HomeMy WebLinkAboutApplication.pdfGarfield County
,Cor ryibri ty Uev", lopment Department
108 8`h Street, Suite 401
OCT ] flee ood Springs, CO 81601
(970) 945-8212
`' 'F'} 1t=�•)� wWW.g rfield-county.com
,'UNITy DEVELOPMENT
GRADING PERMIT
APPLICATION
TYPE OF GRADING
El MAJOR
0 MINOR
INVOLVED PARTIES
1
Property Owner: OXY USA WTP LP add. parcel owners listed Phone: ( 970 ) 263-3607
Mailing Address: 760 Horizon Drive, Suite 101, Grand Junction, CO 81506
Contractor: DIA Construction, Inc. Phone: ( 970 ) 283-5706
Mailing Address: 2171 West 1-70 Frontage Road, DeBeque, CO 81630
Architect: Pipeline Design - Tenaris Global Services (USA) Corp. Phone: ( 713 ) 767-4400
Mailing Address: 2200 West Loop South, Suite 800, Houston, TX 77027
Engineer: D.R. Griffin and Associates, Inc. Phone: ( 307 ) 362-5028
Mailing Address: 1414 Elk St. Suite 202, Rock Springs, WY 82901
PROJECT NAME AND LOCATION
Project Name: Shell 797-09A to Conn Creek 1 Pipeline
Describe Work: Install 14,457 feet of 6 -inch carbon steel pipeline at a depth of 6 feet. Pipeline will
transfer natural gas and will be installed within an existing Right-of-way.
Job Address: Section 5, T7S, R97W and Section 32, T6S, R97W, 6th PM
Assessor's Parcel Number: 2169-214-00-026, 2411-082-00-019, 2411-082-00-011, 2411-101-00-015
Sub. Lot Block
Earthwork (square feet): 722,850 Earthwork (Cubic Yards): 26,772
ALL UTILITIES MUST BE LOCATED PRIOR TO ANY GRADING
Authority. This application for a Building Permit must be signed by the Owner of the property, described above, or
an authorized agent. If the signature below is not that of the Owner, a separate letter of authority, signed by the
Owner, must be provided with this Application.
Legal Access. A Building Permit cannot be issued without proof of legal and adequate access to the property for
purposes of inspections by the Building Division.
Other Permits. Multiple separate permits may be required: (1) State Electrical Permit, (2) County ISM Permit, (3)
another permit required for use on the property identified above, e.g. State or County Highway/ Road Access or a
State Wastewater Discharge Permit.
Void Permit. A Building Permit becomes null and void if the work authorized is not commenced within 180 clays of
the date of issuance and if work is suspended or abandoned for a period of 180 days after commencement.
I hereby certify that I have read this Application and that the information contained above is true and correct. I
understand that the Building Division accepts the Application, along with the plans and specifications and other
data submitted by me or on my behalf (submittals), based upon my certification as to accuracy. Assuming
completeness of the submittals and approval of this Application, a Building Permit will be issued granting
permission to me, as Owner, to construct the structure(s) and facilities detailed on the submittals reviewed by the
Building Division. In consideration of the issuance of the Building Permit, 1 agree that I and my agents will comply
with provisions of any federal, state or local law regulating the work and the Garfield County Building Code, ISDS
regulations and applicable land use regulations (County Regulation(s)). I acknowledge that the Building Permit
may be suspended or revoked, upon notice from the County, if the location, construction or use of the structure(s)
and facility(ies), described above, are not in compliance with County Regulation(s) or any other applicable law.
1 hereby grant permission to the Building Division to enter the property, described above, to inspect the work. I
further acknowledge that the issuance of the Building Permit does not prevent the Building Official from: (1)
requiring the correction of errors in the submittals, if any, discovered after issuance; or (2) stopping construction
or use of the structure(s) or facility(ies) if such is in violation of County Regulation(s) or any other applicable law.
Review of this Application, including submittals, and inspections of the work by the Building Division do not
constitute an acceptance of responsibility or liability by the County of errors, omissions or discrepancies. As the
Owner, I acknowledge that responsibility for compliance with federal, state and local laws and County Regulations
rest with me and my authorized agents, including without limitation my architect designer, engineer and/ or
builder.
I hereby acknowledge that 1 have read and understand the Notice and Certification above as well as
have provided the required infora . tion which is correct and accurate to the best of my knowledge.
Katy Middleton
Property Owner Print and Sign
/o//6
Date
Special Conditions:
The financial security shall be held by Garfield County until vegetation has been successfully
reestablished according to the Reclamation Standards in the Garfield County Weed Management
Plan. It is the responsibility of the applicant to contact the County, upon successful re -vegetation
establishment, to request an inspection for security release consideration. Contact person: Steve
Anthony, County Vegetation Manager, ph: 623.x601
9 � - /377 '4 4305
Permit Fee:
O.00
Misc Fees: j21*
Total F es:
Balance d
BUILDING / PLANNING DIVISION
14‘
Grading Permit:
'c1
Issue Date:
�0-10-11+
Fees Paid:
4ob•DP
Zoning pit
d Approval Date
4 400. °o, \Ack VP 14114
OXY
Occidental Oil and Gas
OXY USA WTP LP
Shell 797 to Conn Creek Compressor Station
Garfield County, Colorado
Major Grading Permit
October 2014
Applicant: OXY USA WTP LP
760 Horizon Drive Suite 101
Grand Junction, CO 81506
(970) 263-3607
OXY USA WTP LP
Shell 797 to Conn Creek Compressor Station Pipeline Grading Permit
Shell 797 to Conn Creek Compressor
Station Pipeline
Major Grading Permit
Table of Contents
1. Grading Permit Application
2. Signature of Authority
3. Agent Authorization
4. Savage SUA and Authorization
5. Savage Documents
6. Shell SUA
7. Application Narrative
8. Site Plan (Provided on 24X34 inch Sheet)
9. Grading Plan (Provided on 24 X 36 inch Sheet)
10. Reclamation and Erosion Control Plan (Figures Located in Binder and on 24 X 36
Inch Sheet)
11. Vicinity Map
12. Parcel Boundary Map
13. Facilities Figure
14. Arial Map
15. Weed Inventory Report
16. Stormwater Management Plan
Grading Permit Application - Table of Contents
Garfield County Major Grading Permit Application, 2014 Page 1 of 1
OXY OXY USA WTP LP.
A subsidiary of Occidental Petroleum Corporation
October 6, 2014
Shell Exploration and Production
200 N. Dairy Ashford
WCK E 1044H
Houston, TX 77079
Attention: Mr. Brad Penn
Re: Shell 797-09-HN1 Well
Section 09-T7S-R97W
Garfield County, Colorado
Dear Mr. Penn:
5 Greenway Plaza, Suite 110, Houston, Texas 77046-0521
P.O. Box 27570, Houston, Texas 77227-7570
Kimberly Evans
Office: (713) 366-5593
Fax: (713) 985-1667
E-mail: kimberly_evans@oxy.com
With regard to the subject well, OXY USA WTP LP ("Oxy") requests certain approvals and
consents from Shell Frontier Oil & Gas Inc. and Shell Oil Company (together, "Shell").
Approvals and Consents
1. Pursuant to the terms of Article Twenty -Three (23) in that certain Oil and Gas Lease
dated June 1, 2004, between Oxy and Shell, as amended, Oxy does hereby wish to
notify Shell of its intent to install a 6" natural gas pipeline across the leases premises;
and,
2. Hereby requests permission to represent Shell in pursuing building and/or land use
applications in Garfield County solely with regard to this pipeline for the Shell 797-09-
HN1 Well.
Please forward one executed original of this letter to my attention at your earliest convenience.
Thank you for your consideration in this matter. If you have any questions, please feel free to
contact me at the telephone number listed above.
Sincerely,
OXY USA WTP LP
Kimberly Evans
Land Negotiator
Mid -Continent Business Unit
By execution hereof, Shell Frontier Oil & Gas Inc. and Shell Oil Company grant all
approvals and consents requested by Oxy in this letter agreement.
Shell F . , ti, • i & Gas Inc.
r 1
By
/ Maw
Name: Jeff Turnbull
Attorney -In -Fact
Title:
Date:
10 I 1s/2. o i y -
Shell it Company
410V‘.
Stanton S.,Lawaon
By:
Name:
ATTORNEY IN FACT
Title:
Date:
Project name/operator:
Project general location:
Pipeline Grading Permit Checklist
6'‘`I S 7970 C(c)4-090/t,r(-/2-A,a4,14 51.
Vtr r (Dle PX cwt
Project acreage: /4)/467 y, 5-0 72,218IV r a 16, ° 4C -
Project length and pipe size: M57 a 6 /! Ge3 htk e/az.
Bond Amount (must equal acreage x $2500): /o 6 n 2.'51`13 41(46 J
Weed management plan approved by Veg. Management: �C. /J
Property owners including federal lands with easements: 5144-)44 Z
Jo T o 'PO-l...r? !Cs)
c4j) 7U &t L
Engineered sealed plans:
Plan set to county engineer consultant for review:cr
State storm water permit: Co , I C
Any county road cut permits needed:o
Any land use permits needed based on size or flood plain:
Any Corp of Eng. wetland issues: 7L
Original Bond and map to Treasurer's office:
Copy of bond in file: r
Map to GIS: A(--
Other:
Pending items/date:
eCt4tiz- &iikkj - S7F- t /E -4-2-t T
44/7, ri)
3Q-7(-cer5,
CRgcb -/0-4-31/
TRAVELERS .�
BOND
(License or Permit - Continuous)
Bond No. 106147326
KNOW ALL MEN BY THESE PRESENTS:
THAT WE OXY USA WTP LP as
Principal, and TRAVELERS CASUALTY AND SURETY COMPANY OF AMERICA , a
corporation duly incorporated under the laws of the State of Connecticut and authorized to do
business in the State of Colorado , as Surety, are held and firmly bound unto
the BOARD OF COUNTY COMMISSIONERS OF GARFIELD COUNTY, COLORADO , as Obligee, in
the penal sum of Forty One Thousand Five Hundred and No/100 ( $41,Soo.00 ) Dollars,
for the payment of which we hereby bind ourselves, our heirs, executors and administrators,
jointly and severally, firmly by these presents.
WHEREAS, the Principal has obtained or is about to obtain a license or permit for
Shell 797-09A Pipeline Grading
NOW, THEREFORE, THE CONDITIONS OF THIS OBLIGATION ARE SUCH, that if the
Principal shall faithfully comply with all applicable laws, statutes, ordinances, rules or
regulations, pertaining to the license or permit issued, then this obligation shall be null and
void; otherwise to remain in full force and effect.
This bond shall become effective on October 17, 2014
PROVIDED, that regardless of the number of years this bond is in force, the Surety shall not
be liable hereunder for a larger amount, in the aggregate, than the penal sum listed above.
PROVIDED FURTHER, that the Surety may terminate its liability hereunder as to future acts
of the Principal at any time by giving thirty (30) days written notice of such termination to the
Obligee.
SIGNED, SEALED AND DATED this 17th day of October, 2014
Bv:
oxY US
TRAVEL.}$'- SUALTY AND
Principal
SURETY COMPANY OF AMERICA
By:
S -2151A (6/10)
Christine A. Dunn, Attorney-in-fact
TRAVELERS CASUALTY AND SURETY COMPANY OF AMERICA
HARTFORD, CONNECTICUT 06183
FINANCIAL STATEMENT AS OF DECEMBER 31, 2013
CAPITAL STOCK $ 6,480,000
ASSETS
LIABILITIES & SURPLUS
ASH AND INVESTED CASH
ONDS
NESTMENT INCOME DUE AND ACCRUED
THER INVESTED ASSETS
REMIUM BALANCES
ET DEFERRED TAX ASSET
EINSURANCE RECOVERABLE
ECURITIES LENDING REINVESTED COLLATERAL ASSETS
ECEIVABLES FROM PARENT, SUBSIDIARIES AND AFFILIATES
TATE SURCHARGES RECEIVABLE
'THER ASSETS
•
"OTAL ASSETS
$ 67,799,824
3,452,214,898
47,758,502
265,099,610
190,838,462
61,575,098
11,361,414
4,910,772
30,772,481
258,771
14,872,822
$ 4,147,460,454
UNEARNED PREMIUMS
LOSSES
LOSS ADJUSTMENT EXPENSES
COMMISSIONS
TAXES, LICENSES AND FEES
OTHER EXPENSES
FUNDS HELD UNDER REINSURANCE TREATIES
CURRENT FEDERAL AND FOREIGN INCOME TAXES
REMITTANCES AND ITEMS NOT ALLOCATED
AMOUNTS WITHHELD / RETAINED BY COMPANY FOR OTHERS
RETROACTIVE REINSURANCE RESERVE ASSUMED
POLICYHOLDER DIVIDENDS
PROVISION FOR REINSURANCE
ADVANCE PREMIUM
PAYABLE FOR SECURITIES LENDING
DERIVATIVES
CEDED REINSURANCE NET PREMIUMS PAYABLE
ESCHEAT LIABILITY
OTHER ACCRUED EXPENSES AND LIABILITIES
TOTAL LIABILITIES
CAPITAL STOCK
PAID IN SURPLUS
OTHER SURPLUS
TOTAL SURPLUS TO POLICYHOLDERS
TOTAL LIABILITIES & SURPLUS
$ 806,717,671
809,863,176
460,670,453
31,781,136
12,482,322
38,437,893
94,401,464
18,387,407
13,677,503
23,615,357
1,511,674
8,482,513
3,970,484
1,078,609
4,910,772
112,003
(04,954,254)
471,948
242,236
$ 2,285,740,367
$ 6,480,000
433,803,760
1,441,436,327
$ 1,881,720,088
$ 4,147,460454
(TATE OF CONNECTICUT
IOUNW OF HARTFORD
3ITY OF HARTFORD
)
) SS.
AICHAEL J. DOODY, BEING DULY SWORN, SAYS THAT HEIS SECOND VICE PRESIDENT, OF TRAVELERS CASUALTY AND SURETY COMPANY OF AMERICA,
WD THAT TO THE BEST OF HIS KNOWLEDGE AND BELIEF, THE FOREGOING ISA TRUE AND CORRECT STATEMENT OF THE FINANCIAL CONDITION OF SAID
;OMPANYAS OF THE 31ST DAY OF DECEMBER, 2013.
SUBSCRIBED AND SWORN TO BEFORE ME THIS
19TH DAY OF MARCH, 2014
'iaa4a4)%J00c
SECOND VICE PRESID N
\S .V �—. h
NOTARY PUBLIC
SUSAN M. WEISSLEDER
Notary Public
Afy Commission Expires November 30, 2017
TRAVELERS J
WARNING: THIS POWER OF ATTORNEY IS INVALID WITHOUT THE RED BORDER
POWER OF ATTORNEY
Farmington Casualty Company
Fidelity and Guaranty Insurance Company
Fidelity and Guaranty Insurance Underwriters, Inc.
St. Paul Fire and Marine Insurance Company
St. Paul Guardian Insurance Company
AttorneyIn Fact No. 227772
St. Paul Mercury Insurance Company
Travelers Casualty and Surety Company
Travelers Casualty and Surety Company of America
United States Fidelity and Guaranty Company
Certificate No. 005837798
KNOW ALL MEN BY THESE PRESENTS: That Farmington Casualty Company, St. Paul Fire and Marine Insurance Company, St. Paul Guardian Insurance
Company, St. Paul Mercury Insurance Company, Travelers Casualty and Surety Company, Travelers Casualty and Surety Company of America, and United States
Fidelity and Guaranty Company are corporations duly organized under the laws of the State of Connecticut, that Fidelity and Guaranty Insurance Company is a
corporation duly organized under the laws of the State of Iowa, and that Fidelity and Guaranty Insurance Underwriters, Inc., is a corporation duly organized under the
laws of the State of Wisconsin (herein collectively called the "Companies"), and that the Companies do hereby make, constitute and appoint
David C. Rosenberg, Harry C. Rosenberg, Matthew J. Rosenberg, Sherri L. Feeney, David A. Johnson, Christine A. Dunn, Julia R. Burnet,
Kimberly G. Rively, Joyce M. Houghton, Denise M. Bruno, Michelle G. Higgins, and Jonathan F. Black
of the City of King of Prussia State of Pennsylvania
, their true d lawfuleach in their separate capacity if more than one is named above, to sign, execute, seal and acknowledge any and all bonds, rec gnizan esn conditionalltomeyundertakings and
other writings obligatory in the nature thereof on behalf of the Companies in their. business of guaranteeing the fidelity of persons, guaranteeing the performance of
contracts and executing or guaranteeing bonds and undertakings required or permitted in any actions or proceedings allowed by law.
IN WITNESS WHEREOF, the Companies have caused this instrumentto be signed and their corporate seals to be hereto affixed this 20th
day of March 2014
Farmington Casualty Company
Fidelity and Guaranty Insurance Company,
Fidelity and Guaranty Insurance Underwriters, Inc.
St. Paul Fire and Marine Insurance Company
St. Paul Guardian Insurance Company
State of Connecticut
City of Hartford ss.
St. Paul Mercury Insurance Company
Travelers Casualty and Surety Company
Travelers Casualty and Surety Company of America
United States Fidelity and Guaranty Company
JW 04P14g4tit
E'
e1�38AL i
By:
O rr/1
Ruben L. Raney, enior Vice President
On this the 20th day of March 2014
before me personally appeared Robert L. Raney, who acknowledged himself to
be the -Senior Vice President of Farmington Casualty Company, Fidelity and Guaranty Insurance Company, Fidelity and Guaranty Insurance Underwriters, Inc., SL Paul
Fire and Marine Insurance Company, St. Paul Guardian Insurance Company, St. Paul Mercury Insurance Company, Travelers Casualty and Surety Company, Travelers
Casualty and Surety Company of America, and United States Fidelity and Guaranty Company, and that he, as such, being authorized so to do, executed the foregoing
instrument for the purposes therein contained by signing on behalf of the corporations by himself as a duly authorized officer.
In Witness Whereof, I hereunto set my hand and official seal.
My Commission expires the 30th day of June, 2016.
58440-8-12 Printed in U.S.A.
i rLQM.b . i �� rig. .k
Mane C. Tetreault, Notary Public
WARNING: THIS POWER OF ATTORNEY IS INVALID WITHOUT THE RED BORDER
1111 WI' 11111
Reception#: 783258
03/15/2010 02:32:69 PM Jean Alberioo
1 of i Rec Fee:$11.00 Doo Fee:0.00 GARFIELD COUNTY CO
STATEMENT OF AUTHORITY
Chris G. Clark, Regulatory Coordinator/Lead for OXY USA WTP LP, a Delaware
limited partnership, and for OXY USA Inc., a Delaware corporation (jointly "Oxy"),
760 Horizon Drive, Grand Junction, Colorado 81506, is authorized to act on
behalf of, and represent Oxy in all matters related to applications for special use
permits, conditional use permits, administrative permits, limited impact review,
major impact reviews, and land use change permits (and may execute such
applications) submitted to Garfield County, Colorado until such time as Oxy files
of record a statement that Mr. Clark no longer has such authority. Oxy
acknowledges that when any such permits are issued by Garfield County,
Colorado, the County may choose to file them of record and such permits may
contain certain covenants that run with the particular lands identified in such
permits.
OXY USA WTP LP
By: OXY USA Inc., its general partner
By: .
Name: William B. Roby
Title: Vice President, Mid -Continent
OXY USA Inc.
By: L...5,1C.
.
Name: William B. Roby
Title: Vice President, Mid -Continent
STATE OF TEXAS
COUNTY OF HARRIS
This instrument was acknowledged before me on this 5- day of March,
2010, by William B. Roby, Vice President of OXY USA Inc. a Delaware
corporation on behalf of OXY USA Inc., a Delaware corporation and on behalf of
OXY USA WTP LP, a Delaware limited partnership.
My Commission Expire
(AVOW t2 M /544101K
Notary Public, State of Texas
CHRISTINE 11 SANCHEZ
My Commission Expires
J4iy 2, 2015
ic>G t-1 j
,'"U OXY USA WTP LP
OXYv
June 4, 2014
Ms. Tamra Allen
Community Development Department
Garfield County
108 8`h Street, Suite 401
Glenwood Springs, CO 81601
RE: Agent Authorization for OXY USA WTP and OXY USA Inc. permitting projects
Garfield County, Colorado
Dear Ms. Allen,
760 Horizon Dr., Suite 101
Grand Junction, CO 81506
Phone 970.263.3600
OXY USA WTP LP and OXY USA Inc. (Oxy) authorizes Blair Rollins with Olsson Associates and Katy Middleton with
Blue Sky Permitting and Planning, LLC to act on behalf of and represent Oxy in matters related to land use
permitting projects located in Garfield County, Colorado,
Please contact me if you have any questions, comments, concerns, or if you require additional information. I can
be reached at 970.2633607 or at chris clark@oxv.com.
Sincerely,
ris Clark
Operations Manag
Cc: file
Olsson
1
SURFACE USE AGREEMENT
THIS SURFACE USE AGREEMENT (the "Agreement"), is made and entered into as of
June 1, 2006 (the "Effective Date"), by and among Savage Limited Partnershipl, a
Colorado limited partnership, 5953 County Road 320, Rifle, Colorado 81650 ("Savage
LP" or "Surface Owners Representative"), Joan L. Savage, c/o Savage LP, Daniel W.
Stroock, c/o Savage LP and Sue van de Bovenkamp, c/o Savage LP (each, a "Surface
Owner" and together, "Surface Owners"), and Surface Owners do hereby agree to
designate Savage LP as their Surface Owners Representative, and OXY USA WTP LP,
P.O. Box 27757, Houston, Texas 77046-0506 ("Operator").
RECITALS
WHEREAS, the property (the "Property") is located in Garfield County, Colorado and
described as:
Township 7 South Range 97 West 6'" PM Acres
Tract 38
159.99
West 20 acres of Tract 39, Except 1.26
acres (as described in Deed at Book 144 at
Page 66)
18.74
Tract 40
160.00
Tract 41
40.00
Tract 42
120.00
Tract 48
160.00
Tract 49
160.00
Being parts of Sections 5, 8, 9, 17 and 18
818.73
Garfield County, Colorado
and
WHEREAS, Surface Owners desire to grant Operator certain rights to use of the
surface and subsurface of the Property for Operator's oil and gas exploration and
production operations; and
WHEREAS, subject to the terms and conditions of any oil and gas leases that affect the
Property and in which Operator is a lessee, Operator proposes to (i) construct and
operate one or more well sites on the Property for the purposes of drilling and producing
one or more oil and gas wells to bottom hole locations on and/or off the Property and (ii)
construct and/or place roads and pipelines and other structures and facilities on the
surface of the Property as the Operator may deem necessary.
NOW, THEREFORE, in consideration of the mutual promises and covenants set forth
herein, the parties hereto agree as follows:
Page 1 of 27
5/30/2006
I. SURFACE USE
A. GRANT BY SURFACE OWNERS:
Surface Owners hereby grant Operator the right to use of the surface and
subsurface of the Property for Operator's oil and gas exploration and
production operations. This grant by Surface Owners shall be in addition
to the rights granted to Operator under any oil and gas leases it may own
that affect the Property, and Includes, but is not limited to (1) the right to
use the surface and subsurface of the Property to drill, produce and
operate one or more well sites on the Property with bottom hole locations
off the Property, (ii) the right to construct and/or place roads and pipelines
and other structures and facilities on the surface of the Property as the
Operator may deem necessary for its operations, (iii) the right to construct
buildings, treatment facilities, individual well compressors, fresh water
storage and / or produced water evaporation pits on the Property to be
used in connection with conventional oil and gas drilling operations, (iv)
the right of ingress to and egress from the Property, and (v) the right to
transport water over and across the Property.
Operator's rights with respect to wells with bottom hole locations on the
Property shall be govemed by Operator's oil and gas lease(s) that affect
the Property, but surface operations conducted on the Property shall be
subject to the provisions of Section I.B. through I.F. and Sections ll, 111 and
IV hereof. Attached to this Agreement as Exhibit A are the oil and gas
leases owned by Operator underlying all or a portion of the Property as of
the Effective Date. During the term of this Agreement, Operator shall
provide to the Surface Owners Representative any other oil and gas
leases that underlie the Property that are entered into by Operator after
the Effective Date.
B. TERM:
1. The initial term of this Agreement shall commence as of the Effective
Date and shall continue for five years (the "Initial Five Year Term").
Thereafter, this Agreement shall automatically renew for one or more
additional five year terms ("Additional Five Year Term") without any action
on the part of either party, unless Operator elects to terminate this
Agreement at the end of the Initial Five Year Term or any Additional Five
Page 2 of 27
5/30/2006
Year Term by providing notice of such termination to Surface Owners
Representative no later than thirty (30) days prior to such termination date.
2. Within sixty (60) days after the termination of this Agreement (plus a
reasonable number of additional days in the event of the occurrence of a
Force Majeure event during such sixty (60) day period), Operator shall
properly plug and abandon all wells drilled on the Property, remove all
buildings and other encumbrances supporting such production, provided,
however, that pipelines do not have to be removed, and may be
abandoned in place. "Force Majeure" shall mean a cause or event that is
beyond the reasonable control of the party claiming Force Majeure and
could not have been reasonably prevented or avoided by it.
3. If Operator requires more time than that which is described in Section
1.8.2., then Operator shall pay Surface Owners Representative $328.77
per day, as Adjusted (as defined in Exhibit B hereto) for the number of
additional days needed to complete the tasks described in Section I.B.2,
provided, however, that within twelve months after the termination of this
Agreement (plus a reasonable number of additional days in the event of
the occurrence of a Force Majeure event during such twelve month
period), Operator shall have completed the tasks described in Section
I.B.2. Per diem amounts are to be paid within ninety (90) days of the last
day of the month in which such charges were incurred.
C. COMPENSATION:
1. Operator shall pay the sum of Three Hundred Thousand Dollars
($300,000.00) to the Surface Owners' Representative within thirty
days after the Effective Date.
2. So long as this Agreement is in effect and has not terminated,
Operator shall make an annual payment ("Annual Payment") As
Adjusted (as defined in Exhibit B hereto) to Surface Owners'
Representative on or before the anniversary of the Effective Date in
accordance with the payment schedule attached hereto as Exhibit
B.
3. Upon the termination of this Agreement in accordance with Section
I.B., there will be no further compensation paid by Operator
pursuant to this Agreement except as provided for in Section 111.8, if
necessary.
4. The Surface Owners' Representative shall be responsible for
distributing to each Surface Owner such Surface Owner's share of
any compensation payment made pursuant to this Agreement.
Operator shall have no further responsibility or liability to any
Page 3 of 27
5/30/2006
Surface Owner for any compensation payment once Operator has
made such payment to the Surface Owners' Representative.
D. RELEASE OF LIABILITY:
As part of the consideration for the compensation to be provided by
Operator pursuant to Section I.C., Surface Owners hereby forever release,
acquit and discharge Operator, its affiliates, agents, principals, partners,
assigns, employees, contractors and subcontractors from any and all
liability for ordinary, customary and usual damage to the Property and
detriment incident to or growing out of Operator's use of the Property,
including but not limited to the moving in and out of well locations, the
establishment, preparation, and use of the well sites, including tank
batteries as needed, the construction, repair and maintenance of pipelines
and roads and all other activities including but not limited to construction,
use, maintenance, and repair, incident to and necessary for the
establishment, drilling, completion, operation, production and
abandonment of the said wells, and the transportation of oil and gas
production, subject to the representations, agreements and obligations set
forth herein.
E. LIABILITY FOR ADDITIONAL INJURIES:
Nothing in this Agreement shall create any liability for any Surface Owner
due to Operator's entry upon the Property, except as described in
Sections I.D. and IV.H. Operator shall be liable for any injury to persons
or personal property caused by the operations of Operator, its agents,
employees, contractors on the property, or any extraordinary damages to
the Property due to spills of hazardous materials, explosions, or any other
harmful activity of Operator not otherwise released under Section I.D.
F. LIMITATIONS:
1. The right to use the surface and subsurface of the Property for
operations related to bottom hole locations of wells located off the
Property is limited to those wells which are wholly or partially
owned by Operator and/or those wells that are operated by the
Operator.
2. The compensation recited in Section I.C.1. and 1.C.2. includes
compensation for well site damages for any and all wells with
bottom holes located on the Property and up to ten (10) wells with
bottom holes located off the Property. Thereafter, Operator shall
pay Surface Owners $10,000, As Adjusted (as defined in Exhibit B
hereto), as additional compensation for any well in excess of ten
(10) with a bottom hole located off the Property. Any such amount
Page 4 of 27
5/30/2006
is to be paid within ninety (90) days of the date on which such
amount was incurred.
3. The use of well pads, roads, and pipelines granted pursuant to this
Agreement is not assignable to other operators, provided, however
that Operator may assign the use of any well pad, pipeline or road
pursuant to one or more asset sales or transfers by Operator.
4. This Agreement is for conventional oil and gas operations only and
specifically excludes any use of the Property for oil shale
development, production, or operations.
5. The locations of all facilities to be constructed by Operator on the
Property are to be determined by mutual agreement between
Operator and Surface Owners Representative, such agreement not
to be unreasonably withheld. Operator and Surface Owners shall
not allow use of fresh water storage and / or produced water
evaporation pits on the Property by other operators or any other
person.
G. SURFACE OWNERS' RESERVATION:
1. Surface Owners may grant similar rights of use to other operators
so long as such use is made subject to, and does not interfere with,
Operator's operations on or across the Property.
2. All surface uses not inconsistent with the rights of Operator,
including the right to grant to third parties successive easements
thereon or across said lands, are hereby reserved to the Surface
Owners.
H. WATER RIGHTS:
This Agreement does not grant to Operator the right to use water owned
by Surface Owners located on the Property or water rights of Surface
Owners, except as specified in a separate written agreement among the
parties hereto.
11. OPERATIONS
A. WELL SITE DETAILS:
1. At least 30 days prior to commencing operations with drilling
equipment for drilling a well on the Property, the Operator shall
evidence its intention to conduct such operations by giving the
Page 5 of 27
5/30/2006
Surface Owners written notice thereof in lieu of any notice
provisions of Rule 305 of the Colorado Oil and Gas Conservation
Commission ("COGCC"). Operator shall provide the following:
a. The estimated date that operations are to commence.
b. A plat or legal description indicating the quarter section upon
which the operations will be conducted.
c. Dimensions of the drill site, if known, the location of
associated production facilities, pipelines, and roads.
2. The well pad and road access located on the Property shall be kept
safe and in good order, and shall at all times be kept free of weeds,
litter, and debris.
3. All drilling fluids and mud shall be handled in accord with COGCC
regulations.
4. The disturbed area for each well pad shall not exceed a reasonable
area for the number of well bores to be drilled, plus additional areas
adjacent to such well pad for the stockpile of topsoil and fill.
5. All dehydrator/tank sites shall be subject to the terms and
conditions of this Agreement.
6. Without written consent from Surface Owners Representative,
which consent shall not be unreasonably withheld, a maximum of
one well site pad will be allowed on each governmental quarter -
quarter section or tract equivalent to 40 acres. Operator may drill
multiple wells from such well pad site.
7. Well sites shall not encroach upon platted/deeded right of ways or
utility easements unless otherwise agreed.
8. The Surface Owners are responsible for notifying any affected
tenant of the operations.
B. WELL SITE PITS:
All production pits shall be constructed and maintained in compliance with
all applicable state and federal regulations and are to be lined unless
mutually agreed that a liner is not necessary to prevent leakage due to
local soil conditions. All well site pits are to be properly reclaimed, and
liners removed, unless it is mutually agreed to bury the liner in place, in
which case a liner disposal fee of one thousand dollars ($1,000), As
Adjusted (as defined in Exhibit B hereto), will be paid by Operator.
Page 6 of 27
5/30/2006
C. ROADS:
1. Access roads shall be constructed by Operator or its contractors
and the location of such roads shall be subject to the approval of
the Surface Owners Representative, such approval not to be
unreasonably withheld. Operator shall provide Surface Owners
Representative with a proposed survey of routes which shall be
staked prior to Surface Owners Representative's review.
2. Roads used by Operator shall be constructed or upgraded to
standards as described in "Surface Operating Standards for Oil and
Gas Exploration and Development" 4th Edition, Prepared by the
Bureau of Land Management ("BLM") / Forest Service Rocky
Mountain Regional Coordinating Committee or of similar utility.
3. Road rights of way shall be limited to 30' feet in width with a 20 -foot
travel surface. Roads may be widened beyond the right of way in
places where such widening is necessary upon approval of the
Surface Owners Representative, such approval not to be
unreasonably withheld. Such widening is to be limited to the
minimum practical extent.
t. Roads used by Operator shall be properly graded, drained, and
maintained by Operator. If and when oil and gas drilling operations
commence on lands using access roads constructed and improved
by Operator, Surface Owners shall require other surface tenants
using such roads to enter into a cooperative agreement with
Operator to allocate proportionate road capital and maintenance
expenses.
5. Culverts, at ditch and drainage crossings, and barrow pits shall be
installed where roads cross ditches or drainages. Operator shall
obtain Army Corps of Engineers permits for drainage crossings
where required and provide Surface Owners Representative with a
copy of each permit. Operator shall bear responsibility for repair
and maintenance of such culverts and liability for flooding or other
damage caused by such culverts.
6. Permanent gates or cattle guards shall be installed at each point
where Operator's access roads cross fences. Any fence cut shall
be restored to BLM fence specifications. If Surface Owners or
Operator chooses to lock any gates on access routes, keys will be
provided to Operator or Surface Owners Representative by the
party locking the gate. Gates on access roads will only be locked
during drilling operations if trespass problems occur and during big
game hunting seasons.
Page 7 of 27
5/30/2006
7. Any roads used by Operator pursuant to this Agreement shall
remain passable at all times, if practicable, except during actual
construction.
8. Surface Owners shall have the right to require relocation of access
roads to accommodate its uses of the Property provided that such
road relocation does not impose undue burden to Operator.
Relocated access roads shall be of similar utility, and all costs
associated with such relocation shall be at Surface Owners'
expense.
9. All roads shall be for the private use of Operator, its agents,
employees, and contractors only, with no right of use by the public.
Surface Owners reserve the right to use all such roads for any
purpose that does not unreasonably interfere with Operator's
operations.
10. COGCC regulations notwithstanding, Surface Owners
Representative shall have the right to designate roads constructed
or improved by Operator as permanent roads. Permanent roads
will not be reclaimed after completion of production activities by
Operator. Any obligation or liability imposed upon Operator, as the
result of not reclaiming any such permanent road, shall, after the
end of oil and gas operations, be assumed by Surface Owners.
11. Power transmission lines, if any, will be located within road rights of
way as far as is physically practicable. Location of transmission
lines to be determined by mutual agreement, such agreement not
to be unreasonably withheld.
D. FACILITIES
Operator may construct buildings, treatment facilities, individual well
compressors, and fresh water storage and / or produced water
evaporation pits on the Property to be used in connection with
conventional oil and gas drilling operations. The location of all such
facilities are to be determined by mutual agreement between Operator and
Surface Owners Representative, such agreement not to be unreasonably
withheld. Operator and Surface Owners shall not allow use of said pit by
other operators or any other person.
E. PIPELINES
1. Surface Owners grant to Operator the right to construct and
operate pipelines under this Agreement for service or transport of
Page 8 of 27
5/30/2006
water and production from Operator's oil and gas wells both on the
Property and off the Property.
2. Pipelines shall have a construction right of way of 50' in width and
the completed rights of way shall be limited to 25' feet on either side
of the installed pipeline. Pipelines shall be installed to one side of a
road right of way where practicable.
3. Where practicable, all pipelines and flow lines outside of the
permanent well site shall be buried at least three feet below final
grade.
4. Pipeline routes, where practicable, shall be installed within roadway
rights of way and parallel to and as close to existing pipelines as
safe engineering practice allows. Operator shall provide Surface
Owners Representative with surveyed as -built drawings of all
pipelines constructed on the Property. Proposed pipeline routes to
be flagged by Operator and routes to be determined by mutual
agreement, such agreement not to be unreasonably withheld.
F. SPECIAL CONDITIONS:
1. Nothing in this Agreement shall create an exclusive right to occupy
the Property.
2. Operator's use of the Property shall take precedence over
agricultural and other uses during the term of this Agreement. Any
livestock grazing, irrigation, harvesting or other agricultural
operations shall be performed by Surface Owners and their tenants
so as to accommodate Operator's use of the Property. Any other
use of Property by Surface Owners or use of Property by other
parties allowed by Surface Owners shall be consistent with
Operator's use of the Property.
III. RECLAMATION
A. INTERIM RECLAMATION:
After initial surface disturbance resulting from the construction of a well
pad, laying of pipelines, and construction of other facilities, Operator shall
restore all disturbed areas to their original grade and vegetation as soon
as practicable, but in no case later than one year, following completion
(weather permitting) of the last well drilled on such well pad. Topsoil shall
be stockpiled and replaced in conformance with COGCC Regulations.
The reclamation shall not apply to the well site or roads except as
otherwise provided herein.
Page 9 of 27
5/30/2006
1. The portion of the well pad to be reclaimed shall be returned to the
original topography and vegetation planted and successfully
established comparable to that existing prior to construction.
2. All non -traveled portions of non -permanent roadways and pipelines
shall be seeded per BLM specifications.
3. If any subsequent disturbance of surface areas outside the well pad
are undertaken at any time, the same reclamation and revegetation
obligations will apply.
4. Operator shall be responsible for maintenance for all disturbed
areas around the well pad, roads, and pipelines as long as they are
in use.
5. Any rocks excavated by Operator that are too large (over 50
pounds each) to be incorporated into fill or reclamation shall be
stockpiled at a location designated by Surface Owners. Slash may
be disposed of on-site at a location and manner to be agreed to by
Surface Owners.
6. Operator shall be responsible for weed control in all areas disturbed
by Operator for the term of this Agreement until revegetation with
acceptable grasses and other vegetation has been completed. Any
weed control or mediation of disturbed areas required by a
governmental entity as a result of Operator's operations shall be
the responsibility of Operator.
B. FINAL RECLAMATION:
Page 10 of 27
5/30/2006
Within one hundred eighty (180) days after the termination of this
Agreement (plus a reasonable number of additional days in the event of
the occurrence of a Force Majeure event during such one hundred eighty
(180) day period), Operator shall return roads (except permanent roads as
designated by Surface Owners), rights of way, pipelines, and sites, the
use of which is to be terminated, to their original grade and vegetation, as
nearly as possible, and shall remove from the Property all materials
installed by Operator, except for (a) properly plugged and abandoned
wells, (b) pipelines abandoned in place and (c) materials that Surface
Owners Representative has approved to remain on the Property. If
Operator requires more time than that which is described in this Section,
Operator shall pay Surface Owners $328.77 per day, As Adjusted (as
defined in Exhibit B hereto), for the number of additional days needed to
complete the tasks described in this Section. Per diem amounts are to be
paid within ninety (90) days of the last day of the month in which such
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14122 0R/14 0,00 GARFIELD
1 of 28 R 141.00 D
COUNTY CO
OIL AND GAS LEASE
2004, by and between Shell Frontier
T011 TX & Gas entered into as of June address of P.O. Box 576,
THIS AGREEMENT. having
Inc., a Delaware corporation,
001,
Greenway
on TX 77046, hereinafter referred to as "LESSEE", WITNESSETH:
hereinafter referred to t s 'LESSOR", and OXY USA WTP LP, whose address is 5 other good
Plaza, Suite 110, Houston,
the receipt andosufficiency of which are herebyd
1. LESSOR, for and in consideration of the sum of Ten Dollars ($10.00 andhas this
and valuable aodso on, agreements hereinafter contained,
acknowledged, a, and of the, and covenantsrebyand oil and/or gas,
rants, leases and lets, unto LESSEE for the sole
g
adnd only
ytp and of ex, hedebng and operating for and producing
and whether puuid or of gaseous,
ng described land in Garfield County,
liquid gaseous, from the following
Colorado, to -wit:
Township-
Ranie
6S -97W
Sections
9, 10
7S®
10
10
10
10
Lands
Lot 1 54.72 , Lot 2 54.78
Tract 71 (48.48 ac), Tract 72 (160 ac), Lot 5
(14.75 ac), Lot 6 (32.60 ac), Lot 7 (22.15 ac),
SEI4SE/4
Amended Tract 75, Subtract F of Tract 77
Tract 92 (160 ac), Tract 93 (160 ac),
Tract
ct(495
(160 ac), Tract 94 A (40 ac), at
9ac , Tract 94 F 10 ac
S/2SI2NI2SEJ4, S/2N/2SI2NI2SE/4
S/2SE/4, SEJ4SWl4, Lot 4 23.82 ac
Lot 1 (23.88 ac), Lot 2 (23.87 ac), Lot 3
23.85 ac , E,/2NW/4, NE/4SW/4
�y.
S/2S/2N/2SE/4, S
I2N
I2
SFJ4,
®7S 97W S/2SW/4, S/2S/2N/2SW/4,
SI2N/2SI2N/2SW21,S/2S/2N/2SW/4, S/ZN/2SI2N/2SW/4
101IS-97W SI2SI2NI2SEl4,/N/2SIE
SW/4, SWI4NW/4, also described as:
.07 ac),
LotEl2SW/4,. Lot 1 (39.75 ac), Lot 2 Tract 105 A (.25 ac ), Tract
0t 3 (22 .4 aa), c
105 B (26.49 ac); includes Mountain Boy
Claims 1, 6 and 7
NE/4, EI2NW/4, SW/4NW/4 Lot 1 39.92 ac
7S -97W
OIL & GAS LEASE.tloc - PAGE 1
North 4.5 acres of NW/4NW/4
109.50
177.04
570.00
30.00
191.60
210.00
60.00
160.00
220.00
120.00
199.56
160.00
4.50
After recordin return to:
Kent Woo ley
OXY U.S.A. Inc.
5 Greenway Plaza, Suite 110
Houston, TX 77046
1.11111111111111111 111 11111111 1111 111111 111 11111 1111 iiia
654127 06/14/2004 04:43P B1596 P532 M RLSDORF
3 of 28 R 141.00 D 0.00 GARFIELD COUNTY CO
6. LESSEE shall deliver to the credit of LESSOR, as royalty, free of all cost whatsoever, in
the pipeline to which LESSEE may connect its wells, the equal 15% of 8/8ths part of all
oil and other liquid hydrocarbons produced and saved from said land or from lands with
which this lease has been pooled.
7. LESSEE shall pay LESSOR, as royalty, free of all costs whatsoever, for all gaseous
substances produced from said land and used by LESSEE, or for the manufacture of
gasoline or any other product, 15% of 8/8ths of the market value of such gaseous
substances at the well. If any gaseous substance is sold by LESSEE, then LESSEE
shall pay LESSOR, as royalty, free of all costs whatsoever, except taxes on production,
15% of 8/8ths of the gross proceeds derived from the sale of such gaseous substance at
the well, or if sold away from the well, then 15% of 8/8ths of the gross proceeds less the
costs of transportation. If, at the expiration of the primary term or at any time thereafter,
there is a unit well, which is capable of producing gas in paying quantities, and such well
is shut-in, this lease as to the shut-in unit shall nevertheless continue in force, If, at any
time after the expiration of the primary term, as to each unit, a unit well is shut-in for a
period of ninety (90) consecutive days, then at or before the expiration of said ninety (90)
day period, LESSEE shall pay or tender by check or draft of LESSEE, as royalty, a sum
equal to one Dollars ($1.00) for each acre of this lease within the shut-in unit. LESSEE
shall make like payments or tenders at or before the end of each succeeding ninety (90)
day period until the lease expires as to that unit or commercial production is restored.
After expiration of the Primary Term, this lease, as to each unit, shall terminate upon the
accumulation of 365 consecutive days of non production for said unit.
8. On or before the last day of each calendar month, LESSEE shall make payment of the
royalties due LESSOR under this lease for the preceding calendar month for oil for the
calendar month and two months prior for gas. LESSEE shall, upon written request,
promptly furnish LESSOR with copies of run tickets and any contracts entered into for
the sale or processing of oil, gas or other hydrocarbons from said land. LESSOR may
also examine the books kept. If LESSEE shall fail to pay promptly any installment of
royalty, and if such default shall continue for a period of thirty (30) days after written
demand therefor, then at the option of LESSOR, this lease shall forthwith terminate;
provided, however, that if there is a bona fide dispute as to the amount due, and all
undisputed amounts are paid, said thirty (30) day period shall be extended until ten (10)
days after such dispute is settled by final court decree, arbitration or mutual agreement.
9. Payout Options - Upon payout as to any and all wells drilled hereunder (for the purposes
of this Agreement payout shall be deemed to have occurred when the proceeds from the
sale of production from any well, less royalties and lease burdens created prior to the
date of this Agreement, including the royalty herein reserved, and production and other
comparable taxes, including excise, windfall profits and/or severance taxes, equal the
cost of drilling, testing, completing and equipping the well, plus operating expenses prior
to payout), LESSOR shall have the option to either:
(a) Escalate the royalty interest herein reserved to an undivided seventeen and one-half
percent (17.5%) royalty interest as to that interest assigned to the designated unit
established for such well, together with a proportionate interest in such well; or
(b) Convert, free of cost, the royalty interest herein reserved to an undivided thirty
percent (30%) working interest as to that interest assigned to the designated unit
OIL 8 GAS LEASE.doc - PAGE 3
-111111111111111111111111111111111111111 1111111111111111
654127 06/14/2004 04:43P B1596 P534 M ALSDORF
5 of 28 R 141.00 D 0.00 GARFIELD COUNTY CO
units are required, under any governmental rule or order, for the drilling or operation of a
well at a regular location, or for obtaining maximum allowable, from any well to be drilled,
drilling, or already drilled, any such unit may be established or enlarged, to conform to
the size required by such governmental order or rule. LESSEE shall exercise said option
as to each desired unit by executing an instrument identifying such unit and filing it for
record in the public office in which this lease is recorded. Each of said options may be
exercised by LESSEE from time to time, and whether before or after production has
been established either on said land or on the portion of said land included in the unit or
on other land unitized therewith and any such unit may include any well to be drilled,
being drilled or already completed. A unit established hereunder shall be valid and
effective for all purposes of this lease even though there may be land or mineral, royalty
or leasehold interests in land within the unit which are not pooled or unitized. Any
operations conducted on any part of such unitized land shall be considered, for all
purposes, except the payment of royalty, operations conducted under this lease. There
shall be allocated to the land covered by this lease included in any such unit that
proportion of the total production of unitized minerals from wells in the unit, after
deducting any used in lease or unit operations, which the number of surface acres in the
land covered by this lease included in the unit bears to the total number of surface acres
in the unit. The production so allocated shall be considered for all purposes, including
the payment or delivery of royalty, overriding royalty, and any other payments out of
production, to be the entire production of unitized minerals from the portion of said land
covered hereby and included in such unit in the same manner as though produced from
said land under the terms of this lease. The owner of the reversionary estate of any term
royalty or mineral estate agrees that the accrual of royalties pursuant to this paragraph
or of shut-in royalties from a well on the unit shall satisfy any limitation of term requiring
production of oil or gas. The formation of such unit shall not have the effect of changing
the ownership of any shut-in production royalty which may become payable under this
lease. Neither shall it impair the right of LESSEE to release from this lease all or any
portion of said land, except that LESSEE may not so release as to lands within a unit
while there are operations thereon for unitized minerals unless all pooled leases are
released as to lands within the unit. LESSEE may dissolve any unit established
hereunder by filing for record in the public office where this lease is recorded a
declaration to that effect, if at that time no operations are being conducted thereon for
unitized minerals. A unit may be so established, modified or dissolved during the life of
this lease. Anything contained herein to the contrary notwithstanding, as to any well
drilled on the leased premises and not pooled or unitized with other leases, a production
unit equal to 80 acres for oil or 320 acres for gas shall be allocated to the lease well as a
production unit with the unit having the unit well as nearly as possible in the center of the
unit.
13. If a well capable of producing oil, gas and other hydrocarbons in paying quantities
should now exist or hereafter be completed within six hundred (600) feet o1 said land in
the case of an oil well, or one thousand five hundred (1,500) feet of said land in the case
of a gas well, or within such greater distances as may be established by governmental
authority as part of a drilling, spacing or unitization pattern, and if no well offsetting same
should have been drilled on said land, then within one hundred eighty (180 )days from
the date hereof in the case of a well existing as of the date of this lease, or within one
hundred eighty (180)days of the drilling rig release in the case of a well completed
within six hundred (600) feet in the case of an oil well and one thousand five hundred
(1,500) feet in the case of a gas well, during the period of time this lease is in effect, then
LESSEE shall either commence operations for, and thereafter diligently prosecute the
OIL & GAS LEASE.dac — PAGE 5
'I 111111 11111111111111111111111111 111111111 11111 1111 1111
654127 06/14/2004 04:43P 61596 P536 11 RLSDORF
• 7 of 28 R 141.00 D 0.00 GARFIELD COUNTY CO
such specifications in accordance and as required by the State of
Colorado Oil and Gas Conservation Commission regulations.
iii.) LESSEE shall be vacated from the designated tract(s) within 180 days of
receipt of the Notice to Vacate. LESSEE's failure to vacate the designated
tracts in the designated amount of time shall be viewed as trespass of
LESSEE.
iv.) This lease shall terminate as to those tracts designated in the Notice to
Vacate.
v.) LESSOR shall not serve a Notice to Vacate prior to June 1, 2019. If
LESSEE receives the Notice to Vacate at anytime after June 1, 2019, ,
LESSOR agrees to pay to LESSEE for the producing well requested to be
vacated, the oil and gas reserves producible therefrom, and the
equipment located thereon, all at the appraised fair market value. Unless
the LESSOR and LESSEE agree otherwise, the appraised fair market
value of the well in question shall be the present value as of the date of
the Notice to Vacate of the future net revenue and costs (based on the
average of such costs during the preceding twelve months) estimated to
be received therefrom, as determined in accordance with generally
accepted engineering principles in effect at the time, by a nationally
recognized petroleum engineering firm agreed upon by LESSOR and
LESSEE. The price of hydrocarbons produced in the well in question and
utilized in the forecast shall be based on a 3% escalated average gas
price reflective of the most recent twelve month period, as quoted in the
first monthly publication of Inside FERC for Colorado Interstate Gas Co.-
Rocky
o:Rocky Mountains Index (or a mutually agreeable substitute index, if such
index is no longer published). The discount rate shall be the prime rate at
the Chase Manhattan Bank (or if such bank no longer exists, the United
States prime rate generally recognized in the financial media from time -
to -time) on the date which the market evaluation is made plus two (2)
percent. The LESSOR shall make such appraised fair market value
payment to LESSEE promptly upon completion of LESSEE's removal of
surface facilities and plugging of the well per Paragraph 18 (ii) of this
lease. LESSOR's right to require LESSEE to plug any or all well(s) is
irrevocable. This provision shall apply to each producing well which
LESSOR serves a Notice to Vacate on a well -by -well basis.
LESSEE understands and agrees that LESSOR shall be held harmless and shall not be
held liable or responsible, in any manner whatsoever, for any demands or causes of
action taken against LESSEE by any oil and gas purchaser or purchasers due to
LESSEE's inability to meet its contractual obligations with such purchaser or purchasers
as a result of LESSEE being required to shut in a producing well(s) on said land.
19. LESSEE shall pay all taxes levied upon or assessed against its improvements, fixtures
and personal property on said land, including LESSEE'S oil stored thereon. Taxes levied
upon or assessed against the minerals and mineral rights subject to this lease (or, if
same shall not be separately assessed, such part of the taxes on said land as are due to
the discovery of oil, gas or related hydrocarbons on said land or lands adjacent thereto)
shall be paid as follows: The royalty share thereof by all the persons entitled to share in
OIL & GAS LEASE.tloc - PAGE 7
1 1111111111111111111111111111 1111111111111111111111 1111
654127 06/14/2004 04:43P 81596 P538 M ALSDORF
_ 9 of 28 R 141.00 D 0.00 GARFIELD COUNTY CO
21. LESSOR at all times shall have free access to all wells on said land and to all records
pertaining thereto and the production therefrom. As to wells being drilled on said land
LESSEE agrees to:
a. Notify LESSOR of the beginning thereof;
b. Promptly furnish to LESSOR a copy of each report filed by LESSEE with any
governmental agency relating thereto;
c. Promptly furnish to LESSOR daily drilling and drilling time reports;
d. Promptly furnish to LESSOR complete information as to the results of all tests;
e. Upon completion of a well, promptly furnish to LESSOR one (1) copy of the
following logs:
*DIL-GR-CAL 2"&5" surface casing to TD
*BHC -SONIC -GR -CAL 2"&5" surface casing to TD
*CNL-LDT 2"&5" surface casing to TD
*A cement bond log to verify that there are no gaps of uncemented space
between the casing and the adjacent formation.
When running the above logs in the oil shale mining zone, the logging scale will
be expanded to one (1) inch equals twenty (20) feet. Lessee may use any scale it
chooses in the balance of the drill hole.
f. In addition to the logs mentioned in Paragraph 21e. above, promptly furnish to
LESSOR all electric, radioactive and other surveys thereof whether similar or
dissimilar;
g. Promptly furnish to LESSOR samples of drill cuttings taken at ten (10) foot
intervals over prospective horizons.
22. In the event any well drilled on said land is completed as a dry hole, LESSOR shall have
the opportunity to run any logs, surveys or tests it deems necessary, fit and proper
before the well is plugged and abandoned and/or take over the well at its sole risk and
expense. In the event LESSEE, at its discretion, makes a decision to plug and abandon
the test well as a dry hole, it shall give LESSOR at least two (2) days written notice, and
LESSOR shall receive such notice at least two (2) days prior to the scheduled date for
plugging and abandoning said test well. LESSOR shall also be allowed at least two (2)
days beyond the scheduled plugging and abandonment of the said test well to conduct
and acquire logs, surveys or tests it deems necessary, fit and proper. After conducting
such logging, surveying or testing, LESSOR shall have an additional two (2) days for
evaluation to determine whether or not to exercise its option of taking over the well at its
sole risk and expense. LESSOR shall reimburse LESSEE for all circulation costs
incurred after the initial two (2) days notice until LESSOR either releases the well for
plugging and abandonment or takes over the well.
All testing and evaluation conducted by LESSOR shall be at LESSOR's expense with
the exception of LESSEE's standby rig time for the first two (2) days after notification has
been received by LESSOR that LESSEE intends to plug and abandon the well. If
OIL & GAS LEASE.doc - PAGE 9
1 111111 11111 111111111 111111111111111111111 111111 111 1111
654127 06/14/2004 04:43P B1596 P540 11 ALSDORF
11 of 28 R 141.00 D 0.00 GARFIELD COUNTY CO
29. It is the intention of LESSOR to lease, and LESSOR does hereby lease all of its interest
in the acreage described in Paragraph 1 of this lease.
IN WITNESS WHEREOF, this instrument is executed effective as of the day and year first
above written.
LESSOR:
SHELL FRONTIER OIL & GAS INC.
P. O. Box 576
Houston, TX 77001
1 d
By:
LESSEE:
OXY USA�WTP LP / /
By: //dlOz�//
OIL & GAS LEASE.doo - PAGE 11
HMI 11111 111111 111 111111111111 111111 III 111111 III 1111
554127 06/14/2004 04:43P B1596 P542 M ALSDORF
13 of 28 R 141.00 D 0.00 GARFIELD COUNTY CO
EXHIBIT "A"
Attached to and made a part of that certain Oil and Gas Lease, by and between Shell Frontier
Oil & Gas Inc. and OXY USA WTP Limited Partnership, dated June 1, 2004.
Well Name:
RELINQUISHMENT OF ROYALTY INTEREST
AND
ASSIGNMENT. CONVEYANCE AND BILL OF SALE OF WORKING INTEREST
THIS INSTRUMENT (hereinafter called "ASSIGNMENT"), is made between SHELL
FRONTIER OIL & GAS INC., a Delaware corporation, having a post office address of P. O. Box
576, Houston, Texas 77001, hereinafter called "LESSOR," and OXY USA WTP LP, having an
address of 5 Greenway Plaza, Suite 110, Houston, TX 77046, hereinafter called "LESSEE."
This ASSIGNMENT is made in consideration of the mutual promises between LESSEE
and LESSOR and upon the following premises:
1. By that certain Oil and Gas Lease dated June 1, 2004, (hereinafter called the
"LEASE"), LESSOR, granted to LESSEE, certain oil and gas rights set forth in the LEASE,
recorded in Volume , at Page , of the Records of Garfield County, State
of Colorado.
2. The LEASE covered, among other lands, that certain land described in
Attachment "1" attached hereto and made a part hereof.
3. The LEASE provides, in Section 9, Option (b), that at payout of each well drilled
thereunder, LESSOR could elect to convert its royalty interest in the oil and gas in and under
and produced from such well to a thirty percent (30%) working interest in the same.
4. The well situated in the of
Garfield County, State of Colorado, has reached payout as provided in the LEASE. LESSOR
has, in accordance with the terms of the LEASE elected to convert its interest as specified
above.
NOW, THEREFORE, LESSOR hereby releases, assigns, transfers and conveys its
royalty interest in the oil and gas in under and produced from said well to LESSEE and LESSEE
simultaneously hereby grants, assigns, transfers and conveys to LESSOR its successors and
assigns, subject to the terms and conditions contained herein, the following interest:
a. An undivided thirty percent (30%) of LESSEE's right, title and interest in and to
the lands described in Attachment "1" as to the land and formations covered thereby, and oil
and gas production attributed to,
b. An undivided thirty percent (30%) interest in and to all permits, franchises,
licenses, servitudes, easements, surface leases and rights-of-way, of every character, relating
to the land described in Attachment "1,"
OIL & GAS LEASE.doc — PAGE 13
1111111 111 111111111111 111111III 111111 111 1111
654127 06/14/2004 04:43P 81596 P544 M RLSDORF
15 of 28 R 141.00 D 0.00 GARFIELD COUNTY CO
STATE OF TEXAS )
)ss:
COUNTY OF HARRIS )
The foregoing instrument was acknowledged before me this day of , 200_,
by
, Attorney -in -Fact of Shell
Frontier Oil & Gas Inc., a corporation, on behalf of the corporation.
STATE OF TEXAS
COUNTY OF HARRIS
)ss:
Notary Public, Harris County, Texas
The foregoing instrument was acknowledged before me this day of , 200_,
by
As attorney in fact for OXY USA Inc. as General
partner for OXY USA WTP LP
OIL & GAS LEASE.doc — PAGE 15
Notary Public, Harris County, Texas
1 111111 11111 111111 11111111 1111 111111 111 111111 111 1111
Exhibit "B" 6M127 06/14/2004 04:43P B1596 P546 M RLSDORF Page 2
Instructions for Completion 17 of 28 R 141.00 D 0.00 GARFIELD COUNTY CO
Of Operating Agreement.
1. PRIORITY OF ELECTIONS Where a well has been authorized under the terms
of this agreement by all parties (or by one or more, but less than all
parties under Article VI.B.2.) and has been drilled to the Objective Depth
or the Objective Formation, whichever is deepest, and the parties
participating in the well cannot agree upon the sequence and timing of
further operations regarding such well, the following elections shall
control in the order enumerated below:
A. An election to do additional logging, coring or testing.
B. An election to attempt to complete the well at either
the Objective Depth or Objective Formation.
C. An election to deepen said well.
D. An election to plug back and attempt to complete said
well.
E. An election to sidetrack the well.
However, if at any time said participating parties are considering the
above elections, the hole is in such a condition that in the opinion of
the participating working interest owners, who owns a majority interest
(based upon working interest ownership as shown on Exhibit "A" after
excluding any non -participating working interest, a reasonable prudent
operator would not conduct the operations contemplated by the particular
election involved for fear of placing the hole in jeopardy or losing the
same prior to completing the well in the Objective Depth or Objective
Formation, such election shall not be given the priority set forth above.
In such event, the operation which, in the opinion of a majority of the
participating working interest owners, is less likely to jeopardize the
well will be conducted. It is further understood that if some, but not
all parties, elect to participate in the additional logging, coring or
testing they may do so and the party or parties not participating in such
operations shall not be entitled to the logs, cores or the results of the
tests but shall suffer no other penalty.
It is agreed by the parties hereto that when any well provided for in this
Agreement is drilling or testing, no party shall propose the drilling of
an additional well on the contract acreage unless the drilling of a well
is necessary to perpetuate the Lease or for some other reason it is
mutually agreed by the parties hereto that an additional well should be
drilled prior to the completion of a well on the contract acreage.
2. STATEMENT OF POLICY: With respect to the conduct of operations in the
Contract Area, the parties to this Agreement state that they share a
commitment to the protection of the health and safety of the people
working in the Contract Area and to the protection of the environment. In
accordance with this commitment, the Operator shall, with the support and
cooperation of the non-operating parties, work to develop a Health Safety
and Environmental ("HSE") Management System and Policies that will
effectively implement the following elements in the conduct of operations
hereunder:
(a) A systematic approach to HSE management designed to ensure
compliance with the law and to achieve continuous performance
Exhibit "B"
Instructions for Completion
Of Operating Agreement.
1 111111 11111 11111 111 11111111 1111 111111 111 111111 111 1111
654127 06/14/2004 04:43P 81596 P548 M ALSDORF
19 of 28 R 141.00 D 0.00 GARFIELD COUNTY CO
3. Section III, Paragraph 1. Overhead -Drilling and Producing Operations:
(i) Select: "Fixed Rates Basis, Paragraph IA"
(ii) Select: "shall not be covered by the overhead rates."
(iii) Select: "shall not be covered by the overhead rates"
A. Overhead -Fixed Rate Basis
Drilling Producing
Well Rate Well Rate
$6,500.00 $650.00
4. Section III, Paragraph 2. Overhead -Major Construction
Line 4 - $25,000
A-5%
B-3%
C-2%
5. Section III, Paragraph 3. Catastrophe Overhead
A-5%
B-3%
C-2%
22. Exhibit "D" - Insurance - Use the following for Exhibit "D".
Insurance
Page 4
The Farmee shall provide for Workmen's Compensation coverage in accordance with the law of
the State where operations are being conducted. No other insurance shall be provided by the Farmee for the
benefit of the parties hereto.
23. Exhibit "E" - Gas Storage and Balancing Agreement - Use the following for Exhibit "E".
EXHIBIT "E"
GAS BALANCING AGREEMENT ("AGREEMENT")
ATTACHED TO AND MADE PART OF THAT CERTAIN
OPERATING AGREEMENT DATED
BY AND BETWEEN , AND
Exhibit "B"
Instructions for Completion
Of Operating Agreement.
11!!1111!1111!111! 111 11111!!1111! 111111 111 1111111 !11!!1 Page 6
654127 06/14/2004 04:43P 81596 P550 M RLSDORF
21 of 28 R 141.00 D 0.00 GRRFIELD COUNTY CO
Gas produced from the Balancing Area.
1.10 "Overproduction" shall mean the cumulative quantity of Gas taken by a Party in excess of its
Percentage Interest in the cumulative quantity of all Gas produced from the Balancing Area.
1.1 1 "Party" shall mean those individuals or entities subject to this Agreement, and their respective
heirs, successors, transferees and assigns.
1.12 "Percentage Interest" shall mean the percentage or decimal interest of each Party in the Gas
produced from the Balancing Area pursuant to the Operating Agreement covering the
Balancing Area. For the purposes of applying the Oklahoma Production Revenue Standards
Act hereto the terms "Percentage Interest", "Proportionate Production Interest, and "Working
Interest Share of Production" shall be considered equivalent terms.
1.13 "Royalty" shall mean payments on production of Gas from the Balancing Area to all owners
of royalties, overriding royalties, production payments or similar interests.
1.14 "Underproduced Party" shall mean any Party having taken a lesser quantity of Gas from the
Balancing Area than the Percentage Interest of such Party in the cumulative quantity of all
Gas produced from the Balancing Area.
1.15 "Underproduction" shall mean the deficiency between the cumulative quantity of Gas taken
by a Party and its Percentage Interest in the cumulative quantity of all Gas produced from the
Balancing Area.
1.16 "Winter Period" shall mean the months of November, December, January and February.
2. BALANCING AREA
2.1 If this Agreement covers more than one Balancing Area, it shall be applied as
if each Balancing Area were covered by separate but identical agreements. All balancing
hereunder shall be on the basis of Gas taken from the Balancing Area measured in MMBtus.
2.2 In the event that all or part of the Gas deliverable from a Balancing Area is or
becomes subject to one or more maximum lawful prices, any Gas not subject to price controls
shall be considered as produced from a single Balancing Area and Gas subject to each
maximum lawful price category shall be considered produced from a separate Balancing
Area.
3. RIGHT OF PARTIES TO TAKE GAS
3.1 Each Party desiring to take Gas will notify the Operator, or cause the
Operator to be notified of the volumes nominated, the name of the transporting pipeline and
the pipeline contract number (if available) and meter station relating to such delivery,
sufficiently in advance for the Operator, acting with reasonable diligence, to meet all
nomination and other requirements. Operator is authorized to deliver the volumes so
nominated and confirmed (if confirmation is required) to the transporting pipeline in
accordance with the terms of this Agreement.
Exhibit "B"
Instructions for Completion
Of Operating Agreement.
111111 11111 111111 111 111111111111111111 III 1111111111111
654127 06/14/2004 04:43P B1596 P552 M PLSDORF
23 of 28 R 141.00 D 0.00 GRRFIELD COUNTY CO
Page 8
4.1 Effective the first day of any calendar month following at least thirty (30)
days' prior written notice to the Operator, any Underproduced Party may begin taking, in
addition to its Full Share of Current Production and any Makeup Gas taken pursuant to
Section 3.3 of this Agreement, a share of current production determined by multiplying fifty
percent (50%) of the Full Shares of Current Production of all Overproduced Parties by a
fraction, the numerator of which is the Percentage Interest of such Underproduced Party and
the denominator of which is the total of the Percentage Interests of all Underproduced Parties
desiring to take Makeup Gas. In no event will an Overproduced Party be required to provide
more than fifty percent (50%) of its Full Share of Current Production for Makeup Gas. The
Operator will promptly notify all Overproduced Parties of the election of an Underproduced
Party to begin taking Makeup Gas.
4.2 Notwithstanding the provisions of Section 4.1, no Overproduced Party will
be required to provide more than twelve and one half percent (12.5%) of its Full Share of
Current Production for Makeup Gas during the Winter Period.
4.3 Notwithstanding anything herein to the contrary no Underproduced Party which
is a Non -Consenting Party under the Operating Agreement and is not then entitled to
participate in any operation regarding a Balancing Area shall be entitled to take gas from said
Balancing Area for which it is a Non -Consenting Party.
5. STATEMENT OF GAS BALANCES
5.1 The Operator will maintain appropriate accounting on a monthly and
cumulative basis of the volumes of Gas that each Party is entitled to receive and the volumes
of Gas actually taken or sold for each Party's account. Within forty-five (45) days after the
month of production, the Operator will furnish a statement for such month showing (1) each
Party's Full Share of Current Production, (2) the total volume of Gas actually taken or sold
for each Party's account, (3) the difference between the volume taken by each Party and that
Party's Full Share of Current Production, (4) the Overproduction or Underproduction of each
Party, and (5) other data as recommended by the provisions of the Council of Petroleum
Accountants Societies Bulletin No. 24, as amended or supplemented hereafter. Each Party
taking Gas will promptly provide to the Operator any data required by the Operator for
preparation of the statements required hereunder.
5.2 If any Party fails to provide the data required herein for four (4) consecutive
production months, the Operator, or where the Operator has failed to provide data, another
Party, may audit the production and Gas sales and transportation volumes of the non -
reporting Party to provide the required data. Such audit shall be conducted only after
reasonable notice and during normal business hours in the office of the Party whose records
are being audited. All costs associated with such audit will be charged to the account of the
Party failing to provide the required data.
6. PAYMENTS ON PRODUCTION
6.1 Each Party taking Gas shall pay or cause to be paid all production and
severance taxes due on all volumes of Gas actually taken by such Party.
Exhibit "B"
Instructions for Completion
Of Operating Agreement.
11111111111111111 111 11111111 1111 111111III 1111111 II III►
654127 06/14/2004 04:43P 81596 P554 M ALSDORF
25 of 28 R 141.00 D 0.00 GARFIELD COUNTY CO
Page 10
both the liquid hydrocarbons (including liquifiable hydrocarbons) and the residue gas
attributable to the Overproduction.
7.5.2 For Overproduction processed for the account of the Overproduced Party at a
gas processing plant for the extraction of liquid hydrocarbons, where settlement for the gas so
processed was on a basis other than percentage of the proceeds, the values used for
calculating cash settlement will include the proceeds received by the Overproduced Party for
the sale of the liquid hydrocarbons extracted from the Overproduction, less the actual
reasonable costs incurred by the Overproduced Party to process the Overproduction and to
transport, fractionate and handle the liquid hydrocarbons extracted therefrom prior to sale.
7.6 To the extent the Overproduced Party did not sell all Overproduction under
an Arm's Length Agreement, the cash settlement will be based on the weighted average price
received by the Overproduced Party for any gas sold from the Balancing Area under Arm's
Length Agreements during the months to which such Overproduction is attributed. In the
event that no sates under Arm's Length Agreements were made during any such month, the
cash settlement for such month will be based on the spot sales prices published for the
applicable geographic area during such month in a mutually acceptable pricing bulletin.
7.7 Interest compounded at the maximum lawful rate of interest applicable to the
Balancing Area will accrue for all amounts due under Section 7.1, beginning the first day
following the date payment is due pursuant to Section 7.3. Such interest shall be borne by the
Operator or any Overproduced Party in the proportion that their respective delays beyond the
deadlines set out in Section 7.2 and 7.3 contributed to the accrual of the interest.
7.8 In lieu of the cash settlement required by Section 7.3, an Overproduced Party
may deliver to the Underproduced Party an offer to settle its Overproduction in-kind and at
such rates, quantities, times and sources as may be agreed upon by the Underproduced Party.
If the Parties are unable to agree upon the manner in which such in-kind settlement gas will
be furnished within sixty (60) days after the Overproduced Party's offer to settle in kind,
which period may be extended by agreement of said Parties, the Overproduced Party shall
make a cash settlement as provided in Section 7.3 The making of an in-kind settlement offer
under this Section 7.8 will not delay the accrual of interest on the cash settlement should the
Parties fail to reach agreement on an in-kind settlement.
7.9 That portion of any monies collected by an Overproduced Party for
Overproduction which is subject to refund by orders of the Federal Energy Regulatory
Commission or other governmental authority may be withheld by the Overproduced Party
until such prices are finally approved by such governmental authority, unless the
Underproduced Party furnishes a corporate undertaking, acceptable to the Overproduced
Party, agreeing to hold the Overproduced Party harmless from financial loss due to refund
orders by such governmental authority.
8. TESTING
Notwithstanding any provision of this Agreement to the contrary, any Party shall
have the right, from time to time, to produce and take up to one hundred percent (100%) of a
well's entire Gas stream to meet the reasonable deliverability test(s) required by such Party's
Gas purchaser, and the right to take any Makeup Gas shall be subordinate to the right of any
Exhibit "B"
Instructions for Completion
Of Operating Agreement.
11111111111 HI HMI 1111111/ III 1111111 11 It
654127 06/14/2004 04:43P B1596 P556 M ALSDORF
27 of 28 R 141.00 D 0.00 GARFIELD COUNTY CO
other Parties harmless from all judgements or damages sustained and costs incurred in
connection therewith.
Page 12
12.3 Except as otherwise provided in this Agreement, Operator is authorized to
administer the provisions of this Agreement, but shall have no liability to the other Parties for
losses sustained or liability incurred which arise out of or in connection with the performance
of Operator's duties hereunder, except such as may result from Operator's gross negligence or
willful misconduct. Operator shall not be liable to any Underproduced Party for the failure of
any Overproduced Party (other than Operator) to pay any amounts owed pursuant to the
terms hereof.
12.4 This Agreement shall remain in full force and effect for as long as the
Operating Agreement shall remain in force and effect as to the Balancing Area, and thereafter
until the Gas accounts between the Parties are settled in full, and shall inure to the benefit of
and be binding upon the Parties hereto, and their respective heirs, successors, legal
representatives and assigns, if any. The Parties hereto agree to give notice of the existence of'
this Agreement to any successor in interest of any such Party and to provide that any such
successor shall be bound by this Agreement, and shall further make any transfer of any
interest subject to the Operating Agreement, or any part thereof, also subject to the terms of
this Agreement.
12.5 Unless the context clearly indicates otherwise, words used in the singular
include the plural, the plural includes the singular, and the neuter gender includes the
masculine and the feminine.
12.6 This Agreement shall bind the Parties in accordance with the provisions
hereof, and nothing herein shall be construed or interpreted as creating any rights in any
person or entity not a signatory hereto, or as being a stipulation in favor of any such person or
entity.
12.7 If contemporaneously with this Agreement becoming effective, or thereafter,
any Party requests that any other Party execute an appropriate memorandum or notice of this
Agreement in order to give third parties notice of record of same and submits same for
execution in recordable form, such memorandum or notice shall be duly executed by the
Party to which such request is made and delivered promptly thereafter to the Party making the
request. Upon receipt, the Party making the request shall cause the memorandum or notice to
be duly recorded in the appropriate real property or other records affecting the Balancing
Area.
12.8 With respect to accounting treatment of any gas imbalances as may exist, the
parties agree to use the "cumulative method" [as defined in Income Tax Regulation' 1.761-2
(d) (4)] of accounting for federal income tax purposes. The "entitlements method" shall not
be used for reporting gas sales from the properties subject hereto.
13. ASSIGNMENT AND RIGHTS UPON ASSIGNMENT
13.1 Subject to the provisions of Section 13.2 hereof, and notwithstanding
anything in this Agreement or in the Operating Agreement to the contrary, if any Party
assigns (including any sale, exchange or other transfer) any of its working interest in the
OXY USA WTP LP
Shell 797 to Conn Creek Compressor Station Pipeline
Existing within ROW:
Sections 8 and 9, Township 7 South Range 97 West
-Gas Gathering Pipeline
-Water Gathering Pipeline
Section 5, Township 7 South Range 97 West & Section 32, Township 6 South Range 97 West
-Water Distribution Pipeline
- Poly Communication Line
-Gas Gathering Pipeline
-Condensate Gathering Pipeline
Proposed:
-Shell to CC1 6 -inch Steel Pipeline
Purpose and Need
The Shell CC1 pipeline will transfer natural gas from the extraction well pad to the Conn Creek
Compressor Station for compression. The proposed site is located on OXY's property and within
the Cascade Creek field. The proposed Shell CC1 Pipeline is essential for transferring natural gas
from a producing COGCC permitted well pad.
Location
The proposed Shell 797 to CC1 Pipeline site plan is designed to be approximately 16.6 acres and
will be southerly located on parcels 2169-214-00-026 (OXY USA INC), 2411-082-00-019 (Savage
Limited Partnerships), 2411-082-00-011 (JOJO Properties), 2411-101-00-015(Shell Frontier Oil
and Gas) in Section 32 of Township 6 South, Range 97 West, Section 5, 8, and 9 of Township 5
South, Range 97 West of the 6th Principal Meridian, Garfield County. The applicant is the owner of
the surface property and mineral rights for parcel 2169-214-00-026, OXY USA Inc. The parcel is
7,732 acres and is zoned Resource Lands.
Savage Limited Partnerships (Savage) is the owner of the surface property for parcel 2411-082-00-
019. The parcel is 7.07 acres and is zoned Resources Lands. JOJO Properties is the owner of the
surface property for parcel 2411-082-00-011. The parcel is 100 acres and is zoned Resource Lands.
Savage is the representative of JOJO Properties. Surface Use Agreement (SUA), Authorization, and
ownership documents are located in the Grading Application. The Garfield County Clerk and
Recorders list contact information for the parcel owner as:
SAVAGE LIMITED PARTNERS AND JOJO PROPERTIES
PO BOX 1926
RIFLE, CO 81650
Shell Frontier Oil and Gas is the owner of the surface property and mineral rights for parcel 2411-
101-00-015. Surface Use Agreement (SUA), Authorization, and ownership documents are located in
the Grading Application. The Garfield County Clerk and Recorders list contact information for the
parcel owner as:
SHELL FRONTIER OIL & GAS INC - SHELL OIL COMPANY
PO BOX 4854
HOUSTON, TX, 77010
Major Grading Permit Application Narrative
Garfield County Major Grading Permit Application, 2014 Page 2 o
OXY USA WTP LP
Shell 797 to Conn Creek Compressor Station Pipeline
All adjacent parcels are zoned resource lands or public lands. Parcel ownership and boundaries are
detailed in the Parcel Boundary Map, located in the Grading Application.
Major Grading Permit Application Narrative
Garfield County Major Grading Permit Application, 2014 Page 3 0
OXY USA WTP LP
Shell 797 to Conn Creek Compressor Station Pipeline
Major Grading Permit
Required Documents
Vicinity Map
A Vicinity Map is located in the Grading Application.
Site Plan
A Site Plan is provided on a 24 X 36 inch sheet.
Erosion Control Plan
Erosion controls are described in the Reclamation and Erosion Control Plan. Erosion Control figures
are located in the Reclamation and Erosion Control Plan and are provided on 24 X 36 sheets.
$evegetation and Reclamation Plan
The revegetation and reclamation plans are detailed in the Weed Management Plan document,
located in the Reclamation and Erosion Control Plan.
Approved State Stormwater Permit
The stormwater permit and extension letter are located in the Reclamation and Erosion Control
Plan. Stormwater management plan is located in the Grading Application.
Soils Report
The Soils Report is not required for the subject application. The depth of cut is less than 15 feet and
the native slopes are less than 25%.
Drainage Report
The Drainage features are shown in the Drainage Report, Site Plan and in the Reclamation and
Erosion Control Plan. Drainage patterns will not be altered in the existing ROW. The subject
pipeline is not within a floodplain and native slopes are less than 25%. The subject pipeline will not
impact adjacent properties drainage.
Major Grading Permit Application Narrative
Garfield County Major Grading Permit Application, 2014 Page 4 o
OXY USA WTP LP
Shell 797 to Conn Creek Compressor Station Pipeline
Shell 797 to Conn Creek Compressor Station Pipeline
OXY USA WTP LP
Major Grading Permit Application Narrative
OXY USA WTP LP (OXY) is pursuing a Major Grading Permit for the Shell 797 to Conn Creek
Compressor Station (CC1) Pipeline (Shell CC1 Pipeline) in Garfield County. Approximately 14,457
stare feet will be graded within an existing ROW. The proposed site is located on 4 se arate
private parcels approximately 10 miles north of DeBeque, Colorado. The pipeline will notrequire a
land use change permit. The pipeline's main function will be to transfer natural gas from the well to
the compressor station facility for processing prior to sale.
1.1 Description
The site location is a previously developed 50 -foot wide right-of-way (ROW) for existing pipelines.
The location of the existing pipelines is detailed in the Pipeline Layout figure, located in the Grading
Application. The proposed site will have a disturbance area of 16.6 acres within an existing ROW
and 722,850 square feet. An access road to the site location is maintained by OXY.
The Shell CC1 pipeline will transfer natural gas from the Shell 797 well pad (COGCC permitted) to
the Conn Creek Compressor Station (Garfield County Permitted- Resolution #2005-88). Natural gas
will be extracted from the active well and sent to the CC1 for compression. Pressure for transferring
natural gas through the pipeline will be provided from the subject well, defined as production field
pressure.
The Shell CC1 Pipeline will be approximately 14,457 feet long and 16.6 acres of disturbance. The
maximum capacity for the subject pipeline is 10 million cfs/day (gas volume) and will decline over
the life of the producing well. The pipeline will be buried at a depth of 6 feet below grade, with a
maximum depth up to 10 feet below grade at crossings. Crossings are identified in the Site Plan,
located in the Major Grading Application. The trench will be constructed with an excavator and
require a trench of 3 feet wide for placement. The pipeline will be constructed with 6 -inch pipe and
is composed of carbon steel (14-16 grade). The seamless beveled drill pipe conforms to the API
standards for buried pipe and is manufactured by Tenaris. The pipe is coated with a three -layer
system and an external coating for corrosive resistance. The maximum operating temperature is
150°F with a pressure of 1,440 PSI. The pipe has a wall thickness of 7.1 millimeters. The pipe
weighs 18.99 pounds per foot. The construction phase will be approximately 2ldays for the site
grading and installation of the CC1 Pipeline.
The subject pipeline will require a depth of cut less than 15 feet and the native slopes are less than
25%. Drainage patterns will not be altered in the existing ROW. The subject pipeline is not within a
floodplain and will not impact adjacent properties drainage. Drainage and erosion features are
detailed in the Site Plan and Reclamation and Erosion Control Plan. Grading documents are located
in the Grading Application.
A Weed Inventory was conducted on September 24, 2014, by ERO Resources Corporation (ERO).
The report details weeds identified and mitigation recommendations. The weed inventory is
located in the Grading Application. The Weed Management and Reclamation Plan are located in the
Grading Application.
Facilities and Equipment Summary
The following section summarizes the structures and equipment that are currently existing and
proposed for the subject site.
Major Grading Permit Application Narrative
Garfield County Major Grading Permit Application, 2014
Page 1
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OXY USA, WTP LP
PROPOSED SHELL
797-09A TO CCI PIPELINE
GRADING PLAN
PLAN AIVD PROFILE
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8481431130214
RECLAMATION AND EROSION CONTROL PLAN
SHELL 797-09A TO CC1 COMP. PIPELINE
GARFIELD COUNTY, COLORADO
PREPARED FOR:
OXY USA WTP LP
760 HORIZON DRIVE, SUITE 101
GRAND JUNCTION, CO 81505
PH: (970) 263-3668
PREPARED BY:
OLSSON ASSOCIATES
CONTACT: WYATT E. POPP, PE
OCTOBER 9, 2014
OLSSON ASSOCIATES
PROJECT No. 014-2066
O\OLSSON
ASSOCIATES
760 horizon Drive, Suite 102 1 Grand Junction, CO 81506 1 970.263.7800 1 Fax 970.263.7456
TABLE OF CONTENTS
1. RECLAMATION PLAN
a. Top Soil Management
b. Seeding Procedures and Schedules
c. Disturbance Area
d. Cost Estimate
2. DRAINAGE AND EROSION CONTROL PLAN
a. Drainage
b. Erosion Control Measures
LIST OF ATTACHMENTS
Attachment A Top Soil Salvage
Attachment B Regional Drainage Analysis
Attachment C Proposed Erosion Control Figures
Attachment D Weed Management Plan
Attachment E Cascade Creek Stormwater Permit COR -038414
Reclamation Plan
Oxy has proposed a pipeline corridor consisting of (1) 6 -inch pipeline, the Shell 797-09A to CC1
Comp. pipeline. Revegetation activities are anticipated to take no longer than forty (40) days.
Upon completion of the installation, the pipeline trench will be backfilled, topsoil replaced on the
entire right-of-way and re -graded as closely as possible to pre -disturbance conditions. The
entire right-of-way will be reseeded by drilling the following seed mixtures:
Approved Seed Mix provided by ERO Resources Corporation
Common Name
Scientific Names
Form
PLS
lbs/acre
Bluebunch Wheatgrass
Pseudoroegneria spicata, Agropyron
spicatum
Bunch
19.28
Shadscale saltbush
Atriplex confertifolia
Shrub
18.51
Fourwing saltbush
Atriplex canescens
Shrub
18.42
Streambank wheatgrass
Elymus lanceolatus ssp. psammophilus,
Agropyron riparium
Sod-
forming
17.23
Indian ricegrass
Achnatherum hymenoides
Bunch
14.87
Galleta grass
Pleuraphis [Hilaria] jamesii
Bunch
6.77
Alkali sacaton
Sporobolus airoides
Bunch
0.63
Top Soil Managment
Topsoil will be stockpiled so that it will not interfere with construction activities or cause potential
environmental problems. Should the construction phase of this project exceed forty (40) days,
appropriate measures will be taken to protect all topsoil stockpiles (covering, seeding,
windbreaks, etc.).
Following final contouring, all backfilled surfaces will be covered evenly with the stockpiled
topsoil. The topsoil will be heavily pocked using the excavator bucket to form an uneven soil
surface complex which will aid in revegetation. Soil amendments or import of new topsoil is not
anticipated. Review of the vegetation establishment will be required to determine whether soil
amendments are required at a later date. (Attachment A).
Seeding Procedures and Schedules
As recommended by ERO Resources seeding shall be applied as soon as possible following
surface grading. The reseeding rate should be doubled for broadcast application. Oxy's
contractor will utilize surface roughing to create microclimates conducive to seed establishment
and growth. It is anticipated that the disturbed areas will be returned to match the original
vegetative state.
1
Seeding will be conducted by means of drilling the prescribed seed mix according to the
recommended rate. The seed will be drilled with a common range drill at a depth of 0.25 — 0.5
inch beneath the soil surface. The reseeding will be monitored and reseeded as appropriate
until the reclamation standards are acceptable to Garfield County Vegetation Management.
Disturbance area
The project has an anticipated total disturbance of approximately 16.6 acre. (722,850 square
feet)
Engineer's Opinion of Probable Cost
Below is a table that outlines the estimated costs associated with the revegetation of the project.
The estimate is an opinion of probable cost and may vary based upon site conditions
encountered or market conditions related to the unit cost.
O‘OLSSON
ASSOCIATES
Olsson Associates
760 Horizon Drive, Suite 102
Grand Junction, CO 81506
REVEGETATION COST SUMMARY
PROJECT: Shell 797-09A to CC1
LOCATION: Garfield County, CO
DATE: 10/08/14
Item Description (Source of Cost) Cost/ Acre
Garfield County Vegetation
Management $2,500
Total Acres 16.6
Estimated Total Cost $41,500
(costs have been provided by Garfield
County Vegetation Management)
2
Drainage and Erosion Control Plan
The primary disturbance anticipated with the construction of this project is soil stockpile. Topsoil
will be stockpiled so that it will not interfere with construction activities or cause potential
environmental problems. Should the construction phase of this project exceed forty (40) days,
appropriate measures will be taken to protect all topsoil stockpiles (covering, seeding,
windbreaks, etc.). The construction of the project is anticipated to return the grades to pre -
construction elevations as closely as possible. The construction plans prepared by D.R. Griffin
and Associates, Inc illustrate the anticipated grades.
Drainage
Nolte Associates prepared the Regional Drainage Analysis. The proposed pipeline route
associated with this project is located within the CONO3, CONO2, and BAK01 drainage basins
as described within the Regional Drainage Analysis. This project is not anticipated to alter the
drainage patterns or flow rates described within the Regional Drainage Analysis. It is expected
that existing drainage measures will be maintained. Deviation from the Regional Drainage
Analysis is not expected, however, if site conditions dictate a deviation then a Colorado
Registered Professional Engineer shall be consulted. The Regional Drainage Analysis
prepared by Nolte Associates demonstrating drainage patterns for the project area is included
as Attachment B.
Erosion Control Measures
Olsson Associates prepared a Stormwater Management Plan for Cascade Creek Development.
It is anticipated that the project will be in conformance with the Stormwater Management Plan
(permit no. COR038414). The Stormwater Management Plan will be revised accordingly. An
exhibit demonstrating approximate locations of anticipated erosion control measures is included
as Attachment C.
The recommendations associated with the Reclamation Plan and review of the Drainage and
Erosion Control Plan .ared on behalf of Olsson Associates under the supervision of:
A GIS
••,V •/
.y
:rt
tolali;
son*
Wyatt E. Po
Olsson Ass
3
'14\
OXY
\al,/
Noxious Weed Management Plan
for
Cascade Creek Operating Area
Mesa
Valley
Logan Wash
OXY USA WTP LP
760 Horizon Drive, Suite 101
Grand Junction, Colorado 81506
Updated March 2013
Table of Contents
Section Page
Introduction 2
Compliance Statements 2
Local Contacts 3
Operating Area 3
Land Use Objectives 3
Weed Management Objectives & Implementation Strategies 4
Inventory and Monitoring 4
Prevention 5
Construction Prevention Measures 5
Operations Prevention Measures 5
Revegetation 5
Control and Management 6
Local, State, and Federal Contacts and Resources 9
Appendices
Appendix A — Colorado Noxious Weed List
Appendix B — Example Excel Spreadsheet Components
Appendix B — Example Tables for Pesticide Reporting
Appendix C — Oxy Tracking Forms for Cascade Creek
Appendix D — Sample Revegetation and Reclamation Plan
Appendix E — Noxious Weed Management Protocols for Areas within the State
Natural Areas
Cascade Creek Noxious Weed Management Plan Page 1
Noxious Weed Management Plan for
OXY USA WTP LP
Cascade Creek Operations
Garfield County, Colorado
Introduction
OXY USA WTP LP ("Oxy") has developed this Noxious Weed Management Plan (Plan) to comply
with the Colorado Noxious Weed Act (C.R.S. Title 35, Article 5.5) ("Act"), Colorado Oil and Gas
Conservation Act, local, and federal noxious weed management requirements, such as Garfield
County Planning Department and the Bureau of Land Management (BLM). The Plan also covers
special best management practices (BMP's) for management of noxious weeds in two designated
State Natural Areas (SNA's) located on Oxy property.
The Act requires that "noxious weeds" be managed on private and public lands. The Act further
declares that control of noxious weeds should use methods that are least damaging to the
environment but also practicable and economically reasonable. The state requires management
of noxious weeds included on one of three lists (see Appendix A): List A — designated for
statewide eradication; List B — managed to prevent further spread and, for selected species,
designated for eradication in large areas; and List C — of more localized concern, but for which
the state will provide education, research, and biological control assistance to jurisdictions that
choose to manage the species.
Oxy owns/leases and operates certain mineral properties in the Piceance basin, located in
Western Colorado. This Plan is intended to manage Oxy's oil and gas operational areas in order
to comply with all local, state and federal noxious weed management requirements including
Garfield County, Colorado Oil and Gas Conservation Commission (COGCC), and the BLM.
Compliance Statements
Oxy will manage all noxious weeds, as defined by the Act, the guidelines in the Garfield County
Noxious Weed Management Plan, the local BLM Pesticide Use Plan (PUP), any other approved
noxious weed management conditions of approval (COA's) issued by a land management agency
in existing surface disturbed areas managed by Oxy as well as newly disturbed project areas.
Some noxious weed management COA's may be identified by a biological consultant at the time
of project specific inventories. The term, "disturbed area" includes all well pads, access roads,
easements, pipelines, and associated support facilities such as compressor stations, water
management facilities, and other areas disturbed by project activities. Disturbed areas also
include soil stockpiles, earthen berms and other erosion control BMP's that require ground
disturbance for installation and maintenance. Oxy will comply with COGCC noxious weed
management 1000 Series rules, which requires Oxy to keep all disturbed areas free of noxious
weeds.
Cascade Creek Noxious Weed Management Plan Page 2
Oxy will report all State List A and List B noxious weed populations inventoried and treated and
any other species identified by Garfield County for eradication upon discovery to the appropriate
County designee.
The Colorado Natural Areas Program (CNAP), which manages the designated SNA's have
provided Oxy with recommended noxious weed management BMP's that will aide in protecting
native plant species. The recommended BMP's will be applied where feasible.
Local Contacts
The local contact for Oxy's Plan include the Regulatory Advisor, who serves as Oxy's noxious
weed management coordinator and manages the noxious weed contractors.
- Regulatory Advisor — Daniel I. Padilla, 970,263.3637
Garfield County's Vegetation Management contact number is 970.625.8601. Addition contact
information is listed in local contacts section of the Plan.
Operating Area
Oxy manages active and inactive leases associated with natural gas exploration in the following
areas of Garfield County:
• Cascade Creek Operating Area, which is separated into three primary fields:
o Valley
o Mesa
o Logan Wash; this area contains two SNA's:
• Mount Callahan SNA
• Mount Callahan Saddle SNA
Oxy operates on split estate, where surface lands may be wholly federal (BLM) and minerals
wholly fee owned and vice versa.
Land Use Objectives
Oxy conducts natural gas exploration and production activities on fee and federal lease holdings
in Western Colorado. Land uses and types of facilities to be developed include access roads,
pipelines, well pads, compressor stations, staging/storage areas for equipment and supplies, and
other associated natural gas development activities. Some of the developments are short-term
temporary disturbances, such as staging areas and pipelines, while the access roads, well pads,
and other support facilities remain in active use for an estimated 20-30 years.
Cascade Creek Noxious Weed Management Plan Page 3
Weed Management Objectives and Implementation Strategies
The following are the overall objectives of the Plan:
• Inventory and monitor existing or new noxious weed infestations using Global Positioning
System (GPS) equipment or other mapping techniques. Inventories shall occur at least
annually;
• Prevent new infestations of noxious weeds;
• Utilize state certified contractors to implement an Integrated Weed Management (IWM)
protocol as recommended by the state or Garfield County Noxious Weed Management
plan to control or manage noxious weed populations;
• Maintain a noxious weed inventory, herbicide application and mapping records;
• Restore disturbed areas to protect native plant ecosystems and watersheds
degradation by noxious weeds.
from
Specific actions to be taken to meet these objectives include:
• Bareground treatments will occur at existing facilities at the start of the spring season,
prior to noxious weed emergence to reduce the emergence potential of noxious weeds.
• Annual monitoring will occur at existing and new facilities, specifically looking for noxious
weeds. If noxious weeds are identified, they will be mapped, treated, and the treatment
event will be logged.
• All treatment events will be logged by the noxious weed treating contractor using a
Pesticide Application Record (PAR). See Appendix B for an example of what information
should be collected; the contractor may choose their own format. The PAR will be use to
report noxious weed management activities to federal land managing agencies. In
addition to completing the PAR, the noxious weed contractor will complete Oxy's noxious
weed tracking form, see Appendix C.
• Completion of the PAR and Oxy's tracking form will serve as documentation of noxious
weed management activities.
• Where feasible implement area specific noxious weed management BMP's in the two
designated state management areas, see Appendix E.
Inventory and Monitoring
Before a new site is developed and when practical, Oxy will inventory the site and adjacent areas
for noxious weeds, including access roads and other probable weed ingress routes. If
development activities are started in the winter months or when noxious weeds cannot be
identified, the new disturbance area will be inventoried the next growing season. Noxious weed
locations (List A and List B species) will be collected with a GPS unit or mapped in relation to the
facility or landmark. Any noxious weed infestations found will be treated before site disturbance,
if timing is appropriate. If the timing is not appropriate for noxious weed treatment, activities may
proceed and the weeds will be monitored and treated during the appropriate season. Weeds on
adjacent properties may be treated as appropriate with permission of the landowner. Populations
of Colorado or County List A and List B species (see Appendix A) will be reported to the County
Weed Manager. On federal lands or for federal projects, a Noxious Weed Inventory record will be
Cascade Creek Noxious Weed Management Plan Page 4
completed each time a List A or B weed infestation is inventoried (with the exception of redstem
filaree and quackgrass), and the populations will be reported.
Monitoring will be conducted at least annually, early in the growing season, by Oxy staff or
contractors, and in coordination with BLM staff on federal lands. For most of Oxy's operation
areas, monitoring will occur between May and July. All previously treated noxious weed sites will
be monitored for regrowth and scheduled for re -treatment as necessary. All disturbed areas
under Oxy management will also be monitored to ensure there are no new weed infestations.
Prevention
The purpose of prevention measures is to preclude the introduction of new or existing noxious
weeds from the project area to un -infested areas or from adjacent land into the project area.
Construction Prevention Measures
Construction equipment entering project areas (backhoes, trackhoes, dozers, blades,
rollers, lowboys, equipment trailers, etc.) will be power washed or otherwise cleaned.
"Equipment" is defined as any earth moving and any other machinery, trucks or vehicles,
trailers and tools. On Federal property, equipment may be inspected by BLM or Forest
Service (FS) personnel. Pickup trucks, SUVs, vans, water trucks, and pipe trucks should
also be clean but do not require inspection prior to entering federal lands. Where
required, track pads, gravel beds or rumble strips will be installed at ingress/egress points
to the site to limit weed seed from entering or leaving the site.
Soils from infested areas of the project site will not be moved off site, but will be
stockpiled and treated for weeds as necessary. If infested soils are moved off site, they
will be kept on Oxy -managed property, monitored, and treated as necessary. Stockpiled
soils will be monitored and treated to control noxious weeds. All purchased products
used in development and reclamation of a site will be inspected or certified as weed -free
whenever possible, including soils, rock and gravel, seeds, mulch and erosion control
products.
Operational Prevention Measures
Existing facilities such as well pads, valve/meter sites, and compressor stations that
require work areas to be free of vegetation shall have bareground treatments at the start
of spring. Existing facilities such as access roads and reclaimed pipeline right-of-ways
shall be monitored through the growing season for noxious weeds and noxious weeds
identified will be treated.
Revegetation
The goal of reclamation and revegetation of a site after disturbance is timely establishment of a
desirable native plant community and prevention of noxious weed infestation. Elements of
successful revegetation include the use of topsoil that was set aside during construction and kept
weed -free; reseeding with appropriate species to establish plant cover, and stabilization of the
soil surface with the appropriate mulches, tackifiers, and erosion control products as needed.
Cascade Creek Noxious Weed Management Plan Page 5
Plans for revegetation and reclamation of disturbed areas are site-specific, and will include a
plant list, method of seeding, how seeding success will be determined and how the revegetated
area will be monitored. Oxy will rely on existing surface use agreements, revegetation plan, or
Stormwater Management Plan, which has a recommended seed mix. BLM and FS seed mixes
are compiled on a site-specific basis, according to elevation and existing vegetation community
on the site. Non-native, non-persistent sterile grasses may be used to provide ground cover for
soil stabilization and weed suppression during temporary reclamation on both private and federal
land. See Appendix D for a sample Oxy Revegetation and Reclamation Plan.
Certified weed seed free straw, hay, mulch, seed or other materials will be used for soil
stabilization and/or revegetation purposes (Colorado Department of Agriculture certified inspector
to State standards). Seed tags will be available for inspection upon request of the Inspector.
Topsoil that is stock piled for more than one year will be seeded according to above standards at
the earliest practical time to reduce the possibility of noxious weed establishment.
Revegetation efforts will be monitored annually until successful establishment of desirable or
intentionally planted seed or plants is confirmed. Noxious weeds found in revegetation will be
documented, and managed per guidelines in this Weed Management Plan.
Control and Management
The noxious weed contractor will follow the guidelines identified in the Noxious Weed
Management Plan developed by the Colorado Department of Agriculture and the Garfield County
Noxious Weed Management Plan developed by the Garfield County Vegetation Management
department to identify, treat, and control noxious weeds. Treatments will include herbicide,
cultural, mechanical, revegetation, and biological control alone or in combination as necessary for
efficient weed control. On federal lands, control and management methods (including herbicide
use) will be verified and approved with the appropriate land management agency representatives.
Noxious weed management activities on federal lands will comply with the BLM or other land
management agencies PUP. Annual reporting to the BLM or other land management agency will
be completed as prescribed in the PUP by the noxious weed contractor.
The accompanying treatment tables describe the management methods, rates, and timing of
control measures for specific targeted weeds (see Table 1 and Table 2). Treatment application
records will be retained by Oxy and available for inspection by agency personnel listed in the
contacts section below.
Cascade Creek Noxious Weed Management Plan Page 6
Table 1 Weed Management Methods
Target Weed(s)
Management
Method(s)
Herbicide
Recommendation
Product/Met
Adjuvant or
Surfactant
& Rate
Timing of Control
Chamomile, scentless
(Matricaria perforate)
Herbicide,
mechanical, cultural
picloram orclopyralid,
as per label
Nonionic surfactant,
as per label
Pre -flower, early
season
Houndstongue
(Cynoglossum
officinate)
Herbicide,
mechanical, cultural
picloram or picloram +
2,4-0, as per label
Nonionic surfactant,
as per label
Pre -bud or rosette
stage (early spring)
Knapweed, Russian
(Acroptilon repens)
Herbicide, cultural
1)clopyralid plus2,4-D,
or 2)clopyralid plus
triclopyr or 3)picloram,
as per label
Nonionic surfactant,
as per label
Fall
Knapweed, spotted
(Centaurea maculosa)
Herbicide
1)clopyralid plus2,4-D,
or 2)clopyralid plus
triclopyr or
3)glyphosate, as per
label
Nonionic surfactant,
as per label
Rosettes in fall or
early spring
Moth mullein
(Verbascum blattaria)
Herbicide,
mechanical, cultural
Dicamba or
chlorsulfuron, as per
label
Nonionic surfactant,
as per label
Rosettes in fall or
early spring
Oxeye daisy,
(Chrysanthemum
leucanthemum)
Herbicide,
mechanical, cultural
Clopyralid or
metsuifuron methyl, as
per label
Nonionic surfactant,
as per label
Early, young growth
*Sulfur cinquefoil
(Potentilla recta)
Herbicide,
mechanical, cultural
1)picloram or
2)metsulfuron methyl,
as per label
Nonionic surfactant,
as per label
Spring or fall
*Tamarisk, Salt cedar
(all Tamarix sp.)
Herbicide
Triclopyr, as per label
Nonionic surfactant,
as per label
Basal spray on
young plants, cut
and treat stump on
older plant.
Thistle, bull
(Cirsium vulgare)
Herbicide,
mechanical, cultural
Clopyralid or picloram,
as per label
Nonionic surfactant,
as per label
Rosette stage,
spring or fall
Thistle, Canada
(Breea arvense)
Herbicide, cultural
1)clopyralid plus2,4-D,
or 2)clopyralid plus
triclopyr or
3)glyphosate, as per
label
Nonionic surfactant,
as per label
Early bud stage or
fall rosettes
Thistle, musk
(Carduus nutans)
Herbicide, biological,
mechanical, cultural
1) 2,4-0 or 2)
Clopyralid plus 2,4-D
or 3)glyphosate, as
per label
Nonionic surfactant,
as per label
Rosette stage,
spring or fall
Thistle, plumeless
(Carduus
acanthokles)
Herbicide,
mechanical, cultural
Clopyralid or tricloram,
as per label
Nonionic surfactant,
as per label
Rosette stage,
spring or fall
Cascade Creek Noxious Weed Management Plan
Page 7
'These are small population or individuals that have been treated in the area, and will be monitored; all others are large
and widespread populafons
(Herbicides that are preferred for control are numbered as 1, if not numbered, there is no preference
Table 2 Biological, Cultural, or Mechanical Methods to be Used
Practice
Target Weed(s)
Herbicide
Adjuvant or
Removal of small infestations by pulling or hand grubbing at any
stage.
Tar
Target Weeds
g
Management
Method(s)
Recommendation
Surfactant
Timing of Control
Product/Ratef
& Rate
Thistle, Scotch
Herbicide,
Picloram or dicamba,
Nonionic surfactant,
Rosette stage,
(Onopordum tauricum,
mechanical, cultural
as per label
as per label
spring or fall
Onopordum
acanthium)
'These are small population or individuals that have been treated in the area, and will be monitored; all others are large
and widespread populafons
(Herbicides that are preferred for control are numbered as 1, if not numbered, there is no preference
Table 2 Biological, Cultural, or Mechanical Methods to be Used
Practice
Target Weed(s)
Seeding with approved seed mix to revegetate disturbed land,
including a combination of fast growing and long-term species
(see revegetation plan).
All weeds above, but especially important for those
that list cultural as a control method in Table 1.
Removal of small infestations by pulling or hand grubbing at any
stage.
Houndstongue, bull thistle, musk thistle, plumeless
thistle, scotch thistle
Repeated mowing during bolting pre -flowering stage; cutting,
bagging and removal of flowering heads if already in flower
All thistle species
Introduce biological control approved for specific weeds in very
large infestations, after agency approval.
Those with biological listed as a control method in
Table 1 have approved bio -controls.
Cascade Creek Noxious Weed Management Plan Page 8
Local, State and Federal Contacts and Resources
Additional Noxious Weed Resource Management contacts include:
Grand Junction BLM Weed Management Specialist
Mark Tabor
2815 H Road
Grand Junction, CO 81601-4180
970.244.3004
Colorado State University Cooperative Extension Service
Garfield County
1001 Railroad Avenue, P.O. Box 1112
Rifle, CO 81650-1112
970.625.3969
Colorado Department of Agriculture
State Weed Coordinator
Noxious Weed Program
Division of Conservation Services
700 Kipling Street, Suite 4000
Lakewood, CO 80215-5894
303.239.4182
www.state.co.usidei/weeds/weed/html
Garfield County Vegetation Management
Steve Anthony
P.O. Box 426.0298 Cr 333A
Rifle, CO 81650
970.625.8601
Colorado Department of Agriculture
Division of Plant Industry
Biological Control Section
P.O. Box 400 Palisade, CO 81526
970.464.7916
Cascade Creek Noxious Weed Management Plan Page 9
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Weed Management Plan
Appendix C
Oxy Tracking Forms for Cascade Creek
Cascade Creek Noxious Weed Management Plan Page 17
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CC Access Road 2-1 (Mesa access)
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STATE OF COLORADO
John W. Hickenlooper, Governor
Christopher E. Urbina, MD, MPH
Executive Director and Chief Medical Officer
Dedicated to protecting and Improving the health and environment of the people of Colorado
4300 Cherry Creek Dr. S.
Denver, Colorado 80246-1530
Phone (303) 692-2000
Located in Glendale, Colorado
http:l/www.cdphe,state.co.us
June 21, 2012
Laboratory Services Division
8100 Lowry Blvd.
Denver, Colorado 80230-6928
(303) 692-3090
Doug Weaver, Ops Mgr & Attorney -in -Fact
Oxy USA WTP LP
760 Horizon Dr Ste 101
Grand Junction, CO 81506
Colorado Department
of Public Hcalth
and Environment
RE: Renewal of Permit/Certification
Administrative Continuation
For: Cascade Creek Common Plan of Development
Located at: 13 Mi N of Debeque (See map in file), Debeque, Garfield County
Permit No.: COR038414
Dear Mr. Weaver;
The Division has received an application to renew the above permit/certification. It has been determined
that there is sufficient information to make this permit/certification eligible for renewal. More information
may be requested by the Division as progress is made in developing a new permit/certification for the
above listed facility. This information must be made available to the Division when requested to complete
the permit process.
The Division is currently in the process of developing a new permit or master general permit and
associated certification for the above permitted facility. The development and review procedures required
by law have not yet been completed. When the discharge permit issued to you for your facility expired on
June 30, 2012 your permit is administratively continued and remains in effect under Section 104(7) of the
Administrative Procedures Act, C.R.S. 1973, 24-4-101, et seq (1982 repl. vol. 10) until the new
permit/certification is issued and effective.
All effluent permit terms and conditions in your current permit will remain in effect until your new
permit/certification is issued and effective.
PLEASE KEEP THIS LETTER WITH YOUR PERMIT AND SWMP TO SHOW
CONTINUATION OF PERMIT COVERAGE.
Sincerely,
Debbie Jessop
Permits Section
WATER QUALITY CONTROL DIVISION
xc: Permit File
STATE OF COLORADO
COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT
WATER QUALITY CONTROL DIVISION
TELEPHONE: (303) 6923500
CERTIFICATION TO DISCHARGE
UNDER
CDPS GENERAL PERMIT COR -030000
STORMWATER DISCHARGES ASSOCIATED WITH CONSTRUCTION
Certification Number COR038414
This Certification to Discharge specifically authorizes:
Oxy USA WTP LP
LEGAL CONTACT: LOCAL CONTACT:
Heidi Reed Sr. EHSAdvisor Joanna Fry, ,
Oxy USA ATP IP Phone # 970/263-7800
2754 Compass Drive Ste. 170 heidi reed®oxy.com
Grand Junction, CO 81506
Phone # 970/263-3609
ffrey@cordeontp.com
During the Construction Activity: Gas/Oil Field Exploration and/or
Development
to discharge stormwater from the facility identified as Cascade Creek
Development 'a
which is located at
13 miles north of Debeque, map in file
Debeque, Co 81630
Latitude 39/30/45, Longitude 108/14/10
In Garfield County
to: Cascade Creek — Colorado River
Anticipated Activity begins 07/01/2005 continuing through 05/17/2007
On 5 acres (5 acres disturbed)
Certification is effective: 07/01/2007 Certification Expires: 06/30/2012
Annual Fee: $245.00 (DO NOT PAY NOW — A prorated bill will be sent shortly.)
Page t of 22
ERO
ERO Resources Corp.
Denver
1842 Clarkson St.
Denver, CO 80218
303.830.1188
Boise
3314 Grace St.
Boise, ID 83703
208.373.7983
Durango
1015 V, Main Avenue
Durango, CO 81301
970.422.2136
Western Slope
P.O. Box 932
161 South 2"d St.
Hotchkiss, CO 81419
970.872.3020
www.eroresou rces.com
October 10, 2014
Katy Middleton
Blue Sky Permitting and Planning, LLC
9321 54 Road
Mesa, CO 81643
(Email -delivered)
RE: Noxious Weed Survey
OXY Conn Creek Compressor Station (CC -1) to Shell 797 Pipeline
Dear Ms. Middleton,
This memo transmits ERO Resources Corporation's (ERO) site review summary
for OXY USA WTP LP's (Oxy) Conn Creek compressor station (CC -1) pipeline in
the Grand Valley Field in Garfield County, Colorado. ERO surveyed the project area
on September 24, 2014. The proposed pipeline is located approximately 10 miles
north of DeBeque, Colorado (Figure 1).
Location and Existing Conditions
For the purposes of the proposed project, the survey area was defined as a uniform
50 -foot Right-of-way corridor surrounding the existing project envelope. The legal
description of the approximate center of the project area is Sections 5, 8, and 9 T7S,
R97W and Section 32 T6S, R97W of the 6th PM; UTM NAD 83 Zone 12N, 737050m
Easting, 4372373m Northing; Latitude, Longitude: 39.468305°N, -108.244193°W;
USGS Red Pinnacle, CO Quadrangle. Surface ownership includes Oxy, Savage
Limited Partnership, JOJO Properties, and Shell Frontier Oil and Gas.
Site Summary
The proposed CC -1 pipeline is in a valley bottom at an approximate elevation of
5,800 feet above sea level (Figure 1). The area consists of graveled and maintained
surfaces with minimal to no vegetation. These developed areas are immediately
surrounded by sagebrush -steppe habitat. Cliff and cottonwood riparian habitat occur
within 0.25 mile of the project area. The sagebrush -steppe habitat is dominated by
sagebrush (Artemisia tridentata sp.), primarily along the eastern project area
boundary. Dominant vegetation observed in the project area is show on Table 1.
Table 1. Dominant veeetation observed near CC -1 to Shell 797 Piaeline.
Common Name
Scientific Name
Sagebrush
Artemisia tridentata sp.
Saltbush
Atriplex spp.
Cheatgrass
Bromus tectorum
Consultants in
Natural Resources
and the Environment
Page 2
Common Name
Scientific Name
Gambel's oak
Quercus gambelii
Wheatgrasses
Thinopyrum spp.
Rye
Elymus spp.
Crested wheatgrass
Agropyron cristatum
Rabbitbrush
Ericameria nauseosa
Perennial pepperweed
Lepidium latifolium
Musk thistle
Carduus nutans
Bindweed
Convolvulus arvensis
Russian thistle
Salsola kali
Narrowleaf cottonwood
Populus angustifolia
Chinese clematis
Clematis orientalis
Noxious weeds
The Colorado Noxious Weed Act designates undesirable plants that are considered
threats to Colorado's natural resources. The Colorado Noxious Weed Act contains
three lists of noxious weeds: List A, List B and List C. List A and B weeds are
targeted for eradication. List C species are not considered major threats at this time
and are not currently subject to eradication. Garfield County has designated 21
species as noxious weeds (see Appendix A).
Table 2. Noxious Weed Species Observed the Survey Area
Common name
Scientific name
State of Colorado
Noxious Weed
List*
Garfield County
Noxious Weed
List
Plumeless thistle
Carduus
acanthoides
List B
Yes
Houndstongue
Cynoglossum
officinale
List B
Yes
Common burdock
Arctium minus
List C
Yes
Russian knapweed
Centaurea diffusa
List B
Yes
Saltcedar (Tamarisk)
Tamarix
ramosissima
List B
Yes
Musk thistle
Carduus nutans
List B
Yes
Redstem filaree
Erodium cicutarium
List B
No
Common mullein
Verbascum thapsus
List C
No
Downy
brome/cheatgrass
Bromus tectorum
List C
No
Field bindweed
Convolvulus
arvensis
List C
No
ERO
Resources
Corporation
Page 3
Common name
Scientific name
State of Colorado
Noxious Weed
List*
Garfield County
Noxious Weed
List
Halogeton
Halogeton
glomeratus
List C
No
Velvetleaf
Abutilon
theophrasti
List C
No
Chinese clematis
Clematis orientalis
List B
No
*The Colorado Noxious Weed Act contains three lists of noxious weeds: List A, List B and List C. List
A and B weeds are targeted for eradication. List C species are not considered major threats at this time
and are not currently subject to eradication
Colorado Department of Agriculture. 2014. Noxious Weed Species.
http://www.colorado.gov/cs/Satellite/ag_Conservation/CBON/1251618874438. Last accessed:
September 2014.
Garfield County. 2014. Noxious Weed List. Available at: http://www.garfield-county.com/vegetation-
management/noxious-weed-list.aspx. Last accessed: September 2014,
Treatment/Mitigation Recommendations
Oxy monitors and treats noxious weeds seasonally, typically with bare -ground
treatments in the early spring followed by hand -spray applications upon detection of
noxious weeds. Oxy tracks noxious weed treatment in compliance with Oxy's
Noxious Weed Management Plan.
ERO recommends cutting and bagging thistle heads prior to any clearing or
surface disturbance to minimize weed spread. Concentrated areas of thistles are
limited and this should be a simple exercise. Areas to cut/bag thistle heads are near
the well pad site from the road crossing south, and near CC -1.
ERO recommends that the seed mix in Table 3 be applied to all disturbed areas as
soon as possible following surface grading. Any topsoil present in disturbed areas
should be salvaged and stored until needed for final reclamation and grading. Surface
should be roughened to produce microclimates conducive to seed establishment and
growth. To minimize efforts for weed control, Oxy could eliminate the shadscale and
fourwing saltbush from initial seeding efforts so that a broad -leaf spray could be
applied, particularly in the area near the Shell 797-09A Pad and CC -1.
Table 3. Approved Seed Mix
Common Name
Scientific Name
Form
PLS
lbs/acrex
Bluebunch
wheatgrass
Pseudoroegneria spicata,
Agropyron spicatum
Bunch
19.28
Shadscale saltbush
Atriplex confertifolia
Shrub
18.51
Fourwing saltbush
Atriplex canescens
Shrub
18.42
Streambank
wheatgrass
Elymus lanceolatus ssp.
psammophilus, Agropyron
riparium
Sod -forming
17.23
Indian ricegrass
Achnatherum hymenoides
Bunch
14.87
ERO
Resources
Corporation
Page 4
Common Name
Scientific Name
Form
PLS
lbs/acre*
Galleta grass
Pleuraphis [Hilaria] jamesii
Bunch
6.77
Alkali sacaton
Sporobolus airoides
Bunch
0.63
Please feel free to contact me at (970) 872-3020 or apowers@eroresources.com if
you have any questions.
Sincerely,
Aktr
Aleta Powers
Principal, Natural Resource Specialist
ERO
Resources
Corporation
PHOTO LOG
OXY CC -1 WEED SURVEY REPORT
Photo 1. View North Near CC -1 (9 24.14)
Photo 2. View of tamarisk near CC -1 (9.24.14)
FRO
Resources
Corporation
PHOTO LOG
OXY CC -1 WEED SURVEY REPORT
Photo 3. View Southeast of thistle near CC -1 (9.24.14)
Photo 4. View South over ROW near CC -1 entrance road (9.24.14)
fRO
Resources
Corporation
PHOTO LOG
OXY CC -1 WEED SURVEY RETORT
Photo 5. View South from CC -1 (9.24.14)
Photo 6. View North near Oxy Conn Creek Entrance (9.24.14)
ERO
Resources
Corporation
PHOTO LOG
OXY CC -1 WEED SURVEY REPORT
Photo 7. View South near Oxy Conn Creek Entrance (9.24.14)
Photo 8. View South Toward Oxy Conn Creek Entrance (9.24.14)
FRO
Resources
Corporation
PHOTO LcG
OXY CC -1 WEED SURVEY REPORT
Photo 9. View West toward Oxy Conn Creek Entrance (9.24.14)
Photo 10. View South from Pond 10 (9.24.14)
ERO
Resources
Corporation
PHOTO LOG
OXY CC -1 WEED SURVEY REPORT
Photo 11. View West along ROW near Shell 797 09A Pad (9.24.14)
Photo 12. View South near Shell 797 09A Pad (9.24.14)
ERO
Resources
Corporation
PHOTO LOG
OXY CC -1 WEED SURVEY REPORT
Photo 13. View North toward Shell 797 09A Pad Access Road (9.24.14)
Photo 14. View East toward Shell 797-09APad (9.24.14)
ERO
Resources
Corporation
Appendix A — Garfield County and State of Colorado Noxious Weed Lists
10/2/2014
Garfield County vegetation- nodous weed list
GARFIELD COUNTY
how our business for do it
do 1? towns here seniors online
44
CV' V
14711 : -ELECTED OFFICES
VEGETATION MANAGEMENT
pages
Garfield County home
Vegetation Management
Documents and forms
Mosquito control
Noxious weed list
Weed calendar/guidebook
Weed cost share
Weed law enforcement
Weed Advisory Board
Noxious weed list
Click on a common name to view image and detailed description.
LCommon name
Scientific name
Leafy Spurge
Euphorbia esula
Russian Knapweed
Acroptilon repens
Yellow Starthistle
Centaurea solstitalis
Plumeless Thistle
[Carduus acanthoides
[Cynoglossum officinale
t-bundstongue
Common Burdock
I Arctium minus
Scotch Thistle
Onopordum acanthium
Canada Thistle
Cirsium arvense
Spotted Knapweed
Centaurea maculosa
Diffuse Knapmed
Centaurea diffuse
Dalmatian
I Toadflax Linaria dalmatica
IYellow Toadflax
I Linariavu[gads
Hoary Cress
LCardaria draba
Salt Cedar
Tamarix parviflora, Tamarix ramosissima
Oxeye Daisy
[Chrysanthemum leucantheum
Jointed Goatgrass
LAegilops cylindrica
Chicory
Cichorium intybus
IMusk Thistle
Carduus nutans
Purple Loosestrife J
LLythrum salicaria
Russian Olive I I
Elaeagnus angustifolia
resources
Home Comrnissioner.s Fleeted Offices Departments Employment News Evrnts Community
Vegetation Management
0375 County Road 352 Bldg. 2060
Rifle, CO 81650
Email Vegetation Management
970-945-1377, ext 4305 1 phone
970-625-5939 1 fax
http:/M wv.garfield-county.corrikegetalion-management/nordous-weed-list.aspx 112
Colorado Noxious Weeds (including Watch List)
List A Species (22)
Common
Scientific
African rue
Camelthom
Common crupina
Cypress spurge
Dyer's woad
Elongated mustard
Giant reed
Giant salvinia
Hydrilla
Japanese knotweed
Giant knotweed
Bohemian knotweed
Meadow knapweed
Mediterranean sage
Medusahead
Myrtle spurge
Orange hawkweed
Purple loosestrife
Rush skeletonweed
Squarrose knapweed
Tansy ragwort
Yellow starthistle
List 8 Species (37)
Common
(Peganum harmala)
(Alhagi pseudalhagi)
(Crupina vulgaris)
(Euphorbia cyparissias)
(Isatis tinctoria)
(Brassica elongata)
(Arundo donax)
(Salvinia molesta)
(Hydrilla verticillata)
(Polygonum cuspidatum)
(Polygonum sachalinense)
(Polygonum x bohemicum)
(Centaurea pratensis)
(Salvia aethiopis)
(Taeniatherum caput -medusae)
(Euphorbia myrsinites)
(Hieracium aurantiacum)
(Lythrum salicaria)
(Chondrilla juncea)
(Centaurea virgata)
(Senecio jacobaea)
(Centaurea solstitialis)
Scientific
Absinth wormwood
Black henbane
Bouncingbet
Bull thistle
Canada thistle
Chinese clematis
Common tansy
Common teasel
Corn chamomile
Cutleaf teasel
Dalmatian toadflax, broad-leaved
Dalmatian toadflax, narrow -leaved
Dame's rocket
Diffuse knapweed
Eurasian watermilfoil
Hoary cress
Houndstongue
Jointed goatgrass
Leafy spurge
Mayweed chamomile
Moth mullein
Musk thistle
Oxeye daisy
Perennial pepperweed
Plumeless thistle
Ouackgrass
Russian knapweed
Russian -olive
Salt cedar
Scentless chamomile
(Artemisia absinthium)
(Hyoscyamus niger)
(Saponaria officinalis)
(Cirsium vulgare)
(Cirsium arvense)
(Clematis orlentalis)
(Tanacetum vulgare)
(Dipsacus fullonum)
(Anthemis arvensis)
(Dipsacus laciniatus)
(Linaria dalmatica)
(Linaria genistifolia)
(Hesperis matronalis)
(Centaurea diffusa)
(Myriophyllum spicatum)
(Cardaria draba)
(Cynoglossum officinale)
(Aegilops cylindrica)
(Euphorbia esula)
(Anthemis cotula)
(Verbascum blattaria)
(Carduus nutans)
(Chrysanthemum leucanthemum)
(Lepidium latifolium)
(Carduus acanthoides)
(Elytrigia repens)
(Acroptilon repens)
(Elaeagnus angustifolia)
(Tamarix chinensis, T. parviflora, and T. ramosissima)
(Matricaria perforata)
Scotch thistle
Spotted knapweed
Spurred anode
Sulfur cinquefoil
Venice mallow
Wild caraway
Yellow nutsedge
Yellow toadflax
List C Species (15)
Common
(Onopordum tauricum)
(Centaurea maculosa)
(Anoda cristata)
(Potentilla recta)
(Hibiscus trionum)
(Carum carvi)
(Cyperus esculentus)
(Linaria vulgaris)
Scientific
Bulbous bluegrass
Chicory
Common burdock
Common mullein
Common St. Johnswort
Downy brome
Field bindweed
Halogeton
Johnsongrass
Perennial sowthistle
Poison hemlock
Punclurevine
Redstem filaree
Velvetleaf
Wild proso millet
Watch List Species (26)
Common
(Poa bulbosa)
(Cichorium intybus)
(Arctium minus)
(Verbascum thapsus)
(Hypericum perforatum)
(Bromus tectorum)
(Convolvulus arvensis)
(Halogeton glomeratus)
(Sorghum halepense)
(Sonchus arvensis)
(Conium maculatum)
(Tribulus terrestris)
(Erodium cicutarium)
(Abutilon theophrasti)
(Panicum miliaceum)
Scientific
Asian mustard
Baby's breath
Bathurst burr, Spiney cocklebur
Brazilian elodea
Common bugloss
Common reed
Flowering rush
Garlic mustard
Hairy willow -herb
Himalayan blackberry
Japanese blood grass/cogongrass
Meadow hawkweed
Onionweed
Pampas grass
Parrotfeather
Scotch broom
Sericea lespedeza
Swainsonpea
Syrian beancaper
Water hyacinth
Water lettuce
White bryony
Woolly distaff thistle
Yellow flag iris
Yellow floatingheart
Yellowtuff
(Brassica tournefortii)
(Gypsophila paniculata)
(Xanthium spinosum)
(Egeria densa)
(Anchusa officinalls)
(Phragmites australis)
(Butomus umbellatus)
(Alliaria petiolata)
(Epilobium hirsutum)
(Rubus armeniacus)
(Imperata cylindrica)
(Hieracium caespitosum)
(Asphodelus fistulosus)
(Cortideria jubata)
(Myriophyllum aquaticum)
(Cytisus scoparius)
(Lespedeza cuneata)
(Sphaerophysa salsula)
(Zygophyllum fabago)
(Eichhornia crassipes)
(Pistia stratiotes)
(Bryonia alba)
(Carthamus lanatus)
(Iris pseudacorus)
(Nymphoides peltata)
(Alyssum murale, A. corsicum)
VW
I\ (6(
Jot
Pipeline Corridor.
Shell 797-09A Pad to CC1 Compressor Station
Section 32, T65, R97W; Sections 5, 8 and 9, T7S, R97W; 6th PM
UTM NAD 83: Zone 12N; 737327mE, 4372517mN
Latitude, Longitude: 39.469531°N, 108.241125°W
USGS Red Pinnacle, CO Quadrangle
Garfield County, Colorado 0 1,000 2,000
Feet
Figure 1
Vicinity Map
Prepared for: Oxy
file: 5754 figure 1.mxd (55)
October 3, 2014
ERA
ERO Resources Corp.
Portions of This document include intellecteol property et ESRI and Its license. and ore used herein under tcense. Copyright 0 2013 ESRI and .3 licensors, All tights reserved.
OXY USA WTP LP
Mer 760 Honzon Drive, Suite 101
Grand Junction, Co 81506
Figure 2 - Shell 797-09A pad to CC1
Compressor Station Pipeline Survey
Revised, October 1, 2014 Garfield County, Colorado
0 0,1 0,2 0.3 0.4 0.5
1111010117 Miles
T6S-R97W
032(';,
CC1 Gas Plant
Low density Clematis, Burdock, Musk Thistle, and Houndstongue
Low density Clematis, Burdock, Thistle, Houndstongue, observed one Velvet Leaf
Low density Burdock and Russian Knapweed
Low density Field Bindweed
T7S-R97,W`
Low density Redstem Filaree
Shell 797-09A
Low density Redstem Filaree
Low density Halogeton
Tamarisk (Individual)
Medium density Russian Knapweed,
Plumeless Thistle, Musk Thistle,
and Halogeton
Note - Cheatgrass found throughout
the entire Weed Survey Area
C3 weed Survey Area
Low density weed population
Medum density weed population
Ffigh density weed population
'N.—. Unimproved Public Road
Gravel Public Road
Paved Public Road
f!"& OXY USA WTP LP
moor 760 Horizon Drive, Suite 101
111610/ Grand Junction, CO 81506
031
029
Shell 797-09A to CC1 Pipeline
Parcel Location Zoom Map
Revised: Oct 6, 2014 Garfield County, Colorado
0 0.1 0.2 0.3 0.4 0.5
Miles
T6S-R97W
Compressor Statron
032
006
007
008
t
1 I�
"/ Shell 797-09Ato CC1 Pipeline Route
''1—• Oxy responsible road
Shell 797-09Awell pad
Shell Frontier Oil & Gas
dip Savage Limited Partnership
JOJO Properties
dip OXY USA Inc.
Th
FED 97.0-510
Project Number 014-2088
Drawn 8y: BKR
Revised By' BKR
Revision Date. 9292014
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Station Pipeline Project
Garfield County, Colorado
Page 1 of 1
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