE 1/4 SW 1/4 (TRACT 40)
SECTION 9, T6S, R98W 213732100008 ±224'CHEVRON USA INCNE 1/4 NW 1/4 (TRACT 40)
SECTION 4, T6S, R98W 213732100008 ±704'CHEVRON USA INCSW 1/4 SE 1/4 (TRACT 40)
SECTION 9, T6S, R98W 213916300014 ±10'CHEVRON USA INCNW 1/4 NE 1/4 (TRACT 41)
SECTION 9, T6S, R98W 213732100008 ±1,214'CHEVRON USA INCSW 1/4 NE 1/4 (TRACT 40)
SECTION 9, T6S, R98W 213732100008 ±1,150'CHEVRON USA INCNW 1/4 SE 1/4 (TRACT 44)
SECTION 4, T6S, R98W ±1,496'CHEVRON USA INCNE 1/4 SW 1/4 (TRACT 108 & 40)213732100008
SECTION 9, T6S, R98W 213732100008 ±961'CHEVRON USA INCNW 1/4 NE 1/4 (TRACT 40)
SECTION 9, T6S, R98W 213732100008 ±665'CHEVRON USA INCNE 1/4 SE 1/4 (TRACT 44)
SECTION 9, T6S, R98W 213732100008 ±1,518'CHEVRON USA INCSE 1/4 SE 1/4 (TRACT 44)
SECTION 16, T6S, R98W 213732100008 ±1,488'CHEVRON USA INCNE 1/4 NE 1/4 (TRACT 44 & 72)
SECTION 16, T6S, R98W 213732100008 ±1,005'CHEVRON USA INCSE 1/4 NE 1/4 (TRACT 72)
SECTION 16, T6S, R98W 216721200008 ±351'CHEVRON USA INCSE 1/4 NE 1/4 (TRACT 77)
SECTION 16, T6S, R98W 216721200008 ±78'CHEVRON USA INCNE 1/4 SE 1/4 (TRACT 77)
SECTION 15, T6S, R98W 216721200008 ±1,320'CHEVRON USA INCNW 1/4 SW 1/4 (TRACT 77 & 75)
SECTION 15, T6S, R98W 213732100008 ±44'CHEVRON USA INCNW 1/4 SW 1/4 (TRACT 72)
SECTION 15, T6S, R98W 216721200008 ±1,309'CHEVRON USA INCSW 1/4 SW 1/4 (TRACT 75)
SECTION 15, T6S, R98W 216721200008 ±969'CHEVRON USA INCSE 1/4 SW 1/4 (TRACT 75)
SECTION 15, T6S, R98W 216722200956 ±119'BLMSE 1/4 SW 1/4 (TRACT 77)
SECTION 22, T6S, R98W 216721200008 ±453'CHEVRON USA INCNE 1/4 NW 1/4 (TRACT 75)
SECTION 22, T6S, R98W 216721200008 ±1,073'CHEVRON USA INCNW 1/4 NE 1/4 (TRACT 75)
SECTION 22, T6S, R98W 216721200008 ±232'CHEVRON USA INCSW 1/4 NE 1/4 (TRACT 75)
SECTION 22, T6S, R98W 216736200023 ±1,133'MAHOGANY ENERGY RESOURCES LLCSW 1/4 NE 1/4 (TRACT 95 & 96)
SECTION 22, T6S, R98W 216736200023 ±1,364'MAHOGANY ENERGY RESOURCES LLCNW 1/4 SE 1/4 (TRACT 96)
SECTION 22, T6S, R98W 216736200023 ±1,320'MAHOGANY ENERGY RESOURCES LLCSW 1/4 SE 1/4 (TRACT 96 & 98)
SECTION 27, T6S, R98W 216736200023 ±1,320'MAHOGANY ENERGY RESOURCES LLCNW 1/4 NE 1/4 (TRACT 98)
SECTION 27, T6S, R98W 216736200023 ±1,331'MAHOGANY ENERGY RESOURCES LLCSW 1/4 NE 1/4 (TRACT 98)
SECTION 27, T6S, R98W 216736200023 ±1,342'MAHOGANY ENERGY RESOURCES LLCNW 1/4 SE 1/4 (TRACT 98)
SECTION 27, T6S, R98W 216736200023 ±1,301'MAHOGANY ENERGY RESOURCES LLCSW 1/4 SE 1/4 (TRACT 98)
SECTION 27, T6S, R98W 216734100963 ±96'BLMSW 1/4 SE 1/4 (TRACT 117)
SECTION 34, T6S, R98W 216734100963 ±840'BLMNW 1/4 NE 1/4 (TRACT 117)
SECTION 34, T6S, R98W 216721200008 ±256'CHEVRON USA INCNW 1/4 NE 1/4 (TRACT 98)
SECTION 34, T6S, R98W 216721200008 ±459'CHEVRON USA INCNE 1/4 NW 1/4 (TRACT 98 & 113)
SECTION 34, T6S, R98W 216721200008 ±1,936'CHEVRON USA INCSE 1/4 NW 1/4 (TRACT 113 & 112)
SECTION 34, T6S, R98W 216721200008 ±336'CHEVRON USA INCSW 1/4 NW 1/4 (TRACT 113 & 112)
SECTION 34, T6S, R98W 216721200008 ±1,364'CHEVRON USA INCNW 1/4 SW 1/4 (TRACT 113)
SECTION 34, T6S, R98W 216721200008 ±1,331'CHEVRON USA INCSW 1/4 SW 1/4 (TRACT 113)
SECTION 34, T6S, R98W 241311200951 ±17'BLMSW 1/4 SW 1/4
SECTION 3, T7S, R98W 241311200951 ±770'BLMNW 1/4 NW 1/4 (LOT 4)
SECTION 4, T7S, R98W 241311200951 ±191'BLMNE 1/4 NE 1/4 (LOT 1)
SECTION 4, T7S, R98W 241304100002 ±545'CHEVRON USA INCNE 1/4 NE 1/4 (LOT 1)
SECTION 4, T7S, R98W 241304100002 ±629'CHEVRON USA INCSE 1/4 NE 1/4
SECTION 4, T7S, R98W 241310200015 ±130'CHEVRON USA INCSE 1/4 NE 1/4
SECTION 3, T7S, R98W 241310200015 ±1,007'CHEVRON USA INCSW 1/4 NW 1/4
SECTION 3, T7S, R98W 241310200015 ±920'CHEVRON USA INCNW 1/4 SW 1/4
SECTION 3, T7S, R98W 241311200951 ±101'BLMNW 1/4 SW 1/4
SECTION 3, T7S, R98W 241311200951 ±653'BLMNE 1/4 SW 1/4
SECTION 3, T7S, R98W 241310200015 ±9'CHEVRON USA INCNE 1/4 SW 1/4
SECTION 3, T7S, R98W 241310200015 ±1,628'CHEVRON USA INCSE 1/4 SW 1/4
SECTION 10, T7S, R98W 241310200015 ±816'CHEVRON USA INCNE 1/4 NW 1/4
SECTION 10, T7S, R98W 241310200015 ±997'CHEVRON USA INCNW 1/4 NE 1/4
SECTION 10, T7S, R98W 241310200015 ±1,864'CHEVRON USA INCSW 1/4 NE 1/4
SECTION 10, T7S, R98W 241311200951 ±83'BLMSW 1/4 NE 1/4
SECTION 10, T7S, R98W 241310200015 ±47'CHEVRON USA INCNW 1/4 SE 1/4
SECTION 10, T7S, R98W 241310200015 ±1,677'CHEVRON USA INCNE 1/4 SE 1/4
SECTION 10, T7S, R98W 241311200951 ±194'BLMNE 1/4 SE 1/4
SECTION 11, T7S, R98W 241311200951 ±86'BLMNW 1/4 SW 1/4
SECTION 11, T7S, R98W 241310200015 ±1,487'CHEVRON USA INCSW 1/4 SW 1/4
SECTION 14, T7S, R98W 241310200015 ±1,317'CHEVRON USA INCNW 1/4 NW 1/4
SECTION 14, T7S, R98W 241325100016 ±11'CHEVRON USA INCNW 1/4 NW 1/4
REV: 1 01-14-26 D.P. (ADD CHEVERON TO TABLE)
NOTE:
·SECTION CORNER AND PIPELINE RIGHT-OF-WAY HAVE NOT BEEN FIELD VERIFIED.
·ALL PIPELINE DISTANCES ARE APPROXIMATE AND THE PIPELINE LENGTH TABLE WAS CREATED BY USING
MAPS, GIS & GLO DATA AND NOT TO BE USED FOR LEGAL PURPOSES.
·PIPELINE SHAPEFILE DATA WAS PROVIDED BY CHEVRON U.S.A. INC. ON OCTOBER 2025
CHEVRON U.S.A. INC.
DRAWN BY
SURVEYED BY SCALE
SKR 698-10-BV TEMPORARYSURFACE FRESHWATER PIPELINET5S, R98W & T6S, R98W & T7S, R98W & T7S, R97W &T8S, R97W, 6th P.M. GARFIELD COUNTY, COLORADO
D.P.01-14-26 NONE
TEMPORARY SURFACE PIPELINE TABLE
UELS, LLC
Corporate Office * 85 South 200 East
Vernal, UT 84078 * (435) 789-1017ENGINEERING & LAND SURVEYING
SECTION 14, T7S, R98W
SECTION 14, T7S, R98W 241325100016 ±461'CHEVRON USA INC
QTR QTR
SW 1/4 NW 1/4
NW 1/4 SW 1/4
SECTION 14, T7S, R98W 241325100016 ±1,476'NE 1/4 SW 1/4
SECTION 14, T7S, R98W 241325100016 ±961'NW 1/4 SE 1/4
SECTION 14, T7S, R98W 241325100016 ±1,172'SW 1/4 SE 1/4
SECTION 14, T7S, R98W 241325100016 ±406'SE 1/4 SE 1/4
SECTION 23, T7S, R98W 241325100016 ±2,035'NE 1/4 NE 1/4
SECTION 24, T7S, R98W 241325100016 ±3'NW 1/4 NW 1/4
SECTION 24, T7S, R98W 241325100016 ±1,781'SW 1/4 NW 1/4
SECTION 24, T7S, R98W 241325100016 ±1,337'NW 1/4 SW 1/4
SECTION 24, T7S, R98W 241336200017 ±1,362'SW 1/4 SW 1/4
SECTION 25, T7S, R98W 241336200017 ±252'NE 1/4 NW 1/4
SECTION 25, T7S, R98W 241336200017 ±1,119'NW 1/4 NW 1/4
SECTION 25, T7S, R98W 241336200017 ±1,474'NE 1/4 SW 1/4
SECTION 25, T7S, R98W 241336200017 ±1,397'SE 1/4 SW 1/4
SECTION 36, T7S, R98W 241336200017 ±1,270'NE 1/4 NW 1/4
SECTION 24, T7S, R98W ±24'SW 1/4 SW 1/4 241325100016
SECTION 25, T7S, R98W 241336200017 ±1,405'SE 1/4 NW 1/4
TEMPORARY SURFACE PIPELINE "A" - LENGTH TABLE
FEETSECTIONPARCEL ID #LAND OWNER
241325100016 ±1,638'CHEVRON USA INC
TOTAL ±91,605'
SECTION 36, T7S, R98W 241336200017 ±293'NW 1/4 NE 1/4
SECTION 36, T7S, R98W 241336200017 ±1,559'SW 1/4 NE 1/4
SECTION 36, T7S, R98W 241336200017 ±596'NW 1/4 SE 1/4
SECTION 36, T7S, R98W 241336200017 ±1,092'NE 1/4 SE 1/4
SECTION 36, T7S, R98W 241336200017 ±936'SE 1/4 SE 1/4
SECTION 31, T7S, R97W 241336200017 ±1,074'SW 1/4 SW 1/4 (TRACT 57)
SECTION 31, T7S, R97W 241336200017 ±931'SE 1/4 SW 1/4 (TRACT 57)
SECTION 6, T8S, R97W 241336200017 ±43'NE 1/4 NW 1/4 (LOT 3)
SECTION 6, T8S, R97W 244312400006 ±1,265'NE 1/4 NW 1/4 (LOT 3)
SECTION 6, T8S, R97W 244312400006 ±1,323'SE 1/4 NW 1/4
SECTION 6, T8S, R97W 244312400006 ±1,245'NE 1/4 SW 1/4
SECTION 6, T8S, R97W 244312400006 ±239'NW 1/4 SE 1/4 (LOT 12)
SECTION 6, T8S, R97W 244312400006 ±1,612'SW 1/4 SE 1/4
SECTION 7, T8S, R97W 244312400006 ±1,238'NW 1/4 NE 1/4
SECTION 7, T8S, R97W 244312400006 ±69'NE 1/4 NE 1/4
SECTION 7, T8S, R97W 244312400006 ±1,304'SE 1/4 NE 1/4
SECTION 7, T8S, R97W 244312400006 ±1,343'NE 1/4 SE 1/4
SECTION 7, T8S, R97W 244312400006 ±1,645'SE 1/4 SE 1/4
SECTION 18, T8S, R97W 244312400006 ±198'NE 1/4 NE 1/4
CHEVRON USA INC
CHEVRON USA INC
CHEVRON USA INC
CHEVRON USA INC
CHEVRON USA INC
CHEVRON USA INC
CHEVRON USA INC
CHEVRON USA INC
CHEVRON USA INC
CHEVRON USA INC
CHEVRON USA INC
CHEVRON USA INC
CHEVRON USA INC
CHEVRON USA INC
CHEVRON USA INC
CHEVRON USA INC
CHEVRON USA INC
CHEVRON USA INC
CHEVRON USA INC
CHEVRON USA INC
CHEVRON USA INC
CHEVRON USA INC
CHEVRON USA INC
CHEVRON USA INC
CHEVRON USA INC
CHEVRON USA INC
CHEVRON USA INC
CHEVRON USA INC
CHEVRON USA INC
CHEVRON USA INC
CHEVRON USA INC
CHEVRON USA INC
CHEVRON USA INC
CHEVRON USA INC
CHEVRON USA INC
SECTION 18, T8S, R97W 244312400006 ±437'NW 1/4 NE 1/4 CHEVRON USA INC
TEMPORARY SURFACE PIPELINE "B" - LENGTH TABLE
FEETSECTIONPARCEL ID #LAND OWNERQTR QTR
SECTION 16, T6S, R98W 213732100008 ±203'CHEVRON USA INCSE 1/4 NE 1/4 (TRACT 72)
SECTION 15, T6S, R98W 216721200008 ±771'CHEVRON USA INCSW 1/4 NW 1/4 (TRACT 72)
SECTION 15, T6S, R98W 216721200008 ±1,527'CHEVRON USA INCNW 1/4 NW 1/4 (TRACT 72)
TEMPORARY SURFACE PIPELINE "C" - LENGTH TABLE
FEETSECTIONPARCEL ID #LAND OWNERQTR QTR
SECTION 22, T6S, R98W 216721200008 ±527'CHEVRON USA INCNE 1/4 NW 1/4 (TRACT 75)
SECTION 22, T6S, R98W 216721200008 ±141'CHEVRON USA INCNW 1/4 NE 1/4 (TRACT 75)
TOTAL ±2,501'
TOTAL ±668'
NOTE:
·SECTION CORNER AND PIPELINE RIGHT-OF-WAY HAVE NOT BEEN FIELD VERIFIED.
·ALL PIPELINE DISTANCES ARE APPROXIMATE AND THE PIPELINE LENGTH TABLE WAS CREATED BY USING
MAPS, GIS & GLO DATA AND NOT TO BE USED FOR LEGAL PURPOSES.
·PIPELINE SHAPEFILE DATA WAS PROVIDED BY CHEVRON U.S.A. INC. ON OCTOBER 2025
APPENDIX D
SURFACE USE
AGREEMENT-BLM
ROW
SKR 698-10-BV
Temporary Surface
Freshwater Layflat
Pipeline
Garfield County, Colorado
34
Mahogany SUA
\lilll!Il lll11111||IIIll II Ill IIlli llIll IllII lil llIllill 22 O &1
710363 11/02/2006 04:16P B1860 PS M ALSDORF
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RIGHT-OF-WAY EASEMENT
FOR AND IN CONSIDERATIONof the sum of TEN AND NO/100 DOLLARS ($10.00)and
other good and valuable consideration,in hand paid to Shell Frontier Oil &Gas Inc.whose
mailing address is P.O.Box 576,200 N.Dairy Ashford Road,Houston,TX 77001,(hereinafter
referred to as GRANTOR,),the receipt and sufficiency of which is hereby acknowledged,by
Chevron U.S.A.Inc.,whose mailing address is P.O.Box 36366,Houston,TX 77236,its
successors and assigns,(hereinafter referred to as GRANTEE),GRANTOR hereby grants,sells,
conveys and warrants to GRANTEEa permanent easement,fifty (50)feet in width,for the purpose
at any time and from time to time to lay,locate,construct,maintain,inspect,alter,repair,operate,
protect,change the size of,replace,relocate,mark,remove and/or abandon in place,multiple lines
and appurtenances,equipment and facilities useful or incidental thereto,including,but not limited
to,valves,metering and corrosion control equipment,and any above-ground appurtenances,as may
be necessary or convenient,for the transportation of fiber optic cable,water,natural gas,petroleum,
petroleum products,liquids and derivatives thereof,upon and along a route to be selected by
GRANTEE on,over,across and through lands owned by GRANTOR,or in which GRANTOR
has an interest,situated in Garfield County,State of Colorado described as follows:
Sections 22 &27,Township 6 South,Range 98 West
In addition to the fifty (50)feet permanent easement area as defined above,GRANTOR grants to
GRANTEE a temporary easement seventy-five (75)feet in width for the purpose of enabling
GRANTEE to initially construct the pipeline.After the post-construction cleanup following the
initial pipeline construction,the permanent easement area shall be limited to a strip fifty (50)feet
wide as referenced above.The permanent easement,located on the above described lands is
generally described on Exhibit "A"attached hereto and made a part hereof.Exhibit "A"attached
hereto is not intended to show the final location of the easement or pipeline as actually constructed;
the actual location of the easement will extend twenty-five (25)feet on each side of the centerline of
the pipeline as actually laid.
GRANTOR further grants and conveys unto GRANTEE the right of unimpaired ingress and
egress on,over,across and through the above-described lands including other lands owned,leased
or claimed by GRANTOR which are adjacent thereto or contiguous therewith for all purposes
necessary or incidental to the exercise of the rights herein granted,with the further right of entry to
maintain the easement herein granted clear of trees,undergrowth,brush,structures,and any other
items,to the extent GRANTEE deems necessary in the exercise of the rights granted herein.
GRANTEE shall not be liable for damages caused by keeping said easement clear of trees,
undergrowth,brush,structures,or any other obstructions.GRANTEE agrees to compensate
GRANTOR for loss or damages caused by GRANTEE,its agents or employees to persons,
property or livestock,including that of its surface lessee,if any.
GRANTEE shall have the right to select,change,and/or alter the right-of-way easement through
the property above described or alter the route prior to or during construction with the consent of the
GRANTORwhich will not be unreasonably withheld or delayed.GRANTORshall have the right
to use and enjoy the above-described premises;provided however,GRANTOR shall not exercise
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such use and enjoyment in a manner that will impair or interfere with the exercise by GRANTEE
of any of the rights herein granted.GRANTOR shall not to change the grade over the pipeline
constructed hereunder and shall not build,create,construct,or permit to be built,created,or
constructed,any obstruction,building,lake,engineering works,or any other type of structure over
or on said easement without advance written consent of GRANTEE.
All equipment or appurtenances to the pipeline,which shall be on or above the surfàce of the
ground,shall be installed in a manner to protect the GRANTOR'S livestock when necessary.
GRANTEE agrees that during construction of said pipeline,livestock crossings will be provided
where necessary.Further,all fences that must be severed or removed for installation and
maintenance will be reinforced prior to severing adjacent to where the cut is made to prevent
damage to the fence line.Temporary gates to preclude the escape of GRANTOR'S livestock
shall be installed where necessary.All fences that are cut or removed shall be restored in as good
a condition as existed prior to installation of the pipeline.
GRANTEE agrees at the time of construction to bury said pipeline to such depth as will not
interfere with lands under cultivation,and in accordance with applicable Federal and State
regulations.Following installation of the pipeline (s),GRANTEE agrees to restore the ground as
nearly as is practicable,to its condition prior to the installation of the pipeline (s)and in
accordance with Federal regulations.
GRANTEE shall pay taxes,assessments or public charges levied or imposed upon its Easement
or upon other personal property,improvements or fixtures owned or placed by it within the
Easement subject to its right to contest same,provided that in no event shall Grantee permit its
Easement to be sold for tax purposes.In the event said taxes,assessments or public charges are
not separately assessed,then promptly following written notice from Grantor,Grantee shall
reimburse Grantor for any taxes,assessments or public charges attributable to its Easement.
GRANTEE shall,at its sole expense,keep the lands subject to the easement granted herein free
and clear of all liens and encumbrances resulting from GRANTEE'S and its agents'activities on
the said lands and shall indemnify and hold harmless GRANTOR from and against any and all
liens,claims,demands,costs,and expenses,including,without limitation,reasonable attorneys'
fees and court costs,in connection with or arising out of any work done,labor performed,or
materials furnished with respect to or by GRANTEE and/or GRANTEE'Sagent.
GRANTEE,its consultants,agents,employees,successor and/or assigns warrant and agree that
they will comply with any and all laws,ordinances,orders,rules,regulations,standards and
licensing requirements of any state,federal,municipal or local authority or agency having
jurisdiction,now in force and effect or which may be passed,enacted,issued,revised,required
or later promulgated,incident to or arising out of or in any way connected with Grantee's
utilization of the Easement or any activity conducted under,pursuant to or by virtue of the
Agreement.Grantee agrees that it will not discharge,dump,bury or store for purposes of
treatment or disposal,pollutants of any kind on the Easement including,but not limited to,
pollutants such as oil,chemicals,toxic substances or materials,hazardous wastes or hazardous
substances,including pollutants as the same may be defined,now or in the future,in any federal,
state,or municipal laws,rules,regulations or ordinances.Grantee specifically agrees to fully
Page 2 of 4
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indemnify and hold Grantor harmless from and against all claims,demands,losses,costs of
removal and/or clean up of pollutants,judgments,causes of actions,fines,penalties,costs,
including,but not limited to,reasonable attorney's fees and costs of court,arising out of or
connected with Grantees noncompliance with the terms of this Agreement.
It is expressly made a condition of the Easement that if GRANTEE,its successors or assigns,shall
abandon the Easement or any portion of said Easement for the stated purposes of the Easement,then
and in the event,all the rights herein granted shall cease and terminate with respect to the Easement
so abandoned,and the title to said Easement shall be freed from the burden of said Easement;and it
is further agreed that nonuse of the Easement or any portion thereof for the purposes of said
Easement for the period of Twenty-four (24)consecutive months along with an intent to abandon
shall constitute an abandonment.In the event of an abandonment of the Easement,GRANTEE
shall execute and record a re-conveyance and release and deliver to GRANTOR the recorded
instrument evidencing that the title to the Easement so abandoned is free and clear of the burden of
said Easement and free and clear of liens,encumbrances,clouds upon or defects in the title to said
Easement created or permitted to be created by GRANTEE.Surviving any termination,it shall be
Grantee's obligation to restore and reclaim all land affected by Grantee's activities to the extent
required by applicable law or regulation or to its equivalent prior condition,whichever is greater,
including,but not limited to,the removal of facilities.At a minimum,the affected area shall be re-
contoured and re-seeded with Natural Resources Conservation Service approved seed in a manner
to prevent erosion.
Notice under this Agreement may be made by one Party to the other in writing by United States
mails or be delivered in person to the following addresses:
Shell Frontier Oil &Gas Inc.Chevron U.S.A.Inc.
P.O.Box 576 P.O.Box 36366
Houston,TX 77001 Houston,TX 77236
Attn:Keith Etzel Attn:Land Manager
The contact information for either party hereto may be changed by
giving written notice of an address change to the other party at its then
current address for notice under this agreement.
This Easement shall be governed by and construed in accordance with the laws of the State of
Colorado,to the extent said laws do not conflict with any other federal statute.
TO HAVE AND TO HOLD unto GRANTEE,its successors and assigns,so long as the right
and easement herein granted,or any one of them shall be used by,or useful to GRANTEE for
the purposes herein granted and the provisions of this agreement are to be considered a covenant
that runs with the land herein described.The easement and rights herein granted may be transferred,
leased or assigned,from time to time,in whole or in part.It is agreed that any payment due
hereunder may be made direct to said GRANTOR.
Section 1445 Certification -Under penalties of perjury,the undersigned Grantor(s)hereby certifies
that it (they)is (are)not a non-resident alien,foreign corporation,foreign partnership,foreign trust
Page 3 of 4
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4 of 5 R 26.00 D 0.00 GARFIELD COUNTY CO
or foreign estate for purposes of U.S.income taxation.
EXECUTED as of this day of Co er
,2006.
Shell Frontier Oil &Gas Iric.Chevron U.S.A.Inc.
By:By:$.þ.
Its:/A A C Its:Attorney-in-Fact
STATE OF TEXAS )
)ss:
COUNTYOF (Ál )
This instrument was acknowledged before me on this f,2 day of /Ⱦ,
2006,by C-b.FyÎ,g þ¿'&,
the Attorney-in-Fact of Chevron U.S.A.
Inc.,on behalf of said corporatio
Notary Public,State of TexasMyCommissionExpires tary Public in and for said State and CountySeptember30,2008Date:§siding at:
STATE OF TEXAS )
)ss:
COUNTYOF Ñar NS )
This instrument was acknowledged before me on this (+L day of ,
2006,by S.D.Go'fC:n
,
the þ\orne 'a-Ed of Shell
Frontier Oil &Gas Inc.,on behalf of said corporation.
MY COMMISSION EXPIRES
Notary Public in and for said State and County
Date:(9 -I N -01 Residing at:Wo.s4e a TV
J
GAYLE KACAL
.Notary Public,State of TexasMyCommissionExpires
June 14,2007
Page 4 of 4
IIIIIIII IIIIllllll Illl!111||IIIIIIIIII IllII IIIIIIIIIll
710363 11/02/2006 04:16P B1860 P12 M ALSDORF
3 of 5 R 26.00 D 0.00 GARFIELD COUNTY CO
EXHIBIT "A"
CM.C SE CDR C 15,
Tes.Ree
1
768.
,
1924 GLO BG
SgELL
SH LL
··FRONTIER
FR0 TIE
SR 898 22-1 ,i
BLM
MT
ms co RAN H
1914 GLo ác 5
SE COR.SEC 22.
T6S,RSSW
.
g
.1924 GLO BC
7902 LF OF PROPOSED w
--¯RICHT OF WAY
'
BLM
E COR SEC 28,
TBS.R98W SR 698 27-2
GETTY OIL Co.
c/o CHEVRON/TEXACO ,
'
'
U.S.A.INC.'
y .\
SR 698 28-2 /Lsa ese 27.
NELLER
PROPOSED RIGHT OF WAY ON SHELL FRONTIER LOCATED IN
SECTIONS 22,&27,TOWNSHIP 6 SOUTH,RANGE 98 WEST
OF THE SIXTH PRINCIPAL MERIDIAN,GARFIELD COUNTY,
COLORADO
p coNemuotioN sumvaYo,iNo.SILY COLO.0012 SUNRISE IBLVD,SURVEYED:SCALE:1°=1500'
SILT,CO 816&2 DRAFTED:09-20-05 DWG:SR-PROP-8PL(310)S16-5153 CHECKED:SHEET:1 of i
BLM ROW
APPENDIX E
PRE-APPLICATION
MEETING
SUMMARY
SKR 698-10-BV
Temporary Surface
Freshwater Layflat
Pipeline
Garfield County, Colorado
34
1
Community Development Department
108 8th Street, Suite 401
Glenwood Springs, CO 81601
(970) 945-8212
www.garfield-county.com
PRE-APPLICATION
CONFERENCE SUMMARY
TAX PARCEL NUMBER: Multiple,
primarily serving 213732100008
DATE: 10/2/2025
PROJECT: SKR 698-10-BV Temp Surface Lay Flat Lin
OWNERS: Multiple – provide with application
CONTACT/REPRESENTATIVE: Tracey Fallang - Chevron
PRACTICAL LOCATION: Off of County Road 211on parcel, northwest of the town of
Parachute
TYPE OF APPLICATION: Pipeline
ZONING: Resource Lands
COMPREHENSIVE PLAN: Resource Lands
I. GENERAL PROJECT DESCRIPTION
A lay-flat, temporary pipeline will serve the SKR 698-10-BV well pad with water from the
Kobe Pump station, north of the Town of De Beque. The pipeline will be approximately 13.4
miles long and may be up to 16 inches in diameter. The pipeline will largely be adjacent to
existing 2-track access road, that is roughly parallel to County Roads 204 and 211.
Minimum vegetation disturbance will be done as part of this lay flat line. Areas with steeper
slopes may require some t-posts with braces to secure the line. The line will primarily be on
property owned by Chevron, but it will impact a parcel owned by Mahogany Energy and two
parcels owned by the BLM. The preapplication materials estimated that the line will be in
place for 6-8 months. The pipeline may cross the County Roads in a few areas.
The applicant should work with Road and Bridge on permissions/permits for crossing the
roadway. The Land Use Application will need to address the crossings.
Pipelines are reviewed under Article 9 of Garfield County’s Land Use and Development
Code. Pipeline Application Submittal Requirements are found in Section 9-102 of the LUDC.
2
A checklist of these requirements is included further in this summary, but it is the applicant’s
responsibility to provide all materials and respond to all review criteria found in the LUDC.
The application will need to show authorization for work on all impacted properties, including
ownership, surface use agreements, and/or BLM right of way as appropriate. A diagram
showing adjacent properties and approximate location/use of buildings within 350 of the
ROW is required. The application will need to explain what facilities will be installed,
construction schedule, as well as what other permitting is required. Information on sensitive
environmental areas needs to be prepared by a qualified professional and included in the
application. Reclamation, revegetation, and a Soil management plan is required, as is a
weed management plan. The application will need to provide an Emergency Response
Plan, show the general location of staging areas, address traffic impact (including estimated
construction traffic, and provide information on pressure testing, including the quantity and
legal source of water. The proposal’s limited disturbance and temporary use of the line will
play a role in the application’s submittals and review.
The application should also provide a response to the Review Criteria found in Section 9-
104.
Pipeline Applications are a modified version of the LUDC’s Administrative Review Permit
Process. The Review Process is found in Section 9-103 of the LUDC and summarized in a
flowchart below. The application should provide a list of all owners of real property within
200 feet of the route for notice. Staff will use the application’s route map and consult with
the applicant on the number and placement of notice posters. Notice does not need to be
done until the application is deemed Technically Complete and a decision date is
determined. Referral agencies will have 21 days to provide review comments to staff, once
the application is technically complete.
The application should include materials to fulfill any Waiver of Submittal Requirements
(Section 4-202) and Waiver of Standards (Section 4-118) requests. A full copy of the Land
Use and Development Code (LUDC) may be found here: https://www.garfield-
county.com/community-development/land-use-code/
II. COMPREHENSIVE PLAN
The proposal is within the Resource Lands FLUM designations. The application should
demonstrate conformance with Garfield’ County’s Comprehensive Plan.
III. REGULATORY PROVISIONS APPLICANT IS REQUIRED TO ADDRESS
Garfield County Land Use and Development Code, specifically sections:
Submittal Requirements, Section 9-102
3
Review Process, Section 9-103
Review Criteria, Section 9-104
IV. SUBMITTAL REQUIREMENTS
As a convenience, outlined below is a list of information typically required for this type of
application, taken from Section 9-102.
General Application Materials as described in Section 4-203
Vicinity Map as described in Section 4-203
Site Plan as described in Section 4-203 - because of the scale of the project, staff
will accept a site plan scale that does not specifically meet the requirements of
Section 4-203 provided that the document does not compromise a proper and
complete review.
Project Overview - 9-102 (D)
Property Ownership and Authority to File Application – Section 9-102 (E)
Adjacent Properties – Section 9-102(F)
o For individual rights-of-way, a diagram showing adjacent properties and the
approximate location of buildings and their uses within a distance of 350 feet
of any proposed structure, facility, or area to be disturbed.
Regulatory Permit Requirements – Section 9-102 (G)
o The permit agency name, permit/action driving task, and the task to be
performed to obtain the permit, prior to issuance of the permit by the County.
Primary Project Participants – Section 9-102 (H)
o The names, address, and phone numbers of the company representative;
company and individual acting as an agent for the company; construction
company contacts; and Federal and State agency contacts.
Project Facilities – Section 9-102 (I)
Construction Schedule – Section 9-102 (J)
o Hours of operation needs to be included.
Sensitive Area Survey – Section 9-102 (K)
Reclamation, Revegetation, and Soil Plan - Section 9-102 (L)
o Staff recommends that the applicant contact the Garfield County Vegetation
Manager prior to the submittal of the application.
Weed Management Plan – Section 9-102 (M)
Emergency Response Plan – Section 9-102 (N)
o Staff recommends the application contact the local Fire District in the area
prior to the submittal of an application
Traffic Impact – Section 9-102 (O)
4
o Staff recommends that the applicant contact Garfield County Road and
Bridge prior to the submittal of an application. The traffic impact should
address both construction and post construction impacts.
Staging Areas – Section 9-102 (P)
o The application should provide the general location of the staging areas
required for pipeline construction.
Pressure Testing – Section 9-102 (Q)
Community Development Staff is available to meet with the Applicant to provide additional
information and clarification on any of the submittal requirements and waiver requests.
V. REVIEW PROCESS
Call-Up for review by the Board in accordance with the procedures and review process
contained in Section 4-112.
Review by: Staff for completeness, recommendation, and referral agencies for additional
technical review.
5
Public Hearing(s): X No Public Hearing, Directors Decision (with notice per code)
Planning Commission
Board of County Commissioners
Board of Adjustment
Referral Agencies: Garfield County Road and Bridge Department, Garfield County
Environmental Health Manager, Garfield County Vegetation Manager, Garfield County
Consulting Engineer, Fire Protection Districts, Colorado Parks and Wildlife, Colorado
Department of Public Health and Environment, Air Quality Division, Mesa County;
Any other agency deemed appropriate upon review of the submittal.
VI. APPLICATION REVIEW FEES
Planning Review Fees: $400 (additional hours are billed at hourly rate of $40.50)
Referral Agency Fees: $TBD (Engineering review fee based on hourly rate)
Total Deposit: $400
VII. GENERAL APPLICATION PROCESSING
The foregoing summary is advisory in nature only and is not binding on the County. The
summary is based on current zoning, which is subject to change in the future, and upon
factual representations that may or may not be accurate. This summary does not create a
legal or vested right. The summary is valid for a six-month period, after which an update
should be requested. The Applicant is advised that the Application submittal once accepted
by the County becomes public information and will be available (including electronically) for
review by the public. Proprietary information can be redacted from documents prior to
submittal.
Pre-application Summary Prepared by:
10/2/2025
Philip Berry, Principal Planner Date
APPENDIX F
SKR 698-10-BV
ECMC FORM 2A
APPROVAL
Garfield County, Colorado
34
State of Colorado
Energy & Carbon Management 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
05/22
This Oil and Gas Location Assessment is to be submitted to the ECMC 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 ECMC website at
https://ecmc.state.co.us/ for all accompanying information pertinent this Oil and Gas Location Assessment.
Document Number:
403606035
12/07/2023
Date Received:
This Location includes a Rule 309.e.(2).E variance request.
This Location is within 2,640 feet of a GUDI or Type III Well per Rule 411.b.(4).
This Location or its associated new access road, utility, or Pipeline corridor meets Rule 309.e.(2).A, B, or C.
CONSULTATION
This location is included in a Comprehensive Area Plan (CAP). CAP ID #
X
This location includes a Rule 309.f.(1).A.ii. variance request.
DougDennison@Chevron.com
(970) 270 2853
( )
Doug Dennison
email:
Fax:
Phone:
Contact Information
Name:
81506COZip:State:GRAND JUNCTION
760 HORIZON DRIVE STE 401
CHEVRON USA INC
16700
City:
Address:
Name:
Operator
Operator Number:
FINANCIAL ASSURANCE FOR THIS LOCATION (check all that apply)
Plugging, Abandonment, and Reclamation 19810003
Gas Gathering, Gas Processing, and Underground Gas Storage Facilities
Centralized E&P Waste Management Facility
X
Federal Financial Assurance
In checking this box, the Operator certifies that it has provided or will provide at least this amount of Financial Assurance to the
federal government for one or more Wells on this Location.
Amount of Federal Financial Assurance $
Surface Owner Protection Bond.
New Location Refile Amend Existing Location #
If this Location assessment is a component of an Oil and Gas Development Plan (OGDP) application, enter the OGDP docket number(s).
Docket Number OGDP ID OGDP Name
231200362
If this Location assessment is part of an approved Oil and Gas Development Plan, enter the OGDP ID number(s).
OGDP ID Number OGDP Name
486609 OGDP SKR 698-10-BV
X 336056
Pad Number:SKR 698-10-BV Name:
LOCATION IDENTIFICATION
08/20/2027Expiration Date:
Location ID:336056
OGDP ID:486609
Page 1 of 23Date Run: 8/23/2024 Doc [#403606035]
06/29/20231.9 Date of Measurement:GPS Quality Value:
5833698W 6S 10 Ground Elevation:Meridian:Township:SWSW QuarterQuarter:Section:
Provide the location description and the latitude and longitude of a single point near the center of the Working Pad Surface as a
reference for this Location.
Range:
Type of GPS Quality Value:PDOP
Latitude:39.540312 Longitude:-108.321827
RELEVANT LOCAL GOVERNMENT SITING INFORMATION
GARFIELD Municipality:
Per § 34-60-106 (1)(f)(I)(A), the following questions pertain to the “Relevant Local Government approval of the siting of the
proposed oil and gas location.”
N/ACounty:
This proposed Oil and Gas Location is in an area designated as one of State interest and subject to the
requirements of § 24-65.1-108, C.R.S.
Yes
Does the Relevant Local Government regulate the siting of Oil and Gas Locations, with respect to this location?Yes
A siting permit application has been submitted to the Relevant Local Government for this proposed Oil and Gas Location:Yes
Date Relevant Local Government permit application submitted:03/15/2024
Current status or disposition of the Relevant Local Government permit application for this proposed Oil and Gas Location:In
Process
Status/disposition date:03/15/2024
If Relevant Local Government permit has been approved or denied, attach final decision document(s).
Provide the contact information for the Relevant Local Government point of contact for the local permit associated with this proposed
Oil and Gas Location:
Kirby H. WynnContact Name:Contact Phone:(970) 625 5905
Contact Email:KWynn@Garfiled-County.com
PROXIMATE LOCAL GOVERNMENT INFORMATION
For every Proximate Local Government (PLG) associated with this proposed Oil and Gas Location, provide the PLG’s point of
contact and their contact information.
< No row provided >
(Enter as many Related Locations as necessary. Enter the Form 2A document # only if there is no established COGCC Location ID#)
Well Site is served by Production Facilities 336050
This proposed Oil and Gas Location is:LOCATION ID #FORM 2A DOC #
RELATED REMOTE LOCATIONS
FEDERAL PERMIT INFORMATION
A Federal drilling permit (or related siting application) has been submitted for this proposed Oil and Gas Location: No
Date submitted:
Current status or disposition of the Federal drilling permit (or related siting application) for this proposed Oil and Gas
Location:
Status/disposition Date:
If Federal agency permit has been approved or denied, attach the final decision document(s).
Provide the contact information of the Federal point of contact for the Federal permit associated with this proposed Oil and Gas Location.
Contact Name:Contact Phone:
Contact Email:Field Office:
Page 2 of 23Date Run: 8/23/2024 Doc [#403606035]
Additional explanation of local and/or federal process:
Chevron has completed the Pre-Application process with Garfield County under application Skinner Ridge (SKR) 698-10-BV Pad, and
the application was submitted on 3/15/2024. Additional details are available within the Consultation Summary attachments.
No
10/12/2023Date of local government consultation:
Complete this section for any pre-application consultation related to this proposed Oil and Gas Location that occurred prior to the
submission of this Form 2A. If a pre-application Formal Consultation Process occurred, attach a Consultation Summary.
RELEVANT LOCAL GOVERNMENT OR FEDERAL PRE-APPLICATION CONSULTATION
Did a pre-application Formal Consultation Process occur with the Federal land manager per Rule 301.f.(3)?
Did a pre-application Formal Consultation Process occur with the Relevant Local Government per Rule 301.f.(3)?Yes
Date of federal consultation:
Was an ALA that satisfies Rule 304.b.(2).C (or substantially equivalent information per Rule 304.e) developed during a
federal or local government permit application process? If yes, attach the ALA to the Form 2A.
Yes
Complete this section for any pre-application consultation related to this proposed Oil and Gas Location that occurred prior to the
submission of this Form 2A. If a pre-application Formal Consultation Process occurred, attach a Consultation Summary.
ALA APPLICABILITY AND CRITERIA
If YES, indicate by checking the box for every Rule 304.b.(2).B criterion met by this proposed Location, and attach an ALA. See Rule
304.b.(2).B.i-x for full text of criteria.
Does the proposed Oil and Gas Location meet any of the criteria listed in Rule 304.b.(2)B?Yes
i. WPS < 2,000 feet from RBU/HOBU
ii. WPS < 2,000 feet from School/Child Care Center
iii. WPS < 1,500 feet from DOAA
iv. WPS < 2,000 feet from jurisdictional boundary and
PLG objects/requests ALA
v. WPS within a Floodplain
vi.aa. WPS within a surface water supply area
vi.bb. WPS < 2,640 feet from Type III or GUDI well
vii. WPS within/immediately upgradient of wetland/riparian corridor
viii. WPS within HPH and CPW did not waive
ix. Operator using Surface bond
X
x. WPS < 2,000 feet from RBU/HOBU/School within a DIC
X
Is the proposed Oil and Gas Location within the exterior boundaries of the Southern Ute Indian Reservation, and the Tribe
objects to the Location or requests an ALA? If YES, attach an ALA to the Form 2A.
Operator requests the Director waive the ALA requirement per Rule 304.b.
(2).A.i:
No
Provide an explanation for the waiver request, and attach supporting information (if necessary).
Page 3 of 23Date Run: 8/23/2024 Doc [#403606035]
ALTERNATIVE LOCATIONS DASHBOARD
List every alternative location reviewed and included in the ALA. Provide a latitude and longitude for the approximate center of the
alternative location, all Rule 304.b.(2).B Criteria met, if a variance would be required to permit the location, and a brief comment on the
key points of the alternative location.
#latitude longitude i ii iii iv v vi vii viii ix x Variance
Required?Comments
39.538721 -108.325703 x x Tier IV-B. Alternate Location 4 on
Narrative and Map.
39.567427 -108.337206 x x Tier IV-B. Alternate Location 6 on
Narrative and Map.
39.542650 -108.320672 x x Tier IV-A. Alternate Location 2 on
Narrative and Map.
39.551267 -108.329444 x x Tier IV-B. Alternate Location 5 on
Narrative and Map.
39.543102 -108.311161 x x Tier IV-A. Alternate Location 3 on
Narrative and Map.
39.567759 -108.323488 x Tier III-A. Alternate Location 1 on
Narrative and Map.
39.569193 -108.314118 x x Tier IV-B. Alternate Location 7 on
Narrative and Map.
304.b.(2).B.i-x Criteria Met:
SURFACE & MINERAL OWNERSHIP
Name:Chevron USA INC Phone:
Fax:PO Box 285
Address:
Address: Email:Ryan.Antonio@Chevron.com
City:Houston State:TX Zip:77001
Surface Owner Info:
X IndianFederalStateFeeSurface Owner at this Oil and Gas Location:
All operations on this Oil & Gas Location will develop the minerals beneath the Location, and the
Operator intends to use a surface bond per Rule 703 to secure access to this Location – attach lease
map or provide lease description.
All operations on this Oil & Gas Location will develop the minerals beneath the Location, and the
surface owner owns the minerals beneath this Location and is committed to an oil and gas lease –
attach lease map or provide lease description.
The Operator has a signed Surface Use Agreement for this Location – attach SUA.
The Operator/Applicant is the surface owner. Check only one:X
Minerals beneath this Oil and Gas Location will be developed from or produced to this Oil and Gas Location:
Mineral Owner beneath this Oil and Gas Location:
Surface Owner protection Financial Assurance type:Surety ID Number:
Lease description if necessary:N/A
X IndianFederalStateFee
Yes
N/A
Wells
Indicate the number and type of major equipment components planned for use on this Oil and Gas Location:
SITE EQUIPMENT LIST
2 Oil Tanks 0 Condensate Tanks 0 Water Tanks 0 Buried Produced Water Vaults 0
Page 4 of 23Date Run: 8/23/2024 Doc [#403606035]
Drilling Pits 0
Pump Jacks 0
Gas or Diesel Motors 0
Dehydrator Units 0
Production Pits 0
Separators 2
Electric Motors 0
Vapor Recovery Unit 0
Special Purpose Pits 0
Injection Pumps 0
Electric Generators 2
VOC Combustor 0
Multi-Well Pits 0
Heater-Treaters 0
Fuel Tanks 0
Flare 0
Modular Large Volume Tank 0
Gas Compressors 0
LACT Unit 0
Enclosed Combustion Devices 0
Pigging Station 2Meter/Sales Building 0 Vapor Recovery Towers 0
OTHER PERMANENT EQUIPMENT
Permanent Equipment Type Number
Chemical Injection Skids 1
Maintenance Tank 1
Ultrasonic Sales Gas Meter 1
Transformer 1
Instrument Air Skid 1
Solar Skids 1
Battery Box 1
Communication Tower 1
Scrubbers 1
A1 Pipe Skid 1
Heat Trace Equipment (Op. Comment)1
Electric Heat Trace Switchracks 1
Skid Drain Vaults 1
OTHER TEMPORARY EQUIPMENT
< No Row Provided >
FLOWLINE DESCRIPTION
Per Rule 304.b.(6), provide a description of all onsite and off-location oil, gas, and/or water flowlines.
Four (4): 2"-12" Steel or Composite Three-Phase Flowlines
One (1): 8-16” Steel or Composite Gas Line
One (1): 6” Steel or Composite Fiberspar Liquids Line
One (1): 14" Temporary Lay Flat Water Line
Two (2): 2" Poly Instrument Air Lines
GAS GATHERING COMMITMENT
Operator commits to connecting to a gathering system by the Commencement of Production Operations?
If the answer is NO, a Gas Capture Plan consistent with the requirements of Rule 903.e MUST be attached on the Plans tab.
Yes
Provide the distance and direction to the nearest cultural feature as measured from the edge of the Working Pad Surface.
Building:683 Feet
Designated Outside Activity Area:5280 Feet
Public Road:68 Feet
CULTURAL DISTANCE AND DIRECTION
Distance
NE
SE
SW
Direction
Rule 604.b Conditions Satisfied
(check all that apply):
604.b.
(1)Details of Condition(s)
604.b.
(2)
604.b.
(3)
604.b.
(4)
Residential Building Unit (RBU):5280 Feet S
High Occupancy Building Unit(HOBU)5280 Feet SE
Page 5 of 23Date Run: 8/23/2024 Doc [#403606035]
Above Ground Utility:38 Feet
Railroad:5280 Feet
Property Line:75 Feet
SE
SE
N
School Facility:5280 Feet
Child Care Center:5280 Feet
SE
SE
Disproportionately Impacted (DI)
Community:
0 Feet N
SEFeet5280RBU, HOBU, or School Facility
within a DI Community.
RULE 604.a.(2). EXCEPTION LOCATION REQUEST
Operator requests an Exception Location Request from Rule 604.a.(2) [well is less than 150 feet from a property line]. Exception
Location Request Letter and Waiver signed by offset Surface Owner(s) must be attached.
CULTURAL FEATURE INFORMATION REQUIRED BY
RULE 304.b.(3).B.
Provide the number of each Cultural feature identified within the following distances, as measured from the Working Pad Surface:
Building Units
Residential Building Units
High Occupancy Building Units
School Properties
School Facilities
Designated Outside Activity Areas 0
0
0
0
0
0
0-500 feet
0
0
0
0
0
0
501-1,000 feet
0
0
0
0
0
0
1,001-2,000 feet
Will a closed-loop drilling system be used?
Is H2S gas reasonably expected to be encountered during drilling operations at concentrations greater than
Will salt based (>15,000 ppm Cl) drilling fluids be used?
Will salt sections be encountered during drilling:
Estimated post-construction ground elevation:
Size of location after interim reclamation in acres:
6.86Size of disturbed area during construction in
acres:
CONSTRUCTION
2.35
DRILLING PROGRAM
Yes
No
Will oil based drilling fluids be used?Yes
5833
or equal to 100 ppm?If YES, attach H2S Drilling Operations Plan.No
No
Page 6 of 23Date Run: 8/23/2024 Doc [#403606035]
Drilling Fluids Disposal:
DRILLING WASTE MANAGEMENT PROGRAM
OFFSITE Commercial DisposalDrilling Fluids Disposal Method:
Cutting Disposal:OFFSITE Commercial DisposalCuttings Disposal Method:
Other Disposal Description:
Beneficial reuse or land application plan submitted?No
Reuse Facility ID:or Document Number:
Centralized E&P Waste Management Facility ID, if applicable:
CURRENT LAND USE
Other
Residential
RecreationForestry
CommercialIndustrial
Rangeland
Conservation Reserve Program (CRP)Non-IrrigatedIrrigated
Subdivided:
Non-Crop Land:
Crop Land:
Current Land Use: check all that apply per Rule 304.b.(9).
X
Describe the current land use:
Rangeland, existing storage pad.
Describe the Relevant Local Government’s land use or zoning designation:
Resource Lands
Describe any applicable Federal land use designation:
N/A
Other
Residential
RecreationForestry
CommercialIndustrial
Rangeland
Conservation Reserve Program (CRP)Non-IrrigatedIrrigated
Subdivided:
Non-Crop Land:
Crop Land:
Final Land Use: check all that apply per Rule 304.b.(9).
X
FINAL LAND USE
Reference Area Latitude:
If Final Land Use includes Non-Crop Land (as checked above), the following information is
required:
Describe landowner’s designated final land use(s):
REFERENCE AREA INFORMATION
Rangeland.
39.539335 -108.321337Reference Area Latitude:
Provide a list of plant communities and dominant vegetation found in the Reference Area.
Page 7 of 23Date Run: 8/23/2024 Doc [#403606035]
Plant Community Dominant vegetation
Native Grassland Inland Saltgrass
Native Grassland Big Sagebrush
Native Grassland Nuttall's Alkaligrass
Native Grassland Bottlebrush Squirreltail
Native Grassland Winterfat
Native Grassland Alkali Bluegrass
Native Grassland Mat Saltbush
Native Grassland Greasewood
Native Grassland Western Wheatgrass
Native Grassland Indian Ricegrass
Noxious weeds present:No
SOILS
List all soil map units that occur within the maximum extent of the proposed Oil and Gas Location. Attach the National
Resource Conservation Service (NRCS) report showing the "Map Unit Description" listing the typical vertical soil profile(s).
This data is to be used when segregating topsoil.
The required information can be obtained from the NRCS website at
https://www.nrcs.usda.gov/wps/portal/nrcs/surveylist/soils/survey/state/ or from the ECMC website GIS Online map page.
Instructions are provided within the ECMC website help section.
NRCS Map Unit Name:44 - Happle very channery sandy loam, 3 to 12 percent slopes
NRCS Map Unit Name:46 - Happle-Rock outcrop association, 25 to 65 percent slopes
NRCS Map Unit Name:
GROUNDWATER AND WATER WELL INFORMATION
Provide the distance and direction, as measured from the Working Pad Surface, to the nearest:
water well:1201 Feet W
Spring or Seep:5280 Feet NW
Estimated depth to shallowest groundwater that can be encountered at this Oil and Gas Location:Feet
Basis for estimated depth to and description of shallowest groundwater occurrence:
Depth to groundwater taken from water well permit 67475-F.
65
SURFACE WATER AND WETLANDS
Provide the distance and direction to the nearest downgradient surface Waters of the State, as defined
in the 100-Series Rules, measured from the Working Pad Surface:
Nearest surface water is a Riverine Habitat 148 feet southeast of the location, that was field verified by a third-party surveyor.
Feet SE148
If less than 2,640 feet, is the Waters of the State identified above within 15 stream miles upstream of a Public Water
System intake?No
Provide the distance and direction to the nearest downgradient wetland, measured from the Working
Provide a description of the nearest downgradient surface Waters of the State:
If the proposed Oil and Gas Location is within a Rule 411.a Surface Water Supply Area buffer zone, select the buffer
Pad Surface:SWFeet2640
zone type:
Page 8 of 23Date Run: 8/23/2024 Doc [#403606035]
If the proposed Oil and Gas Location is within a Rule 411.b GUDI/Type III buffer zone, select the buffer
Is a U.S. Army Corps of Engineers Section 404 permit required for the proposed Oil and Gas Location, access road, or
If a U.S. Army Corps of Engineers Section 404 permit is required, provide the permit status, and permit number if available:
zone type:
associated pipeline corridor?No
Public Water System Administrator - Contact Name Email
Public Water System Administrator - Contact Name Email
Is the Location within a Floodplain?No Floodplain Data Sources Reviewed (check all that apply):
Federal (FEMA)X State County Local
Does this proposed Oil and Gas Location lie within a Sensitive Area for water resources, as defined in the
Yes
Other
100-Series Rules?
CONSULTATION, WAIVERS, AND EXCEPTIONS
This Oil and Gas Location or associated new access road, utility, or pipeline corridor falls within federally designated
critical habitat or an area with a known occurrence for a federal or Colorado threatened or endangered species.
Provide description in Comments section of Submit tab.
X
When Rule 309.e.(2) Consultation must occur, check all that apply:
This location is included in a Wildlife Mitigation Plan
This Oil and Gas Location or associated new access road, utility, or pipeline corridor falls within an existing
conservation easement established wholly or partly for wildlife habitat. Provide description in Comments section of
Submit tab.
When Rule 309.e.(3) Consultation is not required, check all that apply:
This Oil and Gas Location has been included in a previously approved, applicable Wildlife Protection Plan.
This Oil and Gas Location has been included in a previously approved, applicable Wildlife Mitigation Plan.
This Oil and Gas Location has been included in a previously approved, applicable conservation plan.
Pre-application Consultation:
X A pre-application consultation with CPW, regarding this Oil and Gas Location, occurred
on:
10/12/2023
CPW Waivers and Exceptions (check all that apply and attach all CPW waivers to this Form
2A):
The applicant has obtained a Rule 304.b.(2).B.viii CPW waiver for the requirement to complete an ALA.
The applicant has obtained a Rule 309.e.(2).G CPW waiver and consultation is not required.
The applicant has obtained a Rule 309.e.(5).D.i CPW waiver and is requesting an exception from Rule 1202.c.
(1).R.
X The applicant has obtained a Rule 309.e.(5).D.ii CPW waiver and is requesting an exception from Rule 1202.c.
(1).S.
The applicant has obtained a Rule 309.e.(5).D.iii CPW waiver of Rule 1202.c.(1).T.
The applicant has obtained a Rule 309.e.(5).D.iv CPW waiver and is requesting an exception from Rule 1202.c.(1)
in accordance with an approved CAP.
X The applicant has obtained a Rule 1202.a CPW waiver.
Page 9 of 23Date Run: 8/23/2024 Doc [#403606035]
No BMP
Operator Proposed Wildlife BMPs
No Target Species BMP Type Description
1 MULE DEER & ELK Wildlife -
Minimization
If new oil and gas operations must occur within CPW-mapped mule
deer and elk severe winter range and/or winter concentration areas,
the operator agrees to conduct new oil and gas operations outside the
time period from December 1 through April 30.
CPW Proposed Wildlife BMPs
The applicant has obtained a Rule 1202.b CPW waiver.
In accordance with Rule 1203.a.(3), the applicant requests an exception from compensatory mitigation
Rule(s):
HIGH PRIORITY HABITAT AND COMPENSATORY MITIGATION
This Oil and Gas Location, associated access roads, utility, or Pipeline corridor falls wholly or partially within the following
High Priority Habitats (Note: dropdown options are abbreviated - see Rule 1202 for full rule text):
High Priority Habitat (list all that apply)
Oil and Gas
Location Access Road
Utility or Pipeline
Corridor
1202.c.(1).S - Sportfish mgmt waters, non-Gold
Medal x x
1202.d.(2) - Elk migration & winter x x x
The following questions are for Oil and Gas Locations that cause the density to exceed one Oil and Gas Location per
square mile in Rule 1202.d High Priority Habitat:
Direct Impacts:
Is Compensatory Mitigation required per Rule 1203.a for this Oil and Gas Location?
Is a Compensatory Mitigation Plan proposed to address direct impacts for this Oil and Gas Location?
Have all Compensatory Mitigation Plans been approved for this
Location?
If not, what is the current status of each Plan?
N/A
Is a Compensatory Mitigation Fee proposed for this Oil and Gas Location?
Direct impact habitat mitigation fee amount: $
Yes
Yes
Yes
13750
Yes
Indirect Impacts:
Is a Compensatory Mitigation Plan proposed to address indirect impacts for this Oil and Gas Location?
Have all Compensatory Mitigation Plans been approved for this
Location?
If not, what is the current status of each Plan?
N/A
Is a Compensatory Mitigation Fee proposed for this Oil and Gas Location?
Indirect impact habitat mitigation fee amount: $
Yes
Yes
Yes
No
Is Compensatory Mitigation required per Rule 1203.d for this Oil and Gas Location?
Page 10 of 23Date Run: 8/23/2024 Doc [#403606035]
2 MULE DEER & ELK Wildlife -
Minimization
Chevron will limit the placement of extensive linear barrier features (i.e.
fencing, surface lines, berms) that may impact Elk movement and
migration.
3 WILDLIFE MITIGATION
PLAN BMP
Wildlife -
Minimization
Chevron will install and maintain bird-deterrent devices on all open-
vent exhaust stacks on production equipment to discourage perching,
roosting and nesting activities.
4 WILDLIFE MITIGATION
PLAN BMP
Wildlife -
Minimization
Construction of pipeline infrastructure to provide takeaway of oil,
natural gas, and fresh and produced water from the development,
eliminating truck traffic and emissions associated with hauling product
from the oil and gas development and limiting vehicle/wildlife
interactions.
AIR QUALITY MONITORING PROGRAM
Will the Operator install and administer an air quality monitoring program at this Location?Yes
No BMP
Operator Proposed BMPs
CDPHE Proposed COAs OR BMPs
No BMP
PLANS
Total Plans
Uploaded:
13
(1) Emergency Spill Response Program consistent with the requirements of Rules 411.a.(4).B, 411.b.(5).B, & 602.j
(2) Noise Mitigation Plan consistent with the requirements of Rule 423.a
(3) Light Mitigation Plan consistent with the requirements of Rule 424.a
(4) Odor Mitigation Plan consistent with the requirements of Rule 426.a
(5) Dust Mitigation Plan consistent with the requirements of Rule 427.aX
X (6) Transportation Plan
X (7) Operations Safety Management Program consistent with the requirements of Rule 602.d
X (8) Emergency Response Plan consistent with the requirements of Rule 602.j
(9) Flood Shut-In Plan consistent with the requirements of Rule 421.b.(1)
(10) Hydrogen Sulfide Drilling Operations Plan consistent with the requirements of Rule 612.d
(11) Waste Management Plan consistent with the requirements of Rule 905.a.(4)X
(12) Gas Capture Plan consistent with the requirements of Rule 903.e
(13) Fluid Leak Detection PlanX
(14) Topsoil Protection Plan consistent with the requirements of Rule 1002.cX
(15) Stormwater Management Plan consistent with the requirements of Rule 1002.fX
X (16) Interim Reclamation Plan consistent with the requirements of Rule 1003
X (17) Wildlife Plan consistent with the requirements of Rule 1201
Page 11 of 23Date Run: 8/23/2024 Doc [#403606035]
X (18) Water Plan
X (19) Cumulative Impacts Plan
(20) Community Outreach Plan
X (21) Geologic Hazard Plan
VARIANCE REQUESTS
Check all that apply:
This proposed Oil and Gas Location requires the approval of a Rule 502.a variance from ECMC Rule or Commission
Order number:
ALL exceptions and variances require attached Request Letter(s). Refer to applicable rule for additional required attachments (e.g.
waivers, certifications, SUAs).
RULE 304.d LESSER IMPACT AREA EXEMPTION REQUESTS
Check the boxes below for all Exemptions being requested. Lesser Impact Area Exemption Request must be attached, and will include all
requested exemptions.
304.b.(1). Local Government Siting Information
304.b.(2). Alternative Location Analysis
304.b.(3). Cultural Distances
304.b.(4). Location Pictures
304.b.(5). Site Equipment List
304.b.(6). Flowline Descriptions
304.b.(7). Drawings
304.b.(8). Geographic Information System (GIS)
Data
304.b.(9). Land Use Description
304.b.(10). NRCS Map Unit Description
304.b.(11). Best Management Practices
304.b.(12). Surface Owner Information
304.b.(13). Proximate Local Government
304.b.(14). Wetlands
304.b.(15). Schools and Child Care Centers
304.c.(1). Emergency Spill Response Program
X 304.c.(2). Noise Mitigation Plan
304.c.(3). Light Mitigation Plan X
304.c.(4). Odor Mitigation Plan
304.c.(5). Dust Mitigation Plan
304.c.(6). Transportation Plan
304.c.(7). Operations Safety Management Program
304.c.(8). Emergency Response Plan
304.c.(9). Flood Shut-In Plan
304.c.(10). Hydrogen Sulfide Drilling Operations Plan
304.c.(11). Waste Management Plan
304.c.(12). Gas Capture Plan
304.c.(13). Fluid Leak Detection Plan
304.c.(14). Topsoil Protection Plan
304.c.(15). Stormwater Management Plan
304.c.(16). Interim Reclamation Plan
304.c.(17). Wildlife Plan
304.c.(18). Water Plan
304.c.(19). Cumulative Impacts Plan
304.c.(20). Community Outreach Plan
304.c.(21). Geologic Hazard Plan
Comments
OPERATOR COMMENTS AND SUBMITTAL
Page 12 of 23Date Run: 8/23/2024 Doc [#403606035]
DougDennison@Chevron.com
Manager Dev. Permitting
12/07/2023
Doug Dennison
ECMC Approved:Director of ECMC Date:8/23/2024
Based on the information provided herein, this Oil and Gas Location Assessment complies with ECMC Rules, applicable orders,
and SB 19-181 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.
Chevron is committed to connecting to a gathering system by the Commencement of Production Operations.
Chevron conducted a Garfield Pre-Application meeting with Garfield County on 10/12/23 and CPW staff attended the
meeting. Chevron has received a waiver from CPW for ECMC Rules 1202.c.(1).S. and 1202.a.(3). In addition, CPW has
reviewed and accepted Rule 1202.c.(2).C, as described within the CPW Waiver attachment. The proposed SKR 698-10-
BV well drill pad is an existing pad with an existing access road. The current use of this pad as an equipment storage
area results in regular vehicle traffic and activity on the site. It is not anticipated that the new wells on the pad will result in
significantly increased long-term indirect impacts. CPW has reviewed the need to off-set the unavoidable adverse indirect
impacts and decided that they will not recommend compensatory mitigation for the reasons mentioned.
The Heat Trace equipment that will be utilized to prevent freezing within the extended flowlines will utilize either a
propane tank with a small catalytic burner or an electric transformer powered by utility connections.
Completions operations on this Pad will utilize a MLVT staged on the nearby SKINNER RIDGE-66S98W/22NENW Pad,
permitted under Location ID# 324358, to the south.
Pad Soil types: 44 - Happle very channery sandy loam, 3 to 12 percent slopes; 46 - Happle-Rock outcrop association, 25
to 65 percent slopes
Access Soil types: 44 - Happle very channery sandy loam, 3 to 12 percent slopes
Flowline Corridor Soil types: 28 - Cumulic Haploborolls, 1 to 3 percent slopes; 44 - Happle very channery sandy loam, 3
to 12 percent slopes; 45 - Happle very channery sandy loam, 12 to 25 percent slopes; 46 - Happle-Rock outcrop
association, 25 to 65 percent slopes
The following 304.c Plans are Not required for this submittal:
• Emergency Spill Response Program; Not near Type III or GUDI well.
• Noise Mitigation Plan; Lesser Impact Area
• Light Mitigation Plan; Lesser Impact Area
• Odor Mitigation Plan; No RBUs within 2,000'
• Flood Shut-In Plan; Not in floodplain
• Hydrogen Sulfide Drilling Plan; No H2S in area
• Gas Capture Plan; Chevron is committed to a gathering system connection
• Community Outreach Plan; No RBUs within 2,000'
COA Type Description
0 COA
CONDITIONS OF APPROVAL, IF ANY LIST
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.
Page 13 of 23Date Run: 8/23/2024 Doc [#403606035]
Best Management Practices
No BMP/COA Type Description
1 General Housekeeping • Wastes stored onsite will be stored in compatible containers that are regularly
inspected to ensure they are in good condition and free of excessive wear, structural
issues or other defects that may impact their effectiveness.
• All trash receptacles will be designed, maintained, and operated to exclude wildlife,
and to protect public safety, the environment, and wildlife from exposure to
overflowing, leak prone or insecure trash receptacles.
• Chevron utilizes only licenses third-party transporters for all waste transport and
coordinates with Relevant Local Government on haul routes for transport of waste.
• Chevron will not bury or burn trash or other waste materials at an oil and gas
location.
• Some wastes generated from oil and gas operations have the potential to be subject
to TENORM regulation and, when required, will be disposed of at licensed facility
authorized to receive TENORM wastes. Chevron will comply with the requirements of
6 CCR 1007-1 Part 20 – Registration and Licensing of Technologically Enhanced
Naturally Occurring Radioactive Material (TENORM), which became effective on
January 14, 2021. Water-based Bentonitic Drilling Fluids: contained in steel tanks,
hauled to commercial facility
• Oil-based Drilling Fluids: returned up the annulus will be filtered to remove solids
through the closed loop system, cuttings shaken out into impervious bins above a mat
and hauled off-site for disposal while fluids will be routed through a suction tank and
mud pump, remixed and recirculated.
• Drill cuttings: contained in 3-sided high wall steel bins, hauled to commercial facility.
Frac sands: direct placement into truck, hauled to commercial facility during
completions, during flowback Frac sands: periodically drained via vacuum truck,
hauled to commercial facility
• Produced water: piped into existing infrastructure, private disposal by off-lease
injection. Produced water: piped into existing infrastructure, private disposal by off-
lease injection. Spill Response and Remediation : Soil impacted from spills of
production fluids: excavated and direct placement into dump trucks or storage bins,
hauled to commercial facility. Facility Decommissioning
• Any hazardous or non-hazardous waste generated, or equipment and materials
removed during decommissioning: characterized and segregated appropriately, hauled
to commercial facility ? Soil impacted from spills of production fluids: excavated and
direct placement into dump trucks or storage bins, hauled to commercial facility.`
2 General Housekeeping The pre-production potential for light and noise related impacts on wildlife will be
decreased at the OGDP SKR 698-10-BV location because Chevron intends to down-
shield lighting during drilling and completion. Chevron is also committed to performing
all construction, drilling and completion operations outside of the timing limitations for
Elk HPH. Additionally, limited permanent lighting will be located on the well pad and
will be switched so only on when in use, so long-term light and noise related impacts
would be limited to headlights and vehicle engine noise from operational vehicles on
location and enroute to and from the location during production. The majority of
production-related traffic at the well pad will be during daylight hours.`
3 Wildlife • Chevron will pre-clear all proposed disturbances according to CPW guidance
meeting Migratory Bird Treaty Act (MBTA), Bald and Golden Eagle Protection Act
(BGEPA) and Endangered Species Act (ESA) laws in protection of active nesting
activities, observe CPW/USFWS requested protected buffers for active nesting
species, and consult with CPW/USFWS as warranted.
• Chevron will install and maintain bird-deterrent devices on all open-vent exhaust
stacks on production equipment to discourage perching, roosting and nesting
activities.
• Employ Chevron’s Stormwater Management Program to protect soil resources,
minimize erosion, identify pollutants, apply pollutant control measures, and conduct
regular inspections.
• Although the project is using an existing pad, as necessary all interim and final
reclamation areas will be contoured and re-vegetated to a stable condition to restore
natural habitats for wildlife species.
• Chevron will meet weed management targets during construction, drilling, production
and reclamation lifecycles.
• Chevron commits to employ Noise, Light, Dust and Odor mitigation efforts meeting
ECMC Series 400 Rules in the protection of Wildlife Resources.
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• A general summary of wildlife BMP commitments under the Series 400 aesthetic
rules and incorporated by this WMP include: Prior to the commencement of
Drilling/Completion or Production Operations, Chevron will take all necessary and
reasonable precautions to ensure that lighting, dust, noise and odor from the Oil and
Gas Location does not unnecessarily impact the health, safety, and welfare of Wildlife
occupying any High Priority Habitat within 2,000 feet of the Oil and Gas Location. For
permanent facilities this includes: • Survey and document all active nests and dens
potentially impacted by production operations. Documentation will be available for
review.
• Conduct a daily walkthrough of the location to ensure no wildlife have built nest(s)
in/around lighting or noise sources. If nest(s) are found, HSE reporting will be issued to
appropriate personnel to either remove the nest and/or temporarily abandon the
lighting source until nest is abandoned.
• Inform and educate all field employees and contractors on wildlife conservation
practices, including no harassment or feeding of wildlife.
• Utilization of telemetry equipment for remote monitoring to limit in-person visitation by
production operations personnel.
• Institute the Chevron safety program meeting Operational Excellence Management
System initiatives and “Stop Work” authority.
• Construction of pipeline infrastructure to provide takeaway of oil, natural gas, and
fresh and produced water from the development, eliminating truck traffic and
emissions associated with hauling product from the oil and gas development and
limiting vehicle/wildlife interactions.
• Any encroachment of wetlands or active water ways potentially considered Waters of
the United States (WOTUS) will be reviewed and/or protected under USACE
Nationwide or General Permit processes.
• Chevron plans to schedule all construction, drilling, and completion activities outside
of Elk WCA protective timing stipulations (between April 16th and November 30th). If
Chevron is unable to complete all operations between April 16th and November 30th,
the operator will provide notice as soon as practical indicating that activities may be
occurring within Elk SWR/WCA season (December 1st thru April 14th) through direct
communication with CPW. Communication will include an estimated duration of the
planned operations within the HPH. Should Elk be identified in the area during
construction activities, Chevron will have a biologist on site periodically to monitor herd
response and determine any potential negative impacts from development activities
and discuss with CPW any mitigation efforts that could reduce these impacts.
• Chevron will limit the placement of extensive linear barrier features (i.e. fencing,
surface lines, berms) that may impact Elk movement and migration.
• Fencing used will be 3 or 4 strand to a maximum height of 42-inches.
• Chevron will quickly excavate, install, and reclaim linear pipeline features that may
impact Elk movement and migration. Chevron will take all necessary and reasonable
precautions to ensure that dust from the Oil and Gas Location does not unnecessarily
impact the health, safety, and welfare of Wildlife occupying any High Priority Habitat
within 2,000 feet of the Oil and Gas Location. These actions include: Identify
permanent and temporary housing of resident wildlife and ensure locations are
recorded in wildlife reports kept in-house by HSE. Conduct a daily walkthrough of the
location during ongoing operations to ensure no wildlife have built nest(s) in/around
equipment. If nest(s) are found, HSE reporting will be issued to appropriate personnel
to either remove the nest and/or temporarily abandon the equipment until nest is
abandoned.`
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4 Storm Water/Erosion
Control
• Stormwater channels will be constructed topographically downgradient of the working
pad surface and routed to detention ponds to prevent offsite migration of sediment or
contaminants into nearby surface water features. The channels and ponds will help
contain a potential on-site release and prevent contamination of un-plated soil.
Construction details for the channels and detention ponds are provided within the site-
specific Stormwater Management Plan.
• The surface of the location will be plated with 3-5 inches of compacted road base
aggregate that will deter releases from easily seeping into the soil. Structural CMs All
Phases •The post-interim reclamation facility pad area will include a permanent raised
berm between the facility maintenance tank and Deer Park Gulch. Additional CPW
commitments are addressed within the site-specific wildlife mitigation plan.
• Vehicle traffic controls such as rock stabilized construction exits, trackout control
mats, or cattle guards will be located on-site near location exits to prevent offsite
tracking of soils. The type of control measure will depend on local availability,
landowner request, and location specific needs. Any sediment tracked off-site will be
swept or scraped from roadways and returned to the construction site by the end of
each workday. No sediment will be washed, shoveled, or swept into any roadside
ditch, storm sewer, or surface waterbody. Controls will be maintained throughout the
life of the location.
• Stormwater on this location will drain predominantly to the south. Three channels,
one existing and two proposed, will be constructed along the perimeter of the working
pad surface. The channels will drain to two proposed detention ponds on the south
side of the location to reduce stormwater runoff volume and capture sediment.
• A diversion swale will be installed on the northwestern side of the location, to divert
run-on and prevent erosion.
• Existing topsoil stockpiles are located on the east side of the working pad surface
and will be protected against erosion with temporary seeding, hydromulch, surface
roughening, or a combination of erosion controls. Additional topsoil will be segregated,
stored, and stabilized as required per ECMC rules for future reclamation operations;
however, minimal topsoil excavation is anticipated during construction activities.
• Riprap will be installed at connections between channels and the detention pond to
reduce erosion.
• A culvert will be installed under the southeastern, existing access road to convey
stormwater from the drainage ditch to the proposed detention ponds.
• Mulch with netting or erosion control mats will be installed on all slopes 3:1 and
steeper and within 100' of special protection waters or 50' of surface waters.
• The three channels, two detention ponds, and one diversion swale will be maintained
after interim reclamation as long-term stormwater controls to reduce stormwater runoff
volumes and minimize sediment erosion at the location. The channels/swale, ponds,
reclaimed disturbance area, and disturbed topsoil stockpiles will be stabilized with
seeding, hydromulching, and/or surface roughening.
Non-Structural CMs
• Chevron will design the site with flatter slopes and utilize surface ripping/roughening,
and structural surface stabilization control measures including revegetation to increase
infiltration rates and minimize erosion potential.
• Grading – Grading involves reshaping the ground surface to design elevations.
Grading plans will be designed to provide more suitable topography for well pads and
pipelines and help to control runoff, soil erosion, and sediment during and after
construction in these areas.
• The site inspection schedule will be followed in compliance with all ECMC o Control
Measures (CMs) will be maintained and implemented as required based upon the
results of inspection. Construction Stage: At least one inspection every 7 calendar
days; OR At least one inspection every 14 calendar days, if post-storm event
inspections are conducted within 24 hours following precipitation which causes surface
erosion. Completed Stage: At least one inspection every 30 calendar days once
disturbance activities have ceased and the interim reclamation work has been
completed, except that the site has not yet been revegetated. Interim Stabilization
Stage: At least one inspection every 30 calendar days once the site has undergone
seeding. Final Stabilization Stage: At least once annually until the site is plugged and
abandoned (P&A). Bi-annual inspection site visits; or Quarterly visits for locations
with “elevated risk,” until location achieves 50% revegetation, with bi-annual
inspections thereafter. Regardless of initial risk categorization, locations with
corrective actions will be inspected within 14 days of the corrective measure
implementation to ensure satisfactory performance and then returned to their original
category.`
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5 Material Handling and Spill
Prevention
• Bulk storage containers 55 gallons or greater housed onsite for production operations
are stored in secondary containment;
• Use of drip pans and or sorbent materials during vehicle maintenance or material
handling;
• Properly cover/seal material containers;
• Conduct routine site inspections; • Promptly address corrective actions identified
during inspections;
• Maintain stormwater management structures and components;
• Routine trash collection and disposal;
• Properly labeling significant material containers;
• Promote quick spill response/clean up by familiarizing employees and contractors
with spill cleanup procedures; and
• Familiarize employees and contractors with good housekeeping procedures and
pollution prevention procedures.
• During drilling and completion operations, a temporary impermeable layer (e.g.,
synthetic, geosynthetic, cement-modified soil) will be utilized under equipment to
provide an additional layer of protection against spills. Secondary containment
devices, such as duck ponds or equivalent type products, will be used to protect soils
under any pipe connections or equipment that carry, mix, or could possibly leak fluids
or chemicals.
• Audible, Visual, and Olfactory (AVO) inspections of the facility will be conducted
regularly by Chevron. Any valve or fitting that is found to be ineffective will be repaired
immediately, or well shut-in procedures will be implemented.
• The location will be equipped with remote monitoring and shut-in capabilities.
• All flowlines will be designed/constructed/tested to ASME B31.4 and API 1104
standards. Only materials with Material Test Reports (MTRs) provided by the pipeline
supplier will be used in the construction of the flowlines.
• No pits will be used on location; therefore, pit level indicators will not be used on
location.
• Spill prevention and response will continue to be addressed in training of employees
and contractor personnel on at least an annual basis. spill : for protection of the
adjacent waterways and high priority habitats, the facility maintenance tank will be
constructed within an impervious, geosynthetic-lined under base, anchored into a
metal-sided secondary containment system capable of containing up to 150% of the
tanks capacity and any spill or leak from the storage vessel.
`
6 Material Handling and Spill
Prevention
During drilling and completion operations, a temporary impermeable layer (e.g.,
synthetic, geosynthetic, cement-modified soil) will be utilized under equipment to
provide an additional layer of protection against spills. Secondary containment
devices, such as duck ponds or equivalent type products, will be used to protect soils
under any pipe connections or equipment that carry, mix, or could possibly leak fluids
or chemicals. • Audible, Visual, and Olfactory (AVO) inspections of the facility will be
conducted regularly by Chevron. Any valve or fitting that is found to be ineffective will
be repaired immediately, or well shut-in procedures will be implemented. • The location
will be equipped with remote monitoring and shut-in capabilities. • All flowlines will be
designed/constructed/tested to ASME B31.4 and API 1104 standards. Only materials
with Material Test Reports (MTRs) provided by the pipeline supplier will be used in the
construction of the flowlines. • No pits will be used on location; therefore, pit level
indicators will not be used on location. • Spill prevention and response will continue to
be addressed in training of employees and contractor personnel on at least an annual
basis.`
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7 Dust control • All soil piles created by construction activities will be managed utilizing Hydro-mulch,
straw crimping, and/or tracking methods to prevent dust from exiting the location and
creating a hazard during pre-production activities.
• Soil piles will be graded and/or seeded to prevent erosion and the generation of dust
post-production.
• When Chevron is required to suppress dust, its selected vendor will be reminded of
the following: Use only fresh water sources (non-potable) when watering areas within
300 feet of the ordinary high-water mark of any water body. Maintain a current Safety
Data Sheet (SDS) in their company vehicle when using a dust suppressor containing
chemicals, in accordance with OSHA Standard 29 CFR 1910.1200 (Hazard
Communication) as well as local and State requirements. Ensure watering practices
are not creating additional hazards on access roads (slick roads, muddy conditions,
etc.).
• Chevron will minimize the amount of fugitive dust using speed restrictions. All
vehicles will be subject to a speed limit of 20 MPH on all lease roads to minimize dust.
• Chevron will mitigate the creation of fugitive dust through regular road maintenance
as coordinated through agreements with Garfield County and any Relevant Local
Governments or Agencies with road jurisdiction.
• Chevron will use methods including wind breaks and barriers, road or facility
surfacing, and soil stockpile stabilization measures to suppress fugitive dust caused
solely by wind.
• Chevron will avoid the creation of fugitive dust by restricting or limiting construction
activity during high wind days.
• Chevron will minimize fugitive dust caused by operations or dust originating from
areas disturbed by previous operations that becomes windborne by utilizing the dust
suppression methods mentioned above.
• Chevron will not use any of the following fluids for dust suppression: Produced water
from E&P waste or hazardous waste / Crude oil or any oil specifically designed for
road maintenance / Chemical solvents / Process fluids
• Access road(s) will be watered or treated with one of the following commercial dust
suppressants, as needed: Roadsaver (magnesium chloride) / Roadsaver Compaction
Aid (magnesium chloride) / DuraBlend (magnesium chloride)
• Prior to the application of dust suppressant to any county or public roads,
coordination will be conducted with Garfield County Department of Public Works by
Chevron and any relevant vendors.
• Chevron will maintain safety data sheets (“SDS”) for any chemical-based dust
suppressant and make the SDS immediately available upon request to the ECMC
Director, Garfield County, and to any other Local Government or Agency. Safety Data
Sheet(s) for any chemical-based dust suppressant will be archived and maintained
until the site passes final site Reclamation and transfer the records upon transfer of
property ownership.
• All secondary roads created for this project (non-public roadways) will be finished
with ½” – ¾” crushed stone road base.
• Silica dust from handling sand used in hydraulic fracturing operations will be
mitigated by utilization of the enclosed Sand Box delivery systems. As such, no
pneumatic transportation of sand will be conducted at this location.
• At the time of construction, all leasehold roads shall be constructed to accommodate
local emergency vehicle access requirements and shall be maintained in a reasonable
condition.
• Chevron will employ practices for control of fugitive dust caused by operations,
including speed restrictions, regular road maintenance, restriction of construction
activity during high wind days, and silica dust controls when handling sand used in
hydraulic fracturing operations. Additional management practices such as road
surfacing, wind breaks and barriers, or automation of wells to reduce truck traffic may
also be used to minimize fugitive dust emissions.`
8 Noise mitigation Noise during production operations at the well pad will be very limited. Visits to the pad
by lease operators will be normally occur only during daylight hours. All produced gas
and fluids will be piped from the well pad to the existing CPF which eliminates the
trucking of fluids from the well pad and the noise impacts associated with this trucking
Chevron will utilize a quiet frac fleet for completions operations`
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9 Emissions mitigation Chevron will not flare produced gas during normal operations. • Chevron will use
supervisory control and data acquisition (SCADA) systems to monitor well operations,
which will reduce emissions from vehicle traffic due to the reduced number of vehicle
trips to the site. • Chevron has 24/7 monitoring through the OCC that allows for
continuous monitoring of operating conditions when personnel are not on-site to
identify and correct any improper operations as soon as possible. • Chevron will
transport all fluids from the well pad to the CPF via buried pipelines which will
eliminate the truck traffic associated with transporting these fluids. • Chevron
completes regular audio/visual/olfactory observations at every active location which
provides early detection of equipment malfunctions thereby minimizing emissions from
leaks. • Chevron will use instrument air pneumatic control valves at the well heads. •
Chevron will implement a Leak Detection and Repair program (LDAR). • As Chevron is
committed to closed-loop drilling, there will be no emission-producing reserve pits. •
Chevron’s green completions practices includes transporting all flowback fluids via
buried pipelines to the CPF where they will be processed.`
10 Odor mitigation Chevron will utilize a freshwater mud system for surface hole.
• Chevron will use Group III drilling fluids for this location.
• Chevron will store oil-based drilling fluid not being used in the active mud system in
closed, upright tanks.
• To keep odor from oil base cuttings as low as possible, Chevron continuously hauls
cuttings to an approved disposal facility throughout the drilling process. Chevron will
not stockpile cuttings or store any large amount of cuttings on location. Trucks run
continuously during daylight hours to keep the volume of cuttings on location at a
minimum.
• Chevron will wipe the OD and ID of the drill pipe to remove any residual mud upon
tripping out of the hole.
• Chevron will utilize a catch can system mounted around the BOP to catch any mud
that falls through the rotary table, thereby preventing any spillage and reducing the
source of odor.
• Chevron will perform emission testing, as applicable, on natural gas-powered
engines to ensure emission control devices are operating properly. Additionally,
catalyst monitoring and maintenance activities recommended by the manufacturer or
mandated by state and federal regulations will be performed to ensure that control
devices are functioning as intended.`
11 Interim Reclamation •All segregated soil horizons removed from non-crop lands shall be replaced to their
original relative positions and contoured as near as practicable to achieve erosion
control and long-term stability.
•Soils shall be tilled adequately to establish a proper seedbed. The disturbed area will
be returned to rangeland in the first favorable season following rig demobilization.
Chevron will be responsible for backfilling, compacting backfill, reseeding, and re-
contouring the surface of any disturbed area. All disturbed areas will be returned to
preexisting conditions, as practicable.
• Compaction alleviation – compacted soils and areas of the location impacted by
construction will be ripped to a minimum depth of 18 inches prior to topsoil
replacement. Decompaction will be performed by a parabolic Ag style ripper capable of
fracturing the soil ensuring soil layers are not mixed. Any stockpiles used or disturbed
during interim reclamation activities will be restabilized with a combination of erosion
controls, including temporary seeding, hydro/straw mulch, and/or surface roughening.
• Any topsoil disturbed during construction activities will be segregated, stored, and
stabilized with existing topsoil stockpiles for future reclamation. • Any stockpiles used
or disturbed during interim reclamation activities will be restabilized with a combination
of erosion controls, including temporary seeding, hydro/straw mulch, and/or surface
roughening. • Heavy equipment tracking over soil stockpiles will be minimized to
avoid soil compaction.
• The construction layout for the location has been designed in a way that a potential
spill on location would drain towards the infiltration pond and avoid impacting topsoil
stockpiles.
• Chevron will monitor the site for the presence of noxious weeds. If encountered,
Chevron will employ a third-party consultant knowledgeable in identifying such species
and implement weed control measures consistent and in compliance with the Colorado
Noxious Weed Act. Management will be performed by either mowing or spraying and
in some rare occasions, both methods may be necessary. • Erosion control –
seed/mulch application functions as erosion control during initial reclamation efforts
until adequate vegetation has been established on areas not returned to irrigated crop.
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Once sufficient vegetation has been confirmed, the reclamation will be deemed
complete is ECMC and CDPHE Final Stabilization criteria are met. Final Stabilization
criteria are discussed in more detail within Chevron’s Storm Water Management Plan
(SWMP). The interim working pad will be stabilized against potential erosion with
surface armoring.
• Fencing – Chevron may fence reclaimed areas until interim reclamation has been
achieved to ensure vegetation growth is not overgrazed. Fencing will be installed after
seed/mulch application.
• Grading – Grading involves reshaping the ground surface to design elevations.
Grading provides more suitable topography for well pads and pipelines and helps to
control runoff, soil erosion, and sediment during and after construction in these areas.
• Mulching – mulching is a temporary erosion control used to stabilize exposed soils
while waiting for vegetation establishment. Mulch protects soils from rain impacts and
wind erosion, increases infiltration, and helps regulate soil temperatures. Typically,
agricultural straw or hay is mechanically applied and crimped in or wood
splinters/fibers are surface applied by hand or machinery. Tackifiers may be sprayed
over the applied mulch to enhance stabilization.
• Placement of soil – any subsoil used during interim reclamation is applied first,
followed by topsoil, in order to ensure that topsoil is not contaminated or adulterated
and to ensure optimum germination efforts. • Packing of soil layers – if multiple soil
layers are applied during interim reclamation, each soil layer is packed separately and
sequentially.
• Recontouring – documenting the existing topography and natural drainages of the
site prior to disturbance and reestablishing the topography and contours on the
reclamation to pre- disturbance conditions.
• Routine inspections – Chevron, and/or third-party contractors, conduct routine and
regularly scheduled inspections during which the reclamation and general site
conditions are inspected and monitored.
• Seedbed preparation – after decompaction, recontouring, and topsoil application, the
top 3-4 inches of soil will be prepared for seed application using a high-speed disk
and/or a mulcher as needed. Seedbed will be void of earthen clods and firm enough to
keep seed from being applied too deeply. Soil samples will be collected and analyzed
prior to seed application to identify any required amendments. Compost and fertilizer
will be applied based on current site conditions and on an as needed basis.
• Seeding – to establish perennial vegetative cover following construction, is the best
long term stabilization control for areas not stabilized with other permanent controls
(pavement, concrete, road base, etc.). Establishing perennial vegetation stabilizes the
soil, reduces wind and water erosion, minimizes sheet flow, increases infiltration, and
reduces overall runoff volumes. Seeding can be used to establish temporary
stabilization when dirt moving activities have ceased and will not resume for an
extended period of time, or as a final stabilization technique as part of the reclamation
plan for a site.
• Seed mix – the seed mix for reclaimed areas that will not be returned to irrigated crop
operations will be selected in coordination with qualified Chevron personnel and/or the
NRCS.
• Stockpile management – stockpile management is the protection of stockpiled
erodible materials through structural and nonstructural practices. • Surface armor –
surface armor is a combination of various materials (e.g., clay, concrete, dirt, rock,
etc.) used to stabilize a surface on location where erosion could occur. The armor
reduces erosion caused by runoff and raindrop impact, and it provides a stable working
surface for various construction related activities. Surface armor is often utilized
throughout the life of a location and can be incorporated on access roads, tank battery
locations, and well head locations.
• Timing of reclamation – seeding of areas not returned to irrigated crop will occur
during interim reclamation, after compaction alleviation, topsoil application,
recontouring, and seedbed preparation, and will be conducted during a spring or fall
planting window to achieve maximum germination rates.
• Topsoil salvage – the salvage and proper handling of topsoil is one of the keys to
reclamation success. Existing topsoil stockpiles exist at the location and will be used
for revegetation of disturbed areas during interim reclamation. Topsoil will be managed
per the site-specific topsoil protection plan.
• Weed control – invasive plants will be managed by performing a site assessment
during the spring and upon completion of the first growing season after interim
reclamation. This assessment will identify and inventory any/all invasive plants on the
location. The assessment will include GPS coordinates and maps detailing the location
Page 20 of 23Date Run: 8/23/2024 Doc [#403606035]
of the invasive plants. Management will be performed by either mowing or spraying
and in some rare occasions both methods may be necessary. Routine inspections
throughout the life of the pad will also aid in identifying when weed mitigation is
needed.
`
Total: 11 comment(s)
User Group Comment Comment Date
OGLA OGDP ID 486609 and this Form are approved by Commission Order Number 510-77.08/22/2024
OGLA The Director has determined that the OGDP application that this Form is a component of
meets all requirements of Rule 306.a. The Director’s Recommendation has been attached
to the Form 2A.
07/20/2024
General Comments
ATTACHMENT LIST
Att Doc Num Name
21316840 CPW CONSULTATION
21316841 CPW CONSULTATION
21316842 DIRECTOR'S RECOMMENDATION
403606035 FORM 2A SUBMITTED
403617132 ACCESS ROAD MAP
403617141 ALA DATASHEET
403617147 CULTURAL FEATURES MAP
403617149 DISPROPORTIONATELY IMPACTED COMMUNITY MAP
403617155 GEOLOGIC HAZARD MAP
403617156 LOCATION AND WORKING PAD GIS SHP
403617157 HYDROLOGY MAP
403617219 LAYOUT DRAWING
403617231 LOCATION DRAWING
403617238 LOCATION PICTURES
403617243 NRCS MAP UNIT DESC
403617247 REFERENCE AREA MAP
403617251 RELATED LOCATION AND FLOWLINE MAP
403617255 CPW WAIVER
403617263 WILDLIFE HABITAT DRAWING
403617313 ALA NARRATIVE SUMMARY
403765053 REFERENCE AREA PICTURES
403765054 CPW CONSULTATION
403765055 CONSULTATION SUMMARY
403765057 LESSER IMPACT AREA EXEMPTION REQUEST
403765058 PRELIMINARY PROCESS FLOW DIAGRAMS
403765059 DIRECTIONAL WELL PLAT
403785029 CORRESPONDENCE
Total Attach: 27 Files
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CPW Summary: The purpose of this Wildlife Consultation Summary is to give ECMC
Commissioners, ECMC staff (for the wildlife portion of the Director's Recommendation
document), and interested stakeholders insight into how CPW made their conclusions for
this proposed oil and gas development plan and associated wildlife consultation process.
The proposed SKR 698-10-BV location is a FEE/FEE site that falls within the following
CPW-mapped high priority habitats (HPH): Elk Winter Concentration Area (Rule 1202.d.)
and Aquatic Sportfish Management Waters (Rule 1202.c.).
CPW is satisfied that wildlife impact avoidance, minimization, and compensatory
mitigation measures have been addressed pursuant to ECMC's 300 and 1200 Series
Regulations.
Consultation History: CPW has engaged in significant pre-application consultation
discussions with the operator to address alternative locations, best management
practices, necessary CPW waivers, and compensatory mitigation to offset unavoidable
adverse impacts from these proposed activities. CPW confirms that the details and dates
contained within the operator-submitted “CPW Consultation Summary” document are
accurate and align with CPW’s records of the pre-application process that occurred.
Alternative Location Analysis: Chevron evaluated seven potential drilling locations in
addition to the proposed location. CPW has reviewed these alternative locations and
discussed the pros and cons regarding wildlife impacts with Chevron. Due to the
proposed location’s existing disturbance footprint, ability to utilize existing infrastructure
(pipelines and access road), and the existing presence of oil and gas activities in this
immediate area, CPW did not express a preference for any of the alternatives over the
proposed location.
CPW Issued Waivers: Chevron has requested and received two CPW waivers for this
location. Both of these waivers are associated with the siting of the location within 500
feet of a CPW-mapped Sportfish Management Water HPH (Deer Park Gulch). CPW has
agreed to waive the no surface occupancy requirement (Rule 1202.c.) and the statewide
operating requirement for tanks and chemical storage equipment (Rule 1202.a.(3).).
Chevron hired a third party consultant (SWCA) to perform an aquatic habitat survey of
Deer Park Gulch. Results of this survey indicate that the waterway is extremely
intermittent in nature and does not possess characteristics necessary to support any
sportfish populations. Additionally, this drainage is not believed to be utilized seasonally
by native fish species present within the Colorado River. Based on these factors, CPW
has agreed to waive both of these requirements pursuant to the authorities granted to
CPW within the 300 Series Regulations. CPW-provided waivers have been submitted by
the operator with their OGDP application materials, and additional stormwater and
emergency spill response BMPs have been included within the WMP document (in
consultation with CPW staff).
06/28/2024
CPW Minimization Measures (Best Management Practices): CPW approves of the operator-
committed Best Management Practices within the submitted Wildlife Mitigation Plan
document and does not request any additional best management practices at this time.
CPW has submitted the most relevant best management practices from the WMP onto
the Form2A within the wildlife tab in WebForms as CPW-Proposed Wildlife BMPs. This
includes Chevron’s commitment to conduct all construction, drilling, and completions
activities outside the elk winter concentration area timing limitation (Dec. 1 to April 30).
Compensatory Mitigation: Expanding the existing equipment storage facility to
accommodate drilling and completions activities will result in greater than one acre of new
disturbance within Rule 1202.d. elk winter concentration area HPH. Therefore, the
operator has elected to utilize the flat fee mitigation from Table 1203-1 to satisfy their
direct impact compensatory mitigation. This results in a payment of $13,750 to CPW’s
SB-181 mitigation account, due at least 30 days prior to submission of their Form42
Construction Notification.
Given the amount of traffic and disturbance associated with the existing equipment
storage facility, it is not anticipated that the addition of oil and gas wells on this location
will result in significant additions to indirect impacts on surrounding habitats. Furthermore,
Chevron has committed to conducting all pre-production activities outside of the big game
winter range timing limitation. Due to these considerations, CPW is not recommending
any additional mitigation to address adverse indirect impacts. Therefore, the total
06/28/2024
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compensatory mitigation requirement for this OGDP is $13,750.
Conclusion: CPW concurs that the operator has effectively consulted with CPW to
implement the full mitigation hierarchy (avoid, minimize, and mitigate). CPW does not
have any unresolved issues or objections to this permit application and the materials
submitted by the operator.
Approved in ECMC’s WebForms System by: Taylor Elm on June 28, 2024
OGLA The Director has determined this OGDP application is complete.
Form pushed to IN PROCESS.
05/09/2024
OGLA The Conditions of Approval (COA) and Best Management Practices (BMPs) on the Form
2A and the Final Order are the final enforceable permit conditions for this Oil and Gas
Location. Any plan or attachment that contains information or language that is contrary to
or less protective than ECMC rules or the COAs and BMPs on the Form 2A or Final Order
does not relieve the operator from compliance with the applied COAs, BMPs or any
ECMC rules.
05/09/2024
OGLA Operator requested a Rule 304.d Lesser Impact Area exemption from the Rule 304.c.(3)
Light Mitigation Plan. The request is based on the potentially impacted resource not
present or the impacts to the resource will be so minimal as to cause no concern. The
operator requested CPW for input on the request due to the Oil and Gas Location being
elk winter concentration and severe winter range HPH. CPW responded it has no
concerns with the request. There are no RBUs within 2000 feet of the location. Request
granted by Director.
05/01/2024
OGLA Operator requested a Rule 304.d Lesser Impact Area exemption from the Rule 304.c.(2)
Noise Mitigation Plan. The request is based on the potentially impacted resource not
present or the impacts to the resource will be so minimal as to cause no concern. The
operator requested CPW for input on the request due to the Oil and Gas Location being
elk winter concentration and severe winter range HPH. CPW responded it has no
concerns with the request. There are no RBUs within 2000 feet of the location. Request
granted by Director.
05/01/2024
OGLA ECMC Completeness Review done. Send Form 2A back to Draft for revisions to be made
to plans, attachments, and the Form.
04/09/2024
Total: 9 comment(s)
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APPENDIX G
CHEVRON -
PICEANCE BASIN
EMERGENCY
RESPONSE PLAN
Garfield County, Colorado
34
Status: Final Version: 006 Owner: Rockies Business
Unit i/42
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HSER Plan – Tier 4 RBU-PICE-EAP-PA-T4 006
Department
Document Type and Tier
Number
Version
Document Title:
Rockies Business Unit (RBU)
Piceance Basin
Emergency Action Plan (EAP)
Approval Date Signature
Emergency Management, RBU
Tim Mahaffey 5/24/22 Tim Mahaffey
Operations Superintendent, RBU
Andrew Olson 5/24/22 Andy Olson
Production Operations Manager, RBU
Marcus Parham 5/24/22 Marcus Parham
Office of Emergency Management
Piceance EAP
No. RBU-PICE-EAP-PA-T4
Status: Final Version: 006 Owner: Rockies Business
Unit ii/42
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DISTRIBUTION LIST
COPY NUMBER NAME TITLE LOCATION
1 Tim Mahaffey Emergency Management Master copy (Electronic)
Bentley
2 Marcus Parham Production Operations
Manager Greeley (Electronic)
3 Andrew Olson Operations Superintendent Piceance (Paper/Electronic)
4 IMT Incident Command Center Greeley (Electronic)
5 CMT Corporate Management Team Greeley (Electronic)
Piceance EAP
No. RBU-PICE-EAP-PA-T4
Status: Final Version: 006 Owner: Rockies Business
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8.1 Operator Name ...................................................................................................... 8
Plan Development ................................................................................................. 8
8.2.1 Document Owner .................................................................................................. 9
8.2.2 Document Approver .............................................................................................. 9
8.2.3 Distribution of Planning Documents .................................................................... 9
Planning Considerations ....................................................................................... 9
8.3.1 Situation ................................................................................................................ 9
8.3.2 Assumptions .......................................................................................................... 9
Roles and Responsibilities ................................................................................ 10
9.2.1 Emergency Manager .......................................................................................... 10
9.2.2 Emergency Coordinator ..................................................................................... 10
Emergency Contact Information ....................................................................... 11
Fire Prevention Plan ........................................................................................... 11
Response to Small Releases ............................................................................. 12
Emergency Shutdown Devices (ESD)................................................................ 12
Audible and Visual Notifications ....................................................................... 13
Safety Data Sheets ............................................................................................ 13
Protective Actions .............................................................................................. 14
10.6.1 Evacuation .......................................................................................................... 14
10.6.2 Shelter-in-Place .................................................................................................. 14
Muster Locations ............................................................................................... 14
Accountability ..................................................................................................... 14
All Clear (Return to Work) .................................................................................. 14
Offsite Notifications ........................................................................................... 15
IMT Organization Chart ...................................................................................... 15
16
Contingency Planning ........................................................................................ 16
Piceance EAP
No. RBU-PICE-EAP-PA-T4
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Fire and Explosions ............................................................................................ 17
11.1.1 Explosion Scenarios ........................................................................................... 18
Medical Emergencies ........................................................................................ 18
11.2.1 Advanced Medical Care ..................................................................................... 19
Environmental/Hazardous Materials (Release) Incidents .............................. 19
11.3.1 Toxic Gas ............................................................................................................ 19
Property/Security Events ................................................................................... 19
Severe Weather.................................................................................................. 21
Informing Personnel of Emergency ................................................................... 21
Agreements and Contracts ................................................................................ 22
12.1.1 Fire 22
12.1.2 MEDEVAC ............................................................................................................ 22
12.1.3 Environmental Release ..................................................................................... 22
12.1.4 High Voltage Event ............................................................................................. 23
Exercising the Plan ............................................................................................. 23
13.1.1 Fire/Evacuation Drills ........................................................................................ 23
13.1.2 Plan Review and Update ................................................................................... 23
Training Records ................................................................................................ 24
Attachment 1 – Ranch Map and Critical Information ................................................... 33
Attachment 2 – Piceance Emergency Management Team .......................................... 36
Attachment 3 – Spill Mitigation Dam Map .................................................................... 38
Attachment 4 – Initial Actions Flow Chart ..................................................................... 39
Attachment 5 – Piceance Well Locations Lat/Long ..................................................... 40
40
Attachment 6 – Piceance Location Name Lat/Long .................................................... 41
Attachment 7 – Spill Response Trailer Inventory.......................................................... 42
Piceance EAP
No. RBU-PICE-EAP-PA-T4
Status: Final Version: 006 Owner: Rockies Business
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ACRONYMS AND TERMS
ACRONYMS
AAR After Action Report
BBL Barrel
BU Business Unit
CA/IP Corrective Action/Improvement Plan
CO Carbon Monoxide
CO2 Carbon Dioxide
CGF Centralized Gathering Facility
CST Corporate Support Team
CVX Chevron
DOT Department of Transportation
EAP Emergency Action Plan
EHSR Environmental, Health, Safety, & Regulatory
EMS Emergency Medical Service
ESD Emergency Shutdown
EC Emergency Coordinator
EM Emergency Manager
H2S Hydrogen Sulfide
IC Incident Commander
IC/UC Incident Command/Unified Command
ICS Incident Command System
IMT Incident Management Team
IT Information Technology
LNG Liquefied Natural Gas
LZ Landing Zone
MOC Management of Change
NGL Natural Gas Liquids
O2 Oxygen
OA Operational Area
OSHA Occupational Safety and Health Administration
PPE Personal Protective Equipment
PREP Preparedness for Response Exercise Program
PSAP Public Safety Answering Point
SCADA Supervisory Control and Data Acquisition
SDS Safety Data Sheet
UC Unified Command
WGS World Geodetic System
Piceance EAP
No. RBU-PICE-EAP-PA-T4
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TERMS
Corporate Support
Team
A specialized group assembled from CVX personnel to provide support to
Incident Management Teams (IMT) in the event of an incident that has
grown in complexity beyond the capabilities of the IMT.
Facility Emergency
Coordinator
The on-site designated person responsible for providing oversight and
direction to field operations.
ICS 201, Incident
Briefing Sheet
Provides IC/UC and General Staffs with basic information regarding the
incident situation and the resources allocated to the incident. This form
also serves as a permanent record of the initial response to the incident.
Incident Command
System
A standardized on-scene emergency management concept specifically
designed to allow its user(s) to adopt an integrated, modular
organizational structure scalable to the complexity and demands of an
incident.
Incident Management
Team (IMT)
A team comprised of personnel from a respective OA organized into an
ICS structure in the event of an incident that has grown beyond the
capabilities of on-site personnel.
Incipient Stage Fire
A fire in its initial or beginning stage and can be controlled or extinguished
by a single portable extinguisher.
National Incident
Management System
(NIMS)
A comprehensive, nationwide, systematic approach to Incident
Management.
Operational Area
The area of responsibility identified for core business functions (e.g.,
Midstream).
Public Safety
Answering Point
A call center responsible for answering calls to an emergency telephone
number for police, firefighting, and ambulance services.
Stakeholder
External entities within the Operational Area that may be impacted by
incident operations.
Unified Command
The Unified Command organization consists of the IC’s from the various
jurisdictions or organizations operating together to form a single
command structure.
Piceance EAP
No. RBU-PICE-EAP-PA-T4
Status: Final Version: 006 Owner: Rockies Business
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PURPOSE
This Emergency Action Plan (EAP) was developed for Chevron Rockies Business Unit Piceance Basin
Operational Area (OA). It was developed specifically to address field/facility operations and is designed
to outline protection measures for personnel to ensure personnel know what their role is and where
they should muster during an emergency.
SCOPE
This Occupational Safety and Health Administration (OSHA) Emergency Action Plan (EAP) complies with
Standard 29 CFR 1910.119. It also serves as an extension of the Rockies Business Unit (RBU)
Emergency Response Plan (ERP) to assist operators engaged in operations during the initial stages of
emergency situations.
The ERP is organized per the standards prescribed within the National Incident Management System
(NIMS) and Incident Command System (ICS) guidelines. This organization allows the standardization
and flexibility necessary to effectively manage incidents regardless of size or complexity.
This EAP consists of systematic actions, activities, and supporting materials to proactively minimize
potential losses and promote safe actions in the event of unexpected incidents. Documentation and
testing the policies and procedures will assist in identifying the availability and allocation or resources
necessary to safeguard life, the environment and property. The scope of this EAP begins response as
soon as an incident occurs and continues until the transfer of command to the Incident Management
Team.
The primary objective of the EAP is to provide guidance to those personnel that (1), are assigned duties,
or (2) are present at a Facility during an incident. These objectives apply during all incidents, regardless
of the scenario at location. It is the intent that full cooperation exists with responding agencies during
the implementation and execution of this plan.
OPERATIONAL EXCELLENCE APPLICABILITY
The implementation of this EAP conforms to the following Operational Excellence (OE) elements:
• Workforce Safety
• Environment
• Emergency Management
Piceance EAP
No. RBU-PICE-EAP-PA-T4
Status: Final Version: 006 Owner: Rockies Business
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ADMINISTRATION
8.1 OPERATOR NAME
All Piceance Basin operations fall under the direction of:
Chevron, Rockies Business Unit
2115 117th Ave.
Greeley, CO 80634
Phone: (970) 304-5000
**Grand Junction Office**
760 Horizon Dr. #401
Grand Junction, CO
81506
**Hiner Gate Field Office**
4201 CR 211
De Beque, CO 81630
(Lat/Long) 39.54189, -108.32639
**Wilson Creek Field Office**
7265 Rio Blanco CR9
Meeker, CO 81641
**Piceance Ranch Office**
8311 CR 215
Parachute, CO 81635
(Lat/Long) 39.54097, -108.119138
The local representative for all Piceance-related matters is:
Andrew Olson
Operations Superintendent, RBU Piceance Basin
Mobile: 661-979-8847
• After hours call:
o 877-257-6007
o 970-304-5000 (Greeley IOC)
• GATE CODES:
o Skinner Ridge Field Gate Code: 1976
o Ranch Gate Code: 0726
PLAN DEVELOPMENT
The EAP is a document developed by HSER Emergency Management Coordinator with input
from corporate and the leadership of the OA.
Piceance EAP
No. RBU-PICE-EAP-PA-T4
Status: Final Version: 006 Owner: Rockies Business
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8.2.1 DOCUMENT OWNER
Production Operations Superintendent is assigned as the owner of this document. The
document owner is responsible for and has the authority to ensure all personnel are
appropriately trained to execute their assigned roles related to this plan.
8.2.2 DOCUMENT APPROVER
The Production Operations Superintendent is assigned as the local approver for this
EAP. The approver is responsible for ensuring the document owner has the resources
and authority to execute this plan in part or in whole, as required by the situation. To
ensure a consistent standard is maintained across RBU, the Emergency Management
Coordinator is also designated as an approver.
8.2.3 DISTRIBUTION OF PLANNING DOCUMENTS
The Production Operations Manager and Operations Superintendent shall determine
the distribution of the EAP. At a minimum, the plan shall be distributed to the Incident
Management Team (IMT), Production Operations Manager, and the Operations
Superintendent. A copy of this plan will be available in the Piceance office in addition
to being located as a controlled document in SharePoint. The Operations
Superintendent, or their designated representative, will give new personnel a briefing
of the EAP.
PLANNING CONSIDERATIONS
8.3.1 SITUATION
• Not all functions and operations are essential during an emergency or disaster.
• Collaboration and pre-planning with local first responders and key agencies will
allow for a better common operating picture working within a Unified
Command.
• A viable response capability must be ready for immediate activation and must
be capable of assisting to stabilize the scene until additional resources are
mobilized.
• Adequate planning for the most extreme incidents provides a range of
protection applicable to all incidents.
• Performance of an emergency function may depend on support from internal
and external stakeholders.
8.3.2 ASSUMPTIONS
• All personnel will be properly trained in their responsibilities regarding the
execution of this EAP.
• Unified Command (UC) will be implemented as local first responders arrive on
scene.
• A Transfer of Command from the initial Incident Commander (IC) to the IMT IC
will occur upon activation of the IMT and all personnel shall be notified by the
IMT IC.
• Key support personnel have been identified and trained in their emergency
response roles and will be available to activate the EAP.
• Qualified state and local personnel are available to perform emergency
response activities and are familiar with the procedures documented in this
EAP.
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No. RBU-PICE-EAP-PA-T4
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• Service agreements are maintained with cooperating and assisting agencies
to provide resources and support for emergency response activities.
All incidents share a general list of priorities for response actions. General emergency
management practices and the Incident Command System (ICS) establish a list that can be
harmonized with established corporate priorities. A comparison of those prioritizations is
shown in the table below:
PRIORITIES
Order Emergency Management Priorities Corporate Ideals
1 Life Safety Human Life
2 Incident Stabilization Environment
3 Environmental and Property Preservation Assets
4 Societal Restoration Reputation
All protective measures are first focused on the protection of persons. No consideration will
receive higher priority than the safety of persons, both internal and public.
ORGANIZATIONAL ROLES & RESPONSIBILITIES
In terms of incident command protocol, the following individuals/positions are charged with overall
safety, health, and welfare of all persons working at the Facility during an incident.
ROLES AND RESPONSIBILITIES
9.2.1 EMERGENCY MANAGER
The Emergency Manager (EM) shall manage this EAP on behalf of RBU. The EM shall
work with the Operations team to keep information updated within the plan.
The EM or their designee shall also coordinate with local public resources, such as fire
department and emergency medical personnel, to ensure that they are prepared to
respond as the incident dictates.
The EM(s) are identified below:
Name Position Primary Phone Secondary Phone
Tim Mahaffey
Lead Emergency
Management
Specialist
970-304-5000 970-539-1952
9.2.2 EMERGENCY COORDINATOR
The Emergency Coordinator (EC) is responsible for instituting the procedures in this
plan in the event of an emergency.
Note: Coordinators may also be given responsibility for accounting for
employees/visitors after an evacuation has occurred.
The EC is responsible for assisting employees or visitors who have disabilities.
The EC(s) are as follows:
Name Position Primary Phone
Andrew Olson Operations
Superintendent
661-979-8847
Alt. 970-257-6004
Piceance EAP
No. RBU-PICE-EAP-PA-T4
Status: Final Version: 006 Owner: Rockies Business
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EMERGENCY CONTACT INFORMATION
The EC shall maintain a list of all employees’ personal emergency contact information and
shall keep the list in a designated area for easy access in the event of an emergency.
CONCEPT OF OPERATIONS
The following are common initial elements that should be employed for any/all incidents occurring at
any stage of operations in advance of arriving local first responders.
FIRE PREVENTION PLAN
The firefighting philosophy is to isolate the fuel source, extinguish incipient fires, and ultimately
control the fire. Virtually all fires are small at origin and could easily be extinguished provided
they are found quickly and the appropriate type and amount of extinguishing agent is available
and properly applied.
Fire protection at the Facility is divided into four (4) sections:
• Prevention
• Detection and Notification
• Incipient fire fighting
• Isolation and cooling
Prevention
Prevention is facilitated by good engineering practices during construction of equipment and
systems. Good housekeeping practices contribute to the prevention of fires. Proper job
planning and a strict Hot Work Permit policy help ensure that fires do not occur.
Detection and Notification
Tours of the facilities by personnel and installation of fire detection monitors in strategic
locations constitute the major detection systems.
Fires or other emergency situations should be verbally reported to the Chevron person in
charge. Where appropriate, 9-911 should also be called to initiate public emergency response
resources. Remember to identify your location and phone number to allow Dispatch to properly
route your call to the appropriate agency.
Incipient Fire Fighting
Portable fire extinguishers have been placed in an appropriate location. Employees receive
regular training on the use of portable fire extinguishers for incipient firefighting. This training
includes instructions on when to use an extinguisher, when to refrain from fighting a fire and
how to evacuate, when necessary.
Currently the Piceance locations have three (3) different types of extinguishers to handle
specific incipient stage fires:
• Stored Pressure ABC Dry Chemical extinguishers
Piceance EAP
No. RBU-PICE-EAP-PA-T4
Status: Final Version: 006 Owner: Rockies Business
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• Cartridge Fired ABC Dry Chemical extinguishers.
• CO2 ABC extinguishers – general indoor use
• CO2 Fire Suppression System – Solar Turbine
If the fire grows past the incipient stage, all personnel will retreat to the Muster area to ensure
their own safety and wait for the Emergency Fire Department responders to arrive on scene.
If directed, personnel may assist responders in tasks that do not jeopardize their or someone
else’s safety and health.
Isolation and Cooling
Some field stations are equipped with an ESD system, with shutdown devices at strategic
locations. The system is designed to isolate major sources of flammable liquids or gases to
minimize the amount of fuel available.
Cooling of equipment will be performed by the local fire department.
RESPONSE TO SMALL RELEASES
A small release can quickly evolve into a major incident if it if not stopped promptly. If a small
release is witnessed, report the release to the operator on duty and request assistance. Isolate
the source if it is safe to do so. If the release cannot be easily stopped, an ESD and/or
evacuation may have to be initiated. Operations will follow their internal incident reporting
procedures to notify RBU Leadership and obtain Emergency Management assistance, if
necessary.
Operations personnel will only respond to releases if they are trained to do so and will not
jeopardize their health and safety in the process. Response actions can include securing
valves, either on-site or remotely, for isolation, allowing the gas to safely vent to the
atmosphere, and/or evacuating the site and surrounding area.
There is minimal spill response equipment on location. RBU has contract OSRO resources
available that will be leveraged as needed. Inventory includes, but is not limited to:
• Absorbent materials (e.g. quick dry, pads);
• Miscellaneous equipment (e.g. rakes, shovels, squeegees).
• Personal Protective Equipment (e.g. coveralls, chemical gloves).
• Open water booming equipment.
There are 9 spill prevention sites, each site has a minimum of 2 barrels that each contain.
1-20ft. boom, absorbent pads, rubber gloves, and rope for boom deployment.
Spill Response Trailer Inventory can be found in Attachment 7
EMERGENCY SHUTDOWN DEVICES (ESD)
The first responsibility of all employees is personal safety, followed by the safety of others. The
risk of personal injury is the most important consideration in any situation. Activation of site
Emergency Shutdown Devices is an acceptable response, and many times the only appropriate
response to some incidents.
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The following are utilities and/or shutdown procedures for equipment and machinery at
Piceance sites and locations. Personnel present on location are noted by crew leaders and
supervisors. Emergency muster points are established during Pre-Job meetings and noted in
the Job Safety Analysis (JSA). In the event of an emergency, personnel will evacuate to the
designated muster point where a headcount will be conducted. There are no critical operations
at the Grand Junction Office or Field Offices that would require personnel to remain behind
and operate. However, to minimize the dangers associated with an emergency, any trained
employee may shut off the following energy sources after evacuating:
Building Energy Type Utility Shut-off Location
Well Pads Electricity
Fuel Gas
• Abandon Buttons at CPF or from Control
Rooms
• Delineation Wells – Line off Pack
Separator
• Multi Well Pads – Line off Header
Central Processing Facility
(CPF)
Electricity
Fuel Gas
• Abondon Buttons throughout CPF or from
Control Board
• Fuel Gas Building
Office Trailer Electricity
Propane
• Transformer box between Trailer 4 & 6
• Propane Tank
AUDIBLE AND VISUAL NOTIFICATIONS
Notification of an emergency situation may be given at the Skinner Ridge field and facilities by
the following means:
• Verbally
• Two-way Radio
• Phone Loudspeaker (Central Processing Facility)
• Emergency/Evaluation Horn (Central Processing Facility)
• Alarms from monitoring equipment in plant and field (Gas, Fire)
• Operations Alarms (Process Problems)
If the alarm system sounds, personnel on location shall:
• Immediately stop all work;
• Determine wind direction, walk crosswind, then upwind to the nearest appropriate
muster area.
• All non-essential personnel are required to leave the location (well pads or CPF) to the
designated site staging location. Operations will assign someone in the planning
process (JSA) to do a head count of personnel to determine that everyone is accounted
for.
SAFETY DATA SHEETS
Safety Data Sheets (SDS) for all materials and chemicals are readily available and maintained
in the field office, trailer 6, and online via internet.
Link: https://msds-online.chevron.com/PSOnline/Home/Index
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PROTECTIVE ACTIONS
There are two (2) types of Protective Actions that may be employed when needed.
10.6.1 EVACUATION
In the event that a fire/emergency alarm is sounded and/or instructions for evacuation
are given by the EC, all persons shall immediately exit the Facility at the nearest point
and move crosswind then upwind, observing the wind direction from the nearest wind
sock.
10.6.2 SHELTER-IN-PLACE
If conditions (i.e. weather events) arise that require personnel to shelter- in-place the
EC shall announce “Shelter-in-Place” status by immediate voice notification via person-
to-person, radio, intercom, or mobile phone(s).
• If there are contractors, vendors, or visitors in the building, they shall be
advised to stay in the building for their safety.
• Unless there is an imminent threat, employees, vendors, contractors, and
visitors shall notify their emergency contacts to let them know where they are
and that they are safe.
• The EC, or their designee, shall quickly lock exterior doors and close windows.
• The EC shall monitor telephone, radio, television, and internet reports for
further instructions from authorities to determine when it is safe to leave the
building.
MUSTER LOCATIONS
In the event that evacuation is required, all employees shall evacuate per posted instructions
(if applicable) and report to the following designated muster points.
Grand Junction Office Southeast corner of Office parking lot
Primary Field Muster Point Hiner Gate Parking Lot
Alternate Field Muster Point Cowboy Chapel Parking Lot
Field Rally Point Central Processing Facility – Fresh Water Pond
Well Sites - Determined on location by incident
commander with incident in mind.
Shelter in Place As Directed
Ranch Office Muster Point Ranch office parking lot
ACCOUNTABILITY
Following an incident, the EC will conduct an accountability of assigned personnel, contractors,
vendors, and visitors against the sign-in sheet to ensure a complete evacuation of the site.
ALL CLEAR (RETURN TO WORK)
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Once a location has been evacuated, no one shall re-enter for any reason, except for
designated and properly trained rescue personnel, such as fire department or emergency
medical professionals. Untrained individuals may endanger themselves and/or those they are
trying to rescue.
All personnel shall remain at the desigated muster locations until the fire department or other
emergency response agency notifies the EC or designee of the status of the location and the
following is confirmed:
• The emergency situation has been resolved.
• There are no residual hazards remaining from the incident;
• Atmosphere is confirmed safe for reentry by a trained inspector;
• Cause of the original emergency has been identified and
mitigation steps have been employed minimizing a
reoccurrence, to the extent possible;
• Equipment on location has been inspected, is free of
damage and is serviceable.
• Emergency first responders and/or equipment still on
location will not compromise safety or environmental
responsibility if operations are restarted; and
• On-site safety systems are returned to original condition
and available for use should another emergency situation
occur.
OFFSITE NOTIFICATIONS
Offsite notifications for emergency services, contractors, governmental agencies, or RBU
employees (corporate or field) will occur as required/necessary. If the incident is of a chemical
release nature (spill or air), the IC will make any requests for spill response specialists, as
needed. Initial ICs should ensure they are prepared to describe the nature and extent of the
incident and/or injury, so the appropriate level of response can be taken.
In the event an incident has the potential to impact offsite locations, the IC will designate an
IMT member to communicate with the site location/local first responders. The designee will
provide information about the current situation and recommended actions. The designee
should maintain open lines of communications from the affected area(s) as the incident
progresses and provide information and updates to the IC/UC and first responders until
replaced or demobilization has occurred.
Refer to the ERP for more information regarding the activation and composition of the IMT.
IMT ORGANIZATION CHART
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The following locations have been designated by the Piceance Management Team:
• Primary ICC – Hiner Gate Trailer 6 Conference Room
• 1st Alternate ICC – DeBeque Community Center
• 2nd Alternate ICC – Grand Junction Office Suite 401
CONTINGENCY PLANNING
In the event an incident affecting the operational site extends beyond the perimeter of the
Facility, contingency operations will be implemented as appropriate to ensure the protection
of human health, safety, and the environment down and/or crosswind of the Facility.
Examples of hazards or risks that could potentially extend beyond the site boundary include,
but are not limited to, Hydrogen sulfide (H2S) releases, fires, and potential airborne breathing
hazards from smoke associated fires. RBU conducts planning sessions with local fire
responders to identify existing structures within ½ mile of existing or proposed oil and gas
locations consistent with the prescribed standards for evacuation in the Emergency Response
Guidebook (ERG) for large tanks involved in fires (Guide 128).
It is assumed that during an incident ample time exists to identify potential threats to residents
and/or businesses that may be impacted. Protective actions, such as sheltering-in-place or
evacuation, will be recommended to the IC/UC or county emergency management for
transmission to persons at those identified locations.
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INCIDENT REPORTING
It is the responsibility of all employees and/or contractors working on a Chevron location to
immediately report incidents, regardless of the nature. When an employee observes an
incident or condition which requires immediate attention, they should follow the procedures
below. See Appendix D, Attachment 4, for the quick response process flow chart.
All emergency situations will be reported as soon as possible to the EC by one of the following
means:
• In person as soon as possible during normal work hours; or
• By telephone if after normal work hours or on weekends.
The EC shall follow district-specific Incident Reporting Procedures. All incidents involving
personnel and/or contractor injuries/illness, equipment damage, vehicle damages, fire,
security, or unintentional discharges are to be reported, as soon as practical, to the
HSER/Security Department.
Incident Reporting
24-Hour Incident Reporting RBU First Report (Power Apps)
FIRE AND EXPLOSIONS
The primary method of notification during a fire emergency is the activation of emergency
resources by use of the Public Safety Answering Point (PSAP), otherwise known as 911. Other
methods of internal notice include radio or telephone transmission and/or person-to-person
notification.
If the following is reported to you, or if you see smoke, flames, or smell something burning, or
hear a fire alarm, IMMEDIATELY:
• Conduct an initial scene size-up. Determine if ESD activation and/or evacuation is
needed.
• If safe to do so, address life safety issues.
• Notification to the Fire Department should be through the local Public Safety Answering
Point (PSAP) using 911.
Information to be given to the PSAP:
State the emergency condition (e.g. alarm, smoke, flames, etc.)
Address: ____________________
Type of Occupancy: Oil & Gas operations
Telephone # calling from _______________
Let the PSAP Operator Hang Up First!
• Immediately report the incident to the supervisor.
• Document summary of actions using ICS 201 (Appendix C).
• Brief arriving local first responders.
• Implement plan as directed by IC.
If you think you smell a peculiar or unfamiliar odor, IMMEDIATELY:
• Inform others working in the area.
• Remove yourself and other away from the affected area
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• Notify the Facility/Production Foreman.
11.1.1 EXPLOSION SCENARIOS
The ESD should be activated in a situation which could result in an explosion (i.e. vapor
cloud, relief valve activation due to fire on a liquid containing pressure vessel).
Vapor Cloud Explosion (VCE): A VCE may occur is a refrigerated liquid, such as NGL or
LNG, is relieved at a high volume, such as in the case of an equipment failure or during
a process upset such as the activation of a relief valve venting to atmosphere on the
NGL tanks. The release will allow the liquid to vaporize rapidly to air, expand, and
create an easily ignitable flammable mixture. If an ignition source occurs or is present
in the flammable zone, an explosion will occur and create a wave of pressure and
flame.
Boiling Liquid Expanding Vapor Explosion (BLEVE): A BLEVE may occur if a sustained
fire impinges on a pressurized storage tank or other pressure vessel containing liquid
within the Facility. The NGL storage vessels, LNG storage vessels, and various
scrubbers and knockouts have the potential to BLEVE under these conditions. Each of
these vessels have been evaluated for the potential that a fire to occur, such that this
case has been considered in the sizing of each associated relief valve. An early sign of
a potential BLEVE is a relief valve activating on a liquid-containing pressure vessel in
response to a fire occurring under or very near it. The liquid in the vessel functions to
disperse heat to prevent failure. Over time, as the liquid boil vaporizes in the vessel, it
may no longer have the benefit of this protection. The result is a metal failure due to
temperature and catastrophic event.
MEDICAL EMERGENCIES
Employees and contractors should exercise extreme caution when medical emergencies are
presented. To ensure they do not expose themselves to H2S or other dangerous environments
(i.e. oxygen-deficient environments, LELs, etc.) personnel performing duties inside the area will
have personnel gas monitors on their person.
If a medical emergency occurs or it is reported to you, IMMEDIATELY:
• Conduct an initial scene size-up. Determine if ESD activation and/or evacuation is
needed.
• If safe to do so, address life safety issues.
• Notification for EMS personnel will be through the local PSAP using 911 or the number
listed in the Contact List in Appendix A.
Information to be given to the PSAP:
State the emergency condition (e.g. illness, injury, etc.)
Address: _____________________
Type of Occupancy: Oil & Gas operations
Telephone # calling from _______________
Note: If the injury occurred as a result of a snake bite, inform the MEDEVAC operator
when making the call (Advise MEDEVAC to position anti-venom on aircraft).
Let the PSAP Operator Hang Up First!
• Immediately report the incident to the supervisor.
• Document summary of actions using ICS 201 (Appendix C).
• Brief arriving local first responders.
• Implement plan as directed by IC.
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• A helicopter landing zone (LZ) will be determined by the Fire Chief.
11.2.1 ADVANCED MEDICAL CARE
Medical care should only be administered to the level of training of the care provider.
ENVIRONMENTAL/HAZARDOUS MATERIALS (RELEASE)
INCIDENTS
If you see a release or it is reported to you, IMMEDIATELY:
• Conduct an initial scene size-up. Determine if ESD activation and/or evacuation is
needed.
• If safe to do so, address life safety issues.
Note: Employees and contractors should exercise extreme caution when
environmental/hazardous materials releases are present. To ensure they do not
expose themselves to H2S or other dangerous environments (i.e. oxygen-deficient
environments, LELs, etc.) personnel performing duties inside the area will have
personal gas monitors on their person.
• Immediately report the incident to the supervisor.
• Determine if any personnel need to be decontaminated
• For any situations requiring a response from first responders, notification will be
through the local PSAP at 911 or the number listed in the Contact List in Appendix A.
Information to be given to the PSAP:
State the emergency condition (e.g. material released, etc.)
Address: ______________
Type of Occupancy: Oil & Gas operations
Telephone # calling from _______________
Let the PSAP Operator Hang Up First!
• Document summary of actions using ICS 201 (Appendix C).
• Brief arriving local first responders.
• Implement plan as directed by IC.
11.3.1 TOXIC GAS
Personnel may encounter a gas stream consisting of hydrocarbons, H2S, and Carbon
Dioxide (CO2). Combustible gas LEL detectors and gas detectors for H2S are installed
in each process building. Additionally, CO2 detectors are installed within the Amine
building. As such, all personnel are required to wear personal gas monitors (CO, LEL,
H2S, and O2).
Emergency conditions may exist when the personal gas monitor alarms.
• If outside a building, immediately progress upwind & crosswind to the primary
assembly point.
If the building/location gas detector alarms:
• Immediately locate and don the escape pack and exit the structure.
• Actuate the ESD.
• Notify the EC.
PROPERTY/SECURITY EVENTS
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If you receive a verbal, telephonic, or are presented with an immediate threat; are presented
with unauthorized persons; or locate a suspicious package/backpack, IMMEDIATELY:
• Conduct an initial scene size-up. Determine if ESD activation and/or evacuation is
needed.
• If safe to do so, address life safety issues.
• Notification to law enforcement will be through the local PSAP at 911 or the
appropriate number listed in the Contact List in Appendix A.
Information to be given to the PSAP:
State the emergency condition (e.g. threat, suspicious package, etc.)
Address: _______________
Type of Occupancy: Oil and Gas operations
Telephone # calling from _______________
Let the PSAP Operator Hang Up First!
• Immediately report the incident to the supervisor.
• Document summary of actions using ICS 201 (Appendix C).
• Brief arriving local first responders.
• Implement plan as directed by IC.
Security Alert Level Advisory System (SALAS)
The Security Alert Level Advisory System is the corporate Security of Personnel and
Assets Process-endorsed system for Business Units and facilities designed to guide the tiered
escalation (or de-escalation) of security safeguards. This system will help prevent or mitigate
security incidents and ensure that Bus and Facilities, in coordination with Global Security (GS,
adapt the correct security alert level at each location and adjust as appropriate,
commensurate with the threat. This system is liked to the Business Unit Emergency
Management (EM) process.
The higher the security alert level, the greater the threat from a potential event and the greater
the risk to the BU’s personnel and assets. The risk is based on the probability / likelihood of
an event occurring and this event consequence of the act if it were to occur. As the risk level
increases, tiered preventative and mitigative safeguards need to be put in place to counter
them.
Low alert: GREEN
Security Alert Level description or indicator: applies when there is a general, nonspecific threat
of a security-related incident occurring in a BU / facility’s operational area. This is the Normal
Operating condition for the BU/Facility.
Low alert: BLUE
Security Alert Level description or indicator: applies when intelligence indicates a potential
threat of a security-related incident occurring in a BU operational area that may endanger
personnel and/or assets but does not justify restricting business operations.
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Low alert: ORANGE
Security Alert Level description or indicator: applies when intelligence indicates at threat of a
security-related incident occurring in a BU operational area that may endanger personnel
and/or assets and that justifies restricting business operations.
Action: Follow established evacuation procedures for location and advise Supervisor.
Low alert: RED
Security Alert Level description or indicator: applies when intelligence indicates that a major
security-related incident is expected to occur at any time, or when an actual incident occurs
unexpectedly at a particular site or across several sites in a BU.
Action: Follow established evacuation procedures for location and advise Supervisor.
SEVERE WEATHER
The EC shall announce immediate notification of severe weather alerts, such as severe
snowstorms, by voice communications or other means of immediate notification available. If
safe to do so, personnel shall immediately leave the location via their vehicle if safe and head
away from the weather.
• Conduct an initial scene size-up. Determine if ESD activation/evacuation is needed.
• Immediately report the incident to the supervisor or EC.
• If not accomplished, notification to emergency personnel will be through the local PSAP
using 911 or the number listed in Appendix A.
If relocating to a hardened structure, employees, contractors, and/or visitors should avoid
areas near windows and seek shelter under desks, tables, or other structures in the centralized
part of the structure, placing as many barriers (i.e. walls, doors) between themselves and the
exterior of the building as possible.
If the Severe Weather event has caused significant damage or has caused injury to personnel,
the EC will initiate response procedures to be followed.
INFORMING PERSONNEL OF EMERGENCY
In the event of an emergency, the EC shall ensure that all personnel on site are notified as
soon as possible via vocal communications, radio, or cell phone (where appropriate).
The EC shall be responsible for ensuring notification, accountability, and formal
communication flow of information to all on-site personnel.
If a fire or emergency occurs after normal business hours, the EC shall contact all employees
and contractors of future work status, depending on the nature of the situation.
Given the extreme terrain and geography associated with Chevron assets on the Western
Slope, communications can be challenging. To address this issue a satellite-based internet
service solution, Starlink, is available for use. This portable solution is kept and maintained
on a regular basis by Piceance Ranch personnel to ensure updates are in place and system
functionality maintained. Priority use of this solution is always given to the incident
management team. Piceance Ranch personnel will coordinate with the Incident Commander
on the delivery and set up of the Starlink solution during an incident.
Note: Duties and responsibilities for the IMT are addressed in the RBU ERP.
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SERVICE AND SUPPORT ACTIVITIES
AGREEMENTS AND CONTRACTS
There are specific agreements or Master Service Contracts which can be leveraged to support
emergency response actions.
12.1.1 FIRE
A Master Service Contract (MSC) is in effect for:
Wild Well Control
2419 1st Ave
Greeley, CO 80631
12.1.2 MEDEVAC
The preferred vender is:
North Colorado Med Evac (North Colorado Medical Center)
1801 16th Street
Greeley, CO 80631
Dispatch Center/Aircraft Request: (800) 247-4357 or (800) Air help
-OR-
St. Mary’s CareFLIGHT
2849 Aviators Way
Grand Junction, CO 81506
Dispatch Center/Aircraft Request: (970) 298-2149
*Note: In the event St. Mary’s CareFLIGHT is needed, the De Beque Fire
Department must also be notified as a backup.
12.1.3 ENVIRONMENTAL RELEASE
A Master Service Contract is in effect for:
Enviro Care Inc.
505 N. Main St.
North Salt Lake, UT 84054
(801) 299-1900
Custom Environmental Services, Inc.
8041 N I-70 Frontage Road, Unit #11
Arvada, CO 80002
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12.1.4 HIGH VOLTAGE EVENT
A Master Service Contract is in effect for:
N Line Electric, LLC
14293 Longs Peak Court
Longmont, CO 80504
Denver: (303) 702-1147
Fort Collins: (970) 535-6253
Ducey’s Electric
221 E. Main St.
Rangely, CO 81648
(970) 675-8368
PLAN MAINTENANCE
EXERCISING THE PLAN
13.1.1 FIRE/EVACUATION DRILLS
Fire/evacuation drills are performed periodically by personnel. Local first responders
may be notified of the drills as a means of verifying communication with the emergency
officials.
Monthly inspections of each fire extinguisher will be handled by the Operations team
or a qualified alternate. Annual inspections of fire extinguishers will be conducted by a
third-party vendor.
13.1.2 PLAN REVIEW AND UPDATE
All employees shall receive instruction on this EAP as part of the New Employee
Orientation upon hire. Additional training will be provided:
• Annually as a refresher.
• When there are any changes to the EAP; and
• When an employee’s responsibilities change.
Additionally, to ensure consistency and proficiency exists between the company and
local first responder agencies, RBU has conducted the prescribed levels of Incident
Command training in preparation for response to incidents.
The EC, and their designees involved in response to field incidents have completed all
requirements for:
• ICS 100, Introduction to the Incident Command System; and
• ICS 200, ICS for Single Resources, and Initial Action Incidents.
This EAP will be updated based on lessons learned during exercises and reflected in
the CA/IP.
Changes and updates will be documented and added within Appendix B of this EAP
and distributed to the agencies identified within the Distribution List.
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TRAINING RECORDS
All training documentation pertaining to the EAP will be maintained by the FEM.
APPENDICES
APPENDIX OA ACTIVITY
A Contact List
B Record of Change
C ICS 201
D Attachments
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APPENDIX A – CONTACT LIST
Emergency Notification – CALL 911
LOCAL EMERGENCY RESPONSE ASSISTANCE
Organization Phone Number
Public Service Company of Colorado 800-772-7858
Garfield County Sheriff’s Office (GCSO) 970-945-0453
Mesa County Sheriff’s Office (MCSO) 970-224-3500
Mesa County Dispatch 970241-6704
Garfield County Office of Emergency Management (OEM) 970-945-0453 Non-Emergency
Mesa County Office of Emergency Management (OEM)
970-244-3500
970-242-6707 Non-Emergency
Rio Blanco Office of Emergency Management (OEM) 970-878-9623 Non-Emergency
De Beque Fire Department
970-822-5566 Non-Emergency
970-201-4088 Fire Chief
Grand Valley Fire Protection District (Parachute)
970-285-9119 Non-Emergency
970-307-4803 Division Chief
970-250-9851 Fire Chief
Rifle Fire Department 970-625-1220 Non-Emergency
Town of De Beque
970-823-5531
970-283-5146 – Town Marshall
Colorado State Patrol (CSP) 303-239-4501 – Dispatch
Grand Junction Hospital 970-244-2273
St. Mary’s CareFLIGHT
• In the event St. Mary’s Careflight is needed, the De Beque
Fire Department must also be notified as a backup. 800-332-4923
Rifle Hospital 970-625-1510
U.S. Forest Service 970-242-8211
Bureau of Land Management (BLM) 970-244-3000
OSHA 303-844-1600
ECMC – Rifle Office 970-625-1213
Federal Bureau of Investigation (FBI) 970-242-8360
Weather Services 970-243-7007
Colorado Travel Conditions 303-639-1111
Emergency Response Personnel
CVX/RBU Organization Dept. Phone Number
IOC (Integrated Operations Center) Greeley 970-304-5000
Production Operations Manager – Marcus Parham 432-254-2215
Operations Superintendent – Andrew Olson 661-979-8847
Emergency Satellite Phone #3 8881632647122 (Hiner Gate field office, Trailer 6
Control Room)
Emergency Management – Tim Mahaffey 970-539-1952
Other Municipalities
Organization Phone Number
Town of Parachute 970-285-7630
Town of Rifle 970-625-2121
Rifle Fire Department Non-Emergency 970-625-1220
Glenwood Springs Hospital 970-945-6535
Rifle Hospital 970-625-1510
Utility Providers
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Organization Phone Number
Electric – Xcel Energy 800-895-4999
Gas – Xcel Energy 800-895-4999
Telephone – CenturyLink 800-201-4099
Grand Valley Power 970-242-0040
Service Providers
Organization Phone Number
Custom Environmental Services (OSRO) –
Denver, CO 800-310-7445
Clean Harbors (OSRO) – Denver, CO 800-645-8265
Enviro Care Inc.(OSRO) – Salt Lake City, UT 801-299-1900
Enterprise 713-803-2407
ECOS Hazmat 970-618-7355
Shallenberger Construction Inc. (SCI) 970-560-5998
UAries 970-675-5766
Rocky Mountain Electric 970-824-6757
Big D’s 970-675-8610
APPENDIX B – RECORD OF CHANGE
RECORD OF REVIEWS & REVISIONS
Date Action Text Author
3/10/2022 Draft Document Draft MGZW
11/15/22 Update Attachment #2 Update personnel (Admin) MGZW
1/18/22 Update Appendix A Add Satellite phone MGZW
1/18/22 Update Attachment #2 Update personnel (Admin) MGZW
5/16/23 Update 8.1 Updated field offices MGZW
5/16/23 Update 9.1.2 Secondary phone added MGZW
5/16/23 Update 10.5 SDS locations MGZW
5/16/23 Update 12.1.4 New vendor MGZW
5/16/23 Appendix A Contacts updated MGZW
5/16/23 Attachment 2 Updated IMT MGZW
5/16/23 Updated Rev 003 MGZW
8/16/23 Update 11.6 Added language around StarLink system MGZW
8/16/23 Attachment 6 Added 36-BV location MGZW
8/16/23 Updated Rev 004 MGZW
4/26/24 Update A Contacts updated MGZW
Piceance EAP
No. RBU-PICE-EAP-PA-T4
Status: Final Version: 006 Owner: Rockies Business
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4/26/24 Update Attachment 2 Contact update MGZW
4/26/24 Update Section 11.4 Added SALAS information MGZW
4/26/24 Update Rev 005 MGZW
8/6/2024 Updated Appendix D Added Laydown yard information MGZW
8/6/2024 Update Rev 006 MGZW
Piceance EAP
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APPENDIX C – ICS 201
1. Incident Name:
2. Incident Number:
3. Date/Time Initiated:
Date: Time:
4. Map/Sketch (include sketch, showing the total area of operations, the incident site/area, impacted and threatened
areas, overflight results, trajectories, impacted shorelines, or other graphics depicting situational status and resource
assignment):
5. Situation Summary and Health and Safety Briefing (for briefings or transfer of command): Recognize potential
incident Health and Safety Hazards and develop necessary measures (remove hazard, provide personal protective
equipment, warn people of the hazard) to protect responders from those hazards.
6. Prepared by: Name: Position/Title: Signature:
ICS 201, Page 1 Date/Time:
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1. Incident Name:
2. Incident Number:
3. Date/Time Initiated:
Date: Time:
7. Current and Planned Objectives:
8. Current and Planned Actions, Strategies, and Tactics:
Time: Actions:
6. Prepared by: Name: Position/Title: Signature:
ICS 201, Page 2 Date/Time:
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1. Incident Name:
2. Incident Number:
3. Date/Time Initiated:
Date: Time:
9. Current Organization (fill in additional organization as appropriate):
6. Prepared by: Name: Position/Title: Signature:
ICS 201, Page 3 Date/Time:
Incident Commander(s)
Operations Section Chief Planning Section Chief Logistics Section Chief Finance/Administration
Section Chief
Security Officer
Human Resources Officer
Safety Officer
Liaison Officer
Legal Officer
Public Information Officer
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1. Incident Name:
2. Incident Number:
3. Date/Time Initiated:
Date: Time:
10. Resource Summary:
Resource
Resource
Identifier
Date/Time
Ordered ETA
Ar
r
i
v
e
d
Notes (location/assignment/status)
6. Prepared by: Name: Position/Title: Signature:
ICS 201, Page 4 Date/Time:
Piceance EAP
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APPENDIX D – ATTACHMENTS
ATTACHMENTS ACTIVITY
1 PICEANCE RANCH MAP AND CRITICAL
INFORMATION
2 PICEANCE EMERGENCY MANAGEMENT TEAM
3 PICEANCE SPILL MITIGATION DAM MAP
4 INITIAL ACTIONS FLOWCHART
5 PICEANCE WELL LOCATIONS LAT/LONG
6 PICEANCE LOCATION NAME LAT/LONG
7 SPILL RESPONSE TRAILER INVENTORY
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ATTACHMENT 1 – RANCH MAP AND CRITICAL INFORMATION
Piceance Ranch Key Locations
• Ranch House:
39.539372278316186,
-108.12144554386066
• Hinder Gate:
39.541331424289716,
-108.32524427646534
Piceance EAP
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RANCH INFORMATION
Facility Name Ranch House and Office
Type of Facility Base for Ranch Operations
Address (Ranch Office) 8311 County Road 215 Parachute, Colorado 81635
Latitude/ Longitude 39.54097; -108.119138
Elevation (feet above mean sea level) 5,715
Driving Directions From I-70 and CR215; Go North on CR215 for 8.2 miles; Turn West
then South-West .2 mile into location.
FACILITY EMERGENCY RESPONSE CONTACT
Piceance Ranch Manager – Rick Cross 281-620-8564 (Mobile)
Operations Superintendent – Andrew Olson 661-979-8847 (Mobile)
Emergency Satellite Phone #3 8881632647122 (Hiner Gate field office, Trailer 6 Control Room)
SKR LAYDOWN YARD INFORMATION
Facility Name SKR Laydown Yard
Type of Facility Laydown yard for new/used equipment
Latitude/ Longitude 39.57108, -108.34680
Elevation (feet above mean sea level) 6,000
Driving Directions From CR204 and CR211(Clear Creek Rd), North 6.7miles, West
Into location. (Across from CPF)
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LOCAL EMERGENCY RESPONSE ASSISTANCE
Organization Phone Number
Colorado State Patrol 303-239-4501 – Dispatch
Grand Junction Hospital 970-244-2273 St. Mary’s CareFLIGHT
In the event St. Mary’s Careflight is needed, the De Beque Fire Department must also be notified as
a backup. 800-332-4923
Rifle Hospital 970-625-1510
U.S. Forest Service 970-242-8211
Garfield County Administration 970-945-5004
Garfield County OEM 970-945-0453 ext. 1012
Bureau of Land Management (BLM) 970-244-3000
COGCC – Rifle Office 970-625-1213
Federal Bureau of Investigation (FBI) 970-242-8360
Weather Services 970-243-7007
Colorado Travel Conditions 303-639-1111
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ATTACHMENT 2 – PICEANCE EMERGENCY MANAGEMENT TEAM
Name IMT Position Cell Phone
Andy Olson
Chester O’Nan Incident Commander (IC) 661-979-8847
505-947-1000
Rick Cross Liaison/Land
281-620-8564 (Mobile)
Mike Sanford Safety Officer (SO) 970-333-6127
Chester O’Nan
David Sinclair
Michael Herrera
Operations Section Chief (OSC)
505-947-1000
970-309-8269
970-812-2263
Dawn Bittner Logistics & Finance 713-201-8705
Cary Baird Public Information Officer 970-589-9386
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Key Field Operations Personnel/ Onsite Response Team (Operations Section Responders)
Ken Hampton EIS 970-683-5106 (Trailer 6) 970-589-5541 kjta@chevron.com
Scott Dudney EIS 970-683-5106 (Trailer 6) 505-609-1830 scott.dudney@chevron.com
Michael Herrera FS
970-683-5103 (Control
Room) 970-812-2263 mzxs@chevron.com
David Sinclair FS
970-683-5103 (Control
Room) 432-556-5605 ugca@chevron.com
Allison Shafer FS
970-683-5103 (Control
Room) 903-368-0143 fcuf@chevron.com
Fabian Achuleta FS
970-683-5103 (Control
Room) 970-986-7899 Fabian.achuleta@chevron.com
Nick Prinster FS / LDAR
970-683-5103 (Control
Room) 970-985-5118 tnprinster@chevron.com
Brian Trickel FS
970-683-5103 (Control
Room) 970-433-4668 Brian.trickel@chevron.com
Steve Wallace FS
970-683-5103 (Control
Room) 970-314-1409 Steve.wallace@chevron.com
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ATTACHMENT 3 – SPILL MITIGATION DAM MAP
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ATTACHMENT 4 – INITIAL ACTIONS FLOW CHART
Response Actions for EAPs
Fi
r
e
Me
d
i
c
a
l
Re
l
e
a
s
e
To
r
n
a
d
o
Initiate the ESD Evacuate from area via vehicle
Notify your Supervisor of:1) the emergency 2) your escape route3)support needed
Is the release outside of secondary containment?
Initiate shut down
Notify Roustabout crew for cleanup
Yes Is the product outside tertiary containment?Yes Initiate spill containment if safe to do so
Notify Supervisor of:1) estimated release quantity 2) actions already taken
No
Does the illness/injury require a MEDEVAC?
Notify Fire/EMS MEDEVAC*advise to load anti-venom if snake bite victim
Notify PSAP
Yes
No
Is the MEDEVAC available?Yes
No
Prepare the Helispot for MEDEVAC
Prepare to meet the EMS unit
Keep patient stable as best you can
Is there fire beyond incipient stage?
Initiate the ESD
Use available extinguisher to extinguish fire
Yes
No Is the fire extinguished?
Evacuate the location Notify PSAP (911)
No
Is the fire extinguished?
Brief Fire Department upon arrival
No
Make notification to Supervisor
No
Make notification to Supervisor
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ATTACHMENT 5 – PICEANCE WELL LOCATIONS LAT/LONG
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ATTACHMENT 6 – PICEANCE LOCATION NAME LAT/LONG
LOCATION By Local Common Name LATITUDE North LONGITUDE West Description of Location
25-AV 39.58958 108.34167 Multi-Pad Well Location
25-4 39.58909 108.33945 Single Well Location
25 BOOSTER 39.58843 108.33997 Compressor Station
25-BV 39.58603 108.34054 Multi-Pad Well Location
25-CV 39.57767 108.34125 Multi-Pad Well Location
36-AV 39.57273 108.33950 Multi-Pad Well Location
36-BV 39.566351 -108.346504 Multi-Well Location
26-AV 39.57869 108.35565 Multi-Pad Well Location
35-AV 39.57386 108.34774 Multi-Pad Well Location
35-BV 39.57189 108.34934 Water Storage and Treating
CPF 39.57165 108.34502 Processing Plant
F.W. POND 39.57206 108.34660 Fresh Water Pond
28-1 39.49921 108.33939 Single Well Location
28-2 39.49809 108.32935 Single Well Location
27-1 39.50140 108.32386 Single Well Location
22-1 39.52258 108.31859 Single Well Location
11-1 39.54239 108.29118 Single Well Location
12-1 39.54463 108.28424 Single Well Location
12-2 39.54786 108.28024 Single Well Location
12-3 39.54970 108.27638 Single Well Location
8-1 39.63278 108.42148 Water Injection Well
Field Origin Start Of 30 Inch Sale Line
Sales Facility End of 30 Inch Line to Sales
Hiner Gate 39.54155 108.32517 Office Facility
Oil Shale Pad 39.82221 108.30206 Test Pad
Mine Laydown 39.62168 108.41411 Empty Fenced Area
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ATTACHMENT 7 – SPILL RESPONSE TRAILER INVENTORY
Spill response trailer is maintained by the operations and reviewed annually for inventory changes.
• Trailer Location: Hinder Gate
• Lat/Long: 39.541331424289716, -108.32524427646534
1-fire extinguisher
1 square-point shovel
1-rake
1-roll of chicken wire
200-15”x18” heavy duty absorbent pads
400-16”x20” light duty absorbent pads
4-3”x20’ booms
4-5”x20’ booms
4-8”x20’ booms
5-pair safety glasses
5-pairs of goggles
1-box of hefty plastic bags
2-rolls of drum liners
1-large yellow hazardous material bag
1-small yellow hazardous material bag
1-post driver
10-t-posts
1-overpack barrel
200 ft of rope
10-paris of rubber gloves
2-boxes of nitrile disposable gloves.
APPENDIX H
PIPELINE REVIEW
CRITERIA
SKR 698-10-BV
Temporary Surface
Freshwater Layflat
Pipeline
Garfield County, Colorado
34
Rule Reference Applicant Response Comments
9-104.A The temporary freshwater layflat pipeline is placed on existing
Chevron‑owned surface and follows established access routes and
prior disturbance areas, avoiding agricultural production lands. The
placement creates no new disturbance because the line does not
involve excavation, grading, permanent structures, or any new
surface disturbance
9-104.B ECMC does not regulate freshwater surface-laid lines and
associated equipment and there are no RBUs within close
proximity. Noise associated with the temporary pipeline will be
minimal and involve primarily light‑truck traffic and muffled internal
comubsion engines to move the freshwater during the temporary
9-104.C Because the line is surface‑laid, low‑profile, and temporary, and lies
primarily along existing operational corridors on Chevron‑owned
surface, it results in minimal visual impact and no long‑term
alteration of the land surface.
9-104.D The project uses existing access and previously permitted culverts
and crossings, with no new points of entry onto public roads and no
changes to public road visibility, safety, or function.
9-104.E The layflat pipeline transports freshwater only and temporary
pumps associated with the action require no permitting needs.
9-104.F Because the line carries freshwater and involves no hazardous
materials, chemicals, or earthmoving, the project fully complies
with CDPHE Water Quality Control Standards and poses no risk of
water quality impact
9-104.G A reclamation plan is not applicable because the temporary line
generates no surface disturbance, vegetation removal, or soil
disruption, and is fully removed after use, leaving the surface
unchanged
Water Quality Control Standards. All operations shall comply with all applicable
CDPHE Water Quality Control Standards.
Reclamation Plan.
Article 9 - Pipelines Review Criteria
Located Along Perimeters. As a general guide, rights-of-way and any associated
facilities shall be located along the perimeters of surface property ownerships
and not within areas of agricultural crop production. Non perimeter locations
will be acceptable if the surface owner agrees and there is no adverse impact on
adjacent properties.
Noise Abatement. Any equipment used in construction or operation of a pipeline
must comply with either the ECMC Rules and Regulations in regards to noise
abatement or C.R.S. Article 12 of Title 25, as appropriate for the type of
pipeline. All power sources used in pipeline operations shall have electric motors
or muffled internal combustion engines.
Visual Impact. Pipeline operations shall be located in a manner to minimize their
visual impact and disturbance of the land surface.
Access Points to Public Roads. Pipeline operations shall be located in a manner
to minimize their visual impact and disturbance of the land surface.
Air Contaminant Emissions. Air contaminant emissions shall be in compliance
with the applicable permit and control provisions of the Colorado Air Pollution
Prevention and Control Act, C.R.S., Title 25, Article 7.