Document:

EX-10.5

 Exhibit 10.5 

FORM OF OMNIBUS AGREEMENT 
 This Omnibus Agreement (“Agreement”) is entered into on, and effective as of, [ — ], 2013 (the “Closing
Date”) among QEP Resources, Inc., a Delaware corporation (“QEP”), QEP Field Services Company, a Delaware corporation (“Field Services”), QEP Midstream Partners, LP, a Delaware limited partnership (the
“Partnership”), QEP Midstream Partners GP, LLC, a Delaware limited liability company and the general partner of the Partnership (the “General Partner”), and QEP Midstream Partners Operating, LLC, a Delaware limited
liability company and wholly owned subsidiary of the Partnership (the “Operating Company” and, together with QEP, Field Services, the Partnership and the General Partner, the “Parties” and each a
“Party”). 
 RECITALS 
 1. The Parties desire by their execution of this Agreement to evidence their understanding, as more fully set forth in Article II, with respect to certain indemnification obligations of the Parties
to each other. 
 2. The Parties desire by their execution of this Agreement to evidence their understanding, as more fully set
forth in Article III, with respect to the amount to be paid by the Partnership for the centralized corporate services to be performed by QEP and its Affiliates for and on behalf of the Partnership Group. 

3. The Parties desire by their execution of this Agreement to evidence their understanding, as more fully set forth in Article IV,
with respect to the granting of certain licenses between the Parties. 
 In consideration of the premises and the covenants,
conditions, and agreements contained herein, and for other good and valuable consideration, the receipt and sufficiency of which are hereby acknowledged, the Parties agree as follows: 

ARTICLE I 

Definitions and Interpretation 
 1.1 Definitions. In addition to the terms defined in the introductory paragraph and the recitals of this Agreement, for purposes hereof, the capitalized terms used herein and not otherwise defined
shall have the meanings set forth in Appendix A. 
 1.2 Rules of Construction. Unless expressly provided for
elsewhere in this Agreement, this Agreement shall be interpreted in accordance with the following provisions: 
 (a) If a word
or phrase is defined, its other grammatical forms have a corresponding meaning. 
 (b) The headings contained in this Agreement
are for reference purposes only and shall not affect the meaning or interpretation of this Agreement. 
 (c) A reference to any
Party to this Agreement or another agreement or document includes the Party’s successors and assigns. 

 (d) The words “hereof,” “herein” and “hereunder” and words of
similar import when used in this Agreement shall refer to this Agreement as a whole and not to any particular provision of this Agreement, and article, section, subsection and schedule references are to this Agreement unless otherwise specified.

 (e) The words “including,” “include,” “includes” and all variations thereof shall mean
“including without limitation.” 
 (f) The word “or” shall have the inclusive meaning represented by the
phrase “and/or.” 
 (g) The words “shall” and “will” have equal force and effect. 

(h) The schedules identified in this Agreement are incorporated herein by reference and made a part of this Agreement. 

(i) References to “$” or to “dollars” shall mean the lawful currency of the United States of America. 

ARTICLE II 

Indemnification 
 2.1 Environmental Indemnification. 
 (a) Each of QEP and Field Services,
jointly and severally, shall indemnify, defend and hold harmless each Group Member from and against any Losses suffered or incurred by such Group Member, directly or indirectly, by reason of or arising out of: 

(i) any violation of Environmental Laws as in effect prior to the Closing Date and such violation commenced, occurred or
existed before the Closing Date; 
 (ii) any environmental event, condition or matter associated with or arising
from the ownership or operation of the Assets that commenced, occurred or existed before the Closing Date (including the presence of Hazardous Substances on, under, about or migrating to or from the Assets or the disposal or the release of Hazardous
Substances generated by operation of the Assets at non-Asset locations), including (A) the cost and expense of any investigation, assessment, evaluation, monitoring, containment, cleanup, repair, restoration, remediation, risk-based closure
activities, or other corrective action required or necessary under Environmental Laws and (B) the cost and expense of the preparation and implementation of any closure, remedial, corrective action, or other plans required or necessary under
Environmental Laws as in effect prior to the Closing Date; and 
 (iii) any environmental event, condition or
matter associated with or arising from the Retained Assets, whether occurring before, on or after the Closing Date and whether occurring under Environmental Laws as in effect prior to, at or after the Closing Date (clauses (i), (ii) and
(iii) being referred to collectively as “Covered Environmental Losses”); 

  
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 provided, however, that QEP and Field Services will be obligated to indemnify such Group Member for a
Covered Environmental Loss described in Section 2.1(a)(i) or Section 2.1(a)(ii) only to the extent that QEP is notified in writing of such violation, event, condition or environmental matter prior to the Identification
Deadline. 
 (b) The Partnership shall indemnify, defend and hold harmless QEP and Field Services from and against any
Losses suffered or incurred by any of the QEP Entities, directly or indirectly, by reason of or arising out of: 

(i) any violation of Environmental Laws as in effect on or after the Closing Date and such violation is associated with or
arises from the ownership or operation of the Assets on or after the Closing Date; and 
 (ii) any environmental
event, condition or matter associated with or arising from the ownership or operation of the Assets on or after the Closing Date (including the presence of Hazardous Substances on, under, about or migrating to or from the Assets or the disposal or
the release of Hazardous Substances generated by operation of the Assets at Asset locations) including (A) the cost and expense of any investigation, assessment, evaluation, monitoring, containment, cleanup, repair, restoration, remediation,
risk-based closure activities, or other corrective action required or necessary under Environmental Laws in effect on or after the Closing Date, and (B) the cost or expense of the preparation and implementation of any closure, remedial,
corrective action, or other plans required or necessary under Environmental Laws as in effect on or after the Closing Date; 
 and regardless of
whether such violation under Section 2.1(b)(i) or such environmental event, condition or matter included under Section 2.1(b)(ii) occurred before or after the Closing Date, in each case, to the extent that any of the
foregoing are not Covered Environmental Losses (without giving effect to the Environmental Deductible). 
 2.2 Right of Way
Indemnification. Each of QEP and Field Services, jointly and severally, shall indemnify, defend and hold harmless each Group Member from and against any Losses suffered or incurred by such Group Member by reason of or arising out of (a) the
failure of such Group Member to be the owner of such valid and indefeasible easement rights or fee ownership or leasehold interests in and to the lands on which any of the Assets conveyed or contributed to such Group Member on the Closing Date is
located as of the Closing Date, and such failure renders such Group Member liable to a third party or unable to use or operate the Assets in substantially the same manner that the Assets were used and operated as of immediately prior to the Closing
Date; (b) the failure of such Group Member to have the consents, licenses and permits necessary to allow (1) any pipeline included in the Assets to cross the roads, waterways, railroads and other areas upon which any such pipeline is
located as of the Closing Date, or (2) the transfer of any of the Assets to the Partnership Group, in each case, where such failure renders the Partnership Group liable to a third party or unable to use or operate the Assets in substantially
the same manner that the Assets were used and operated as of immediately prior to the Closing Date; and (c) the cost of curing any condition set forth in Section 2.3(a) or (b) that does not allow any Asset to be operated
in accordance with prudent industry practice, in each case to the extent that QEP and Field Services are notified in writing of any of the foregoing prior to the Identification Deadline. 

  
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 2.3 Additional Indemnification. 

(a) Each of QEP and Field Services, jointly and severally, shall indemnify, defend, and hold harmless each Group Member from and against
any Losses suffered or incurred by such Group Member by reason of or arising out of: 
 (i) the consummation of
the transactions contemplated by the Contribution Agreement. For the avoidance of doubt, the Parties agree that, subject to the qualifications set forth on Schedule A, each Group Member shall be entitled to indemnification by QEP and Field
Services under this Section 2.3(a)(i) for those litigation matters listed on Schedule A; 

(ii) events and conditions associated with the Retained Assets, whether occurring before, on or after the Closing Date;

 (iii) all federal, state and local tax liabilities attributable to the ownership or operation of the Assets on
or prior to the Closing Date, including under Treasury Regulation Section 1.1502-6, as it may be amended (or any similar provision of state or local law), and any such tax liabilities that may result from the consummation of the formation
transactions for the Partnership Group and the General Partner occurring prior to the Closing Date or from the consummation of the transactions contemplated by the Contribution Agreement; and 

(iv) the failure of any Group Member to have on the Closing Date any consent, license, permit or approval necessary to
allow such Group Member to own or operate the Assets in substantially the same manner that the Assets were owned or operated immediately prior to the Closing Date. 
 (b) The Partnership shall indemnify, defend, and hold harmless QEP and Field Services from and against any Losses suffered or incurred by any of the QEP Entities by reason of or arising out of events and
conditions to the extent associated with the ownership or operation of the Assets and occurring after the Closing Date (other than Covered Environmental Losses which are provided for under Section 2.1(a) and Losses for which the
Partnership is indemnifying QEP under Section 2.1(b)), unless such indemnification would not be permitted by any Group Member under the Partnership Agreement. 
 2.4 Indemnification Procedures. 
 (a) The Indemnified Party agrees that
within a reasonable period of time after it becomes aware of facts giving rise to a claim for indemnification under this Article II, it will provide notice thereof in writing to the Indemnifying Party, specifying the nature of and specific
basis for such claim. 
 (b) The Indemnifying Party shall have the right to control all aspects of the defense of (and any
counterclaims with respect to) any claims brought against the Indemnified Party that are covered by the indemnification under this Article II, including, without limitation, the selection of counsel, determination of whether to appeal any
decision of any court and the settling of any such claim or any matter or any issues relating thereto; provided, however, that no such 

  
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settlement for only the payment of money shall be entered into without the consent of the Indemnified Party unless it includes a full release of the Indemnified Party from such claim; provided
further, that no such settlement containing any form of injunctive or similar relief shall be entered into without the prior written consent of the Indemnified Party, which consent shall not be unreasonably delayed or withheld. 

(c) The Indemnified Party agrees to cooperate in good faith and in a commercially reasonable manner with the Indemnifying Party, with
respect to all aspects of the defense of and pursuit of any counterclaims with respect to any claims covered by the indemnification under this Article II, including, without limitation, the prompt furnishing to the Indemnifying Party of any
correspondence or other notice relating thereto that the Indemnified Party may receive, permitting the name of the Indemnified Party to be utilized in connection with such defense and counterclaims, the making available to the Indemnifying Party of
any files, records or other information of the Indemnified Party that the Indemnifying Party considers relevant to such defense and counterclaims, the making available to the Indemnifying Party of any employees of the Indemnified Party and the
granting to the Indemnifying Party of reasonable access rights to the properties and facilities of the Indemnified Party; provided, however, that in connection therewith the Indemnifying Party agrees to use reasonable efforts to
minimize the impact thereof on the operations of the Indemnified Party and further agrees to maintain the confidentiality of all files, records, and other information furnished by the Indemnified Party pursuant to this Section 2.4. The
obligation of the Indemnified Party to cooperate with the Indemnifying Party as set forth in the immediately preceding sentence shall not be construed as imposing upon the Indemnified Party an obligation to hire and pay for counsel in connection
with the defense of and pursuit of any counterclaims with respect to any claims covered by the indemnification set forth in this Article II; provided, however, that the Indemnified Party may, at its own option, cost and expense,
hire and pay for counsel in connection with any such defense and counterclaims. The Indemnifying Party agrees to keep any such counsel hired by the Indemnified Party informed as to the status of any such defense or counterclaim, but the Indemnifying
Party shall have the right to retain sole control over such defense and counterclaims so long as the Indemnified Party is still seeking indemnification hereunder. 
 (d) In determining the amount of any loss, cost, damage or expense for which the Indemnified Party is entitled to indemnification under this Agreement, the gross amount of the indemnification will be
reduced by (i) any insurance proceeds realized by the Indemnified Party, and such correlative insurance benefit shall be net of any incremental insurance premium that becomes due and payable by the Indemnified Party as a result of such claim
and (ii) all amounts recovered by the Indemnified Party under contractual indemnities from third Persons. 
 2.5
Limitations Regarding Indemnification. 
 (a) With respect to Covered Environmental Losses under
Section 2.1(a)(i) or Section 2.1(a)(ii) that arise out of an event, condition or matter that is first discovered after the Closing Date, neither QEP nor Field Services shall be obligated to indemnify, defend and hold harmless
any Group Member until such time as the total aggregate amount of Losses incurred by the Partnership Group for such Covered Environmental Losses exceeds $500,000 (the “Environmental Deductible”), at which time QEP and Field Services
shall be obligated to indemnify the Partnership Group for the excess of such Covered Environmental Losses over the 

  
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Environmental Deductible. For the avoidance of doubt, it is agreed that the Environmental Deductible shall not apply to any Covered Environmental Losses incurred by any Group Member attributable
to those locations identified on Schedule B. 
 (b) For the avoidance of doubt, there is no deductible or cap with
respect to the indemnification owed by any Indemnifying Party under any portion of this Article II other than that described in Section 2.5(a). 
 (c) For the avoidance of doubt, the obligation of QEP and Field Services to indemnify any Group Member, as specified in Section 2.1, Section 2.2 and Section 2.3 shall
be limited to the extent of the Losses incurred by the Partnership with respect to its direct or indirect ownership interest in such Group Member. 
 (d) NOTWITHSTANDING ANYTHING HEREIN TO THE CONTRARY, IN NO EVENT SHALL ANY PARTY’S INDEMNIFICATION OBLIGATION HEREUNDER COVER OR INCLUDE CONSEQUENTIAL, INDIRECT, INCIDENTAL, PUNITIVE, EXEMPLARY,
SPECIAL OR SIMILAR DAMAGES OR LOST PROFITS (INCLUDING ANY DIMINUTION IN VALUE OF ANY PARTY’S RESPECTIVE INVESTMENT IN THE PARTNERSHIP) SUFFERED, DIRECTLY OR INDIRECTLY, BY ANY OTHER PARTY ENTITLED TO INDEMNIFICATION UNDER THIS AGREEMENT, EXCEPT
AS A REIMBURSEMENT FOR ANY SUCH DAMAGES AS ARE PAID TO A GOVERNMENTAL AUTHORITY OR OTHER THIRD PARTY. 
 ARTICLE III

 General and Administrative Services 
 3.1 General. QEP agrees to provide, and agrees to cause its Affiliates to provide, to the General Partner, for the Partnership Group’s benefit, the centralized general and administrative
services that QEP and its Affiliates have traditionally provided in connection with the ownership and operation of the Assets, which consist of the services set forth on Schedule C (the “General and Administrative Services”).
Absent the written agreement of the Parties to the contrary, the Parties agree that the General and Administrative Services will be received by the General Partner, for the benefit of the Partnership Group, at the General Partner’s principal
place of business. 
 3.2 Administrative Fee. 
 (a) As consideration for QEP’s and its Affiliates’ provision of the General and Administrative Services, the Partnership Group will pay to QEP an annual fee that will reflect the costs incurred
by QEP and its Affiliates in providing such General and Administrative Services (other than those costs for which QEP and its Affiliates are entitled to reimbursement pursuant to Section 3.3), as determined in good faith by QEP in
accordance with Schedule C (the “Administrative Fee”). The Parties acknowledge and agree that it is the intent of the Parties that the General and Administrative Services be provided based on an arm’s-length standard,
and that the Administrative Fee is intended to reflect such standard. For the avoidance of doubt, the Parties further acknowledge and agree that the Administrative Fee will cover the fully burdened cost of the General and Administrative Services
provided by QEP and its Affiliates to the 

  
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Partnership Group, as well as any third party costs actually incurred by QEP and its Affiliates on behalf of the Partnership Group in providing such General and Administrative Services (other
than those costs for which QEP and its Affiliates are entitled to reimbursement pursuant to Section 3.3), including the following: 
 (i) the compensation and employee benefits of employees of QEP or its Affiliates (and any withholding or payroll taxes related thereto), to the extent, but only to the extent, such employees perform
General and Administrative Services for the Partnership Group’s benefit. For the avoidance of doubt, the Administrative Fee shall include any withholding and payroll related taxes paid by QEP and its Affiliates in connection with any
long-term incentive plan of the General Partner or the Partnership Group. With respect to employees that do not devote all of their business time to the Partnership Group, such compensation and employee benefits (and any withholding or payroll taxes
related thereto) shall be allocated to the Partnership Group based on the annual weighted average of time spent and number of employees devoting services to the Partnership Group; 

(ii) any expenses incurred or payments made by QEP or its Affiliates on behalf of the Partnership Group for insurance
coverage with respect to the Assets or the business of the Partnership Group; 
 (iii) all expenses and
expenditures incurred by QEP or its Affiliates on behalf of the Partnership Group as a result of the Partnership becoming and continuing as a publicly traded entity, including, but not limited to, costs associated with annual, quarterly and current
reporting; tax return and Schedule K-1 preparation and distribution expenses; Sarbanes-Oxley compliance expenses; expenses associated with listing on the NYSE; independent auditor fees; legal fees; investor relations expenses; registrar and transfer
agent fees, outside director fees and director and officer insurance expenses; and 
 (iv) all sales, use,
excise, value added or similar taxes, if any, that may be applicable from time to time with respect to the services provided by QEP and its Affiliates to the Partnership Group pursuant to Section 3.1. 

(b) As part of the Administrative Fee, the Partnership Group shall pay to QEP a fixed fee, in the amount shown on Schedule C, in
consideration for the services of certain employees of QEP and its Affiliates in their capacities as officers of the General Partner and the Group Members. 
 (c) The Parties acknowledge and agree that the Administrative Fee may change each calendar year, as determined by QEP in good faith, to accurately reflect the degree and extent of the General and
Administrative Services provided to the Partnership Group and may be adjusted to reflect, among other things, the contribution, acquisition or disposition of assets to or by the Partnership Group or to reflect any change in the cost of providing
General and Administrative Services to the Partnership Group due to changes in any law, rule or regulation applicable to the QEP Entities or the Partnership Group, including any interpretation of such laws, rules or regulations. 

  
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 (d) On or prior to January 1 of each calendar year during the term of this Agreement,
QEP will notify the General Partner of the estimated amount of the Administrative Fee (including both the fixed and variable portions of the Administrative Fee as described in Schedule C) to be paid by the Partnership Group for such calendar
year. For the calendar year in which the Closing Date occurs, such estimate shall be made on or prior to the Closing Date and shall pertain only to the remainder of such calendar year. Commencing with the first full month following the Closing Date,
the Administrative Fee shall be invoiced and paid as follows: 
 (i) Within 20 days following the end of each
month during the term of this Agreement, QEP will submit to the Partnership Group an invoice of the amounts due for such month for the Administrative Fee. Each invoice will contain reasonably satisfactory support of such amounts and such other
supporting detail as the General Partner may reasonably require. 
 (ii) The Partnership Group will pay the
Administrative Fee within 10 days after the receipt of the invoice therefor. The Partnership Group shall not offset any amounts owing to it by QEP or any of its Affiliates against the Administrative Fee payable hereunder. 

3.3 Reimbursement of Expenses. 
 (a) In addition to the Administrative Fee payable under Section 3.2, the Partnership Group will reimburse QEP and its Affiliates for any additional out-of-pocket costs and expenses actually
incurred by QEP and its Affiliates in providing the General and Administrative Services, as well as any other out-of-pocket expenses incurred on behalf of the Partnership Group. 

(b) The Partnership Group will reimburse QEP and its Affiliates for any costs and expenses incurred by QEP and its Affiliates under
Section 3.3(a) as incurred on a monthly basis. 
 ARTICLE IV 

Licenses of Marks 
 4.1 Grant of QEP License. Upon the terms and conditions set forth in this Article IV, QEP hereby grants and conveys to the Partnership and each of the entities currently or hereafter
comprising a part of the Partnership Group a nontransferable, nonexclusive, royalty­free right and license (the “QEP License”) to use the “QEP” logo and trademark and the other trademarks and tradenames owned by QEP
(collectively, the “QEP Marks”). 
 4.2 Ownership and Quality of QEP Marks. The Partnership, on behalf
of itself and the other Group Members, agrees that ownership of the QEP Marks and the goodwill relating thereto shall remain vested in QEP during the term of the QEP License and thereafter. The Partnership agrees, and agrees to cause the other Group
Members, never to challenge, contest or question the validity of QEP’s ownership of the QEP Marks or any registration thereof by QEP. In connection with the use of the QEP Marks, the Partnership and any other Group Member shall not in any
manner represent that they have any ownership in the QEP Marks or registration thereof. The Partnership, on behalf of itself and the other Group Members, acknowledges that the use of the QEP Marks shall not create any right, title or interest in or
to the QEP Marks, and all use of the QEP Marks by the Partnership or any other Group Member shall inure to the 

  
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benefit of QEP. The Partnership agrees, and agrees to cause the other Group Members, to use the QEP Marks in accordance with such quality standards established by QEP and communicated to the
Partnership Group from time to time, it being understood that the products and services offered by the Group Members as of the Closing Date are of a quality that is acceptable to QEP. 

4.3 Grant of the Partnership License. Upon the terms and conditions set forth in this Article IV, the General Partner, for
the benefit of the Partnership, hereby grants and conveys to QEP and its Affiliates a nontransferable, nonexclusive, royalty-free right and license (“Partnership License”) to use the “QEPM” logo and trademark and the other
trademarks and tradenames owned by the General Partner for the benefit of the Partnership (collectively, the “Partnership Marks”). 
 4.4 Ownership and Quality of the Partnership Marks. QEP agrees, on behalf of itself and the other QEP Entities, that ownership of the Partnership Marks and the goodwill relating thereto shall
remain vested in the General Partner, for the benefit of the Partnership, during the term of the Partnership License and thereafter. QEP agrees, and agrees to cause the other QEP Entities, never to challenge, contest or question the validity of the
General Partner’s ownership of the Partnership Marks or any registration thereof by the General Partner or the Partnership. In connection with the use of the Partnership Marks, neither QEP nor any of the other QEP Entities shall in any manner
represent that they have any ownership in the Partnership Marks or registration thereof. QEP, on behalf of itself and the other QEP Entities, acknowledges that the use of the Partnership Marks shall not create any right, title or interest in or to
the Partnership Marks, and all use of the Partnership Marks by QEP or any of the other QEP Entities shall inure to the benefit of the General Partner and the Partnership. QEP agrees, and agrees to cause the other QEP Entities, to use the Partnership
Marks in accordance with such quality standards established by the General Partner, on behalf of and for the benefit of the Partnership, and communicated to QEP from time to time. 

4.5 Termination. The QEP License and the Partnership License shall each terminate upon the termination of this Agreement pursuant
to Section 5.5. 
 ARTICLE V 
 Miscellaneous 
 5.1 Confidentiality. 

(a) From and after the Closing Date, each of the Parties shall hold, and shall cause their respective Subsidiaries and Affiliates
and its and their directors, officers, employees, agents, consultants, advisors, and other representatives (collectively, “Representatives”) to hold all Confidential Information in strict confidence, with at least the same degree of
care that applies to such Party’s confidential and proprietary information and shall not use such Confidential Information and shall not release or disclose such Confidential Information to any other Person, except its Representatives or except
as required by applicable law. Each Party shall be responsible for any breach of this section by any of its Representatives. 

  
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 (b) If a Party receives a subpoena or other demand for disclosure of Confidential
Information received from any other Party or must disclose to a Governmental Authority any Confidential Information received from such other Party in order to obtain or maintain any required governmental approval, the receiving Party shall, to the
extent legally permissible, provide notice to the providing Party before disclosing such Confidential Information. Upon receipt of such notice, the providing Party shall promptly either seek an appropriate protective order, waive the receiving
Party’s confidentiality obligations hereunder to the extent necessary to permit the receiving Party to respond to the demand, or otherwise fully satisfy the subpoena or demand or the requirements of the applicable Governmental Authority. If the
receiving Party is legally compelled to disclose such Confidential Information or if the providing Party does not promptly respond as contemplated by this section, the receiving Party may disclose that portion of Confidential Information covered by
the notice or demand. 
 (c) Each Party acknowledges that the disclosing Party would not have an adequate remedy at law for the
breach by the receiving Party of any one or more of the covenants contained in this Section 5.1 and agrees that, in the event of such breach, the disclosing Party may, in addition to the other remedies that may be available to it, apply
to a court for an injunction to prevent breaches of this Section 5.1 and to enforce specifically the terms and provisions of this Section 5.1. Notwithstanding any other section hereof, to the extent permitted by applicable
law, the provisions of this Section 5.1 shall survive the termination of this Agreement. 
 5.2 Choice of Law;
Mediation; Submission to Jurisdiction. 
 (a) This Agreement shall be subject to and governed by the laws of the State of
Delaware, excluding any conflicts-of-law rule or principle that might refer the construction or interpretation of this Agreement to the laws of another state. EACH OF THE PARTIES HERETO AGREES THAT THIS AGREEMENT INVOLVES AT LEAST U.S. $100,000.00
AND THAT THIS AGREEMENT HAS BEEN ENTERED INTO IN EXPRESS RELIANCE UPON 6 Del. C. § 2708. EACH OF THE PARTIES HERETO IRREVOCABLY AND UNCONDITIONALLY AGREES (i) TO BE SUBJECT TO THE JURISDICTION OF THE COURTS OF THE STATE OF DELAWARE AND OF
THE FEDERAL COURTS SITTING IN THE STATE OF DELAWARE, AND (ii) TO THE EXTENT SUCH PARTY IS NOT OTHERWISE SUBJECT TO SERVICE OF PROCESS IN THE STATE OF DELAWARE, TO APPOINT AND MAINTAIN AN AGENT IN THE STATE OF DELAWARE AS SUCH PARTY’S AGENT
FOR ACCEPTANCE OF LEGAL PROCESS AND TO NOTIFY THE OTHER PARTY OF THE NAME AND ADDRESS OF SUCH AGENT. 
 (b) If the Parties
cannot resolve any dispute or claim arising under this Agreement, then no earlier than 10 days nor more than 60 days following written notice to the other Parties, any Party may initiate mandatory, non-binding mediation hereunder by giving a notice
of mediation (a “Mediation Notice”) to the other Parties to the dispute or claim. In connection with any mediation pursuant to this Section 5.2, the mediator shall be jointly appointed by the Parties to the dispute or
claim and the mediation shall be conducted in Denver, Colorado unless otherwise agreed to by the Parties to the dispute or claim. All costs and expenses of the mediator appointed pursuant to this section shall be shared equally by the Parties to the
dispute or claim. The then-current Model ADR Procedures for Mediation of Business Disputes of the Center for 

  
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Public Resources, Inc., either as written or as modified by mutual agreement of the Parties to the dispute or claim, shall govern any mediation pursuant to this section. In the mediation, each
Party to the dispute or claim shall be represented by one or more senior representatives who shall have authority to resolve any disputes. If a dispute or claim has not been resolved within 30 days after the receipt of the Mediation Notice by a
Party, then any Party to the dispute or claim may refer the resolution of the dispute or claim to litigation. 
 (c) Subject to
Section 5.2(b), each Party agrees that it shall bring any action or proceeding in respect of any claim arising out of or related to this Agreement, whether in tort or contract or at law or in equity, exclusively in any federal or state
courts located in Delaware and (i) irrevocably submits to the exclusive jurisdiction of such courts, (ii) waives any objection to laying venue in any such action or proceeding in such courts, (iii) waives any objection that such
courts are an inconvenient forum or do not have jurisdiction over it and (iv) agrees that, to the fullest extent permitted by law, service of process upon it may be effected by mailing a copy thereof by registered or certified mail (or any
substantially similar form of mail), postage prepaid, to it at its address specified in Section 5.3. The foregoing consents to jurisdiction and service of process shall not constitute general consents to service of process in the State
of Delaware for any purpose except as provided herein and shall not be deemed to confer rights on any Person other than the Parties. 
 5.3 Notice. All notices or requests or consents provided for by, or permitted to be given pursuant to, this Agreement must be in writing and must be given by e-mail or United States mail, addressed
to the Person to be notified, postpaid, and registered or certified with return receipt requested or by delivering such notice in person or by facsimile to such Party. Notice given by personal delivery or mail shall be effective upon actual receipt.
Notice given by e-mail or facsimile shall be effective upon actual receipt if received during the recipient’s normal business hours or at the beginning of the recipient’s next business day after receipt if not received during the
recipient’s normal business hours. All notices to be sent to a Party pursuant to this Agreement shall be sent to or made at the address set forth below or at such other address as such Party may stipulate to the other Parties in the manner
provided in this Section 5.3. 
 If to QEP or Field Services: 

QEP Resources, Inc. 
 1050 17th
Street, Suite 500 
 Denver, Colorado 80265 
 Attn: General Counsel 
 Facsimile: (303) 295-2190 

E-mail: Chris.Woosley@qepres.com 
 If to any Group Member: 
 QEP Midstream Partners, LP 

c/o QEP Midstream Partners GP, LLC, its General Partner 

1050 17th Street, Suite 500 
 Denver, Colorado 80265 
 Attn: General Counsel 

Facsimile: (303) 295-2190 
 E-mail: Chris.Woosley@qepres.com 

  
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 5.4 Entire Agreement. This Agreement constitutes the entire agreement of the Parties
relating to the matters contained herein, superseding all prior contracts or agreements, whether oral or written, relating to the matters contained herein. 
 5.5 Termination of Agreement. This Agreement, other than the provisions set forth in Article II hereof, may be terminated (a) by the written agreement of all of the Parties or
(b) by QEP or the Partnership immediately upon a Partnership Change of Control by written notice given to the other Parties to this Agreement. For the avoidance of doubt, the Parties’ indemnification obligations under Article II
shall, to the fullest extent permitted by law, survive the termination of this Agreement in accordance with their respective terms. 
 5.6 Amendment or Modification. This Agreement may be amended or modified from time to time only by the written agreement of all the Parties. Each such instrument shall be reduced to writing and
shall be designated on its face an “Amendment” or an “Addendum” to this Agreement. 
 5.7 Assignment.
No Party shall have the right to assign its rights or obligations under this Agreement without the consent of the other Parties; provided, however, that the Partnership Group may make a collateral assignment of this Agreement solely to
secure financing for the Partnership Group. 
 5.8 Counterparts. This Agreement may be executed in any number of
counterparts with the same effect as if all signatory parties had signed the same document and shall be construed together and shall constitute one and the same instrument. 
 5.9 Severability. If any provision of this Agreement shall be held invalid or unenforceable by a court or regulatory body of competent jurisdiction, the remainder of this Agreement shall remain in
full force and effect. 
 5.10 Further Assurances. In connection with this Agreement and all transactions contemplated by
this Agreement, each signatory party hereto agrees to execute and deliver such additional documents and instruments and to perform such additional acts as may be necessary or appropriate to effectuate, carry out and perform all of the terms,
provisions and conditions of this Agreement and all such transactions. 
 5.11 Rights of Limited Partners. The provisions
of this Agreement are enforceable solely by the Parties to this Agreement, and no Limited Partner or other interest holder of the Partnership shall have the right, separate and apart from the Partnership, to enforce any provision of this Agreement
or to compel any Party to this Agreement to comply with the terms of this Agreement. 
 [Remainder of page intentionally left
blank.] 

  
 12 

 IN WITNESS WHEREOF, the Parties have executed this Agreement on, and effective as of,
the Closing Date. 
  

			
	QEP Resources, Inc.
		
	By:	 	  

	Name:	 	
	Title:	 	
	
	QEP Field Services Company
		
	By:	 	  

	Name:	 	
	Title:	 	
	
	QEP Midstream Partners GP, LLC
		
	By:	 	  

	Name:	 	
	Title:	 	
	
	QEP Midstream Partners, LP
	
	By: QEP Midstream Partners GP, LLC, its general partner
		
	By:	 	  

	Name:	 	
	Title:	 	
	
	QEP Midstream Partners Operating, LLC
		
	By:	 	  

	Name:	 	
	Title:	 	

 [Signature page to Omnibus Agreement] 

 APPENDIX A 

Attached to and made part of that certain Omnibus Agreement, dated as of
[ — ], 2013, by and among QEP Resources, Inc., a Delaware corporation, QEP Field Services Company, a Delaware corporation, QEP Midstream Partners, LP, a Delaware limited partnership (the
“Partnership”), QEP Midstream Partners GP, LLC, a Delaware limited liability company and the general partner of the Partnership, and QEP Midstream Partners Operating, LLC, a Delaware limited liability company and wholly owned
subsidiary of the Partnership. 
 “1993 Gathering Agreement” means that certain gas
gathering agreement, dated September 1, 1993, between Questar Gas Company (f/k/a Mountain Fuel Supply Company) and QEP Field Services Company (f/k/a Questar Pipeline Company), as amended. 

“Administrative Fee” is defined in Section 3.2(a). 

“Agreement” has the meaning set forth in the preamble. 

“Affiliate” means, with respect to any Person, any other Person that directly or indirectly through
one or more intermediaries controls, is controlled by or is under common control with, the Person in question. As used herein, the term “control” means the possession, direct or indirect, of the power to direct or cause the direction of
the management and policies of a Person, whether through ownership of voting securities, by contract or otherwise. 
 “Assets” means the equity interests in the entities being conveyed, contributed or otherwise transferred to any Group Member pursuant to the Contribution Agreement
and any gathering pipelines, transportation pipelines, compressor stations, pump stations, metering stations, vehicles, related equipment, offices, real estate, contracts and other assets, or portions thereof owned by, leased by or necessary for the
operation of the business of any Group Member as of the Closing Date. 
 “Closing Date”
has the meaning set forth in the preamble. 
 “Confidential Information” means any
proprietary or confidential information that is competitively sensitive material or otherwise of value to a Party or its Affiliates and not generally known to the public, including trade secrets, scientific or technical information, design,
invention, process, procedure, formula, improvements, product planning information, marketing strategies, financial information, information regarding operations, consumer and/or customer relationships, consumer and/or customer identities and
profiles, sales estimates, business plans, and internal performance results relating to the past, present or future business activities of a Party or its Affiliates and the consumers, customers, clients and suppliers of any of the foregoing.
Confidential Information includes such information as may be contained in or embodied by documents, substances, engineering and laboratory notebooks, reports, data, specifications, computer source code and object code, flow charts, databases,
drawings, pilot plants or demonstration or operating facilities, diagrams, specifications, bills of material, equipment, prototypes and models, and any other tangible manifestation (including data in computer or other digital format) of the
foregoing; provided, however, that Confidential Information does not include information that a receiving Party can show (A) has been published 

 
or has otherwise become available to the general public as part of the public domain without breach of this Agreement, (B) has been furnished or made known to the receiving Party without any
obligation to keep it confidential by a third party under circumstances which are not known to the receiving Party to involve a breach of the third party’s obligations to a Party or (C) was developed independently of information furnished
or made available to the receiving Party as contemplated under this Agreement. 
 “Contribution
Agreement” means that certain Contribution, Conveyance and Assumption Agreement, dated as of the Closing Date, among QEP, Field Services, the General Partner, the Partnership and the Operating Company, together with the additional
conveyance documents and instruments contemplated or referenced thereunder, as such may be amended, supplemented or restated from time to time. 
 “Covered Environmental Losses” is defined in Section 2.1. 
 “Departing General Partner” means a former General Partner from and after the effective date of any withdrawal or removal of such former General Partner pursuant to
Section 11.1 or Section 11.2 of the Partnership Agreement. 
 “Environmental
Deductible” is defined in Section 2.5. 
 “Environmental Defect” is defined
Section 2.5. 
 “Environmental Laws” means all federal, state, and local laws,
statutes, rules, regulations, orders, judgments, ordinances, codes, injunctions, decrees, Environmental Permits and other legally enforceable requirements and rules of common law relating to pollution or protection of human health, natural
resources, wildlife and the environment or workplace health or safety including, without limitation, the federal Comprehensive Environmental Response, Compensation, and Liability Act of 1980, as amended, 42 U.S.C. §§9601
et seq., the Resource Conservation and Recovery Act of 1976, as amended, 42 U.S.C. §§6901 et seq., the Clean Air Act, as amended, 42 U.S.C. §§7401
et seq., the Federal Water Pollution Control Act, as amended, 33 U.S.C. §§1251 et seq., the Toxic Substances Control Act, as amended, 15 U.S.C. §§2601
et seq., the Oil Pollution Act of 1990, 33 U.S.C. §§2701 et seq., the Safe Drinking Water Act of 1974, as amended, 42 USC §§300f et
seq., the Hazardous Materials Transportation Act of 1994, as amended, 49 U.S.C. §§ 5101 et seq., and other environmental conservation and protection laws and the Occupational Safety and
Health Act of 1970, 29 U.S.C. §§ 651 et seq, and the regulations promulgated pursuant thereto, and any state or local counterparts, each as amended from time to time. 

“Environmental Permit” means any permit, approval, identification number, license, registration,
certification, consent, exemption, variance or other authorization required under or issued pursuant to any applicable Environmental Law, including applications for renewal of such permits in which the application allows for continued operation
under the terms of an expired permit. 
 “Field Services” has the meaning
set forth in the preamble. 
 “General and Administrative Services” is defined in Section 3.1.

  
 15 

 “General Partner” means QEP Midstream Partners GP,
LLC, a Delaware limited liability company, and its successors and permitted assigns that are admitted to the Partnership as general partner of the Partnership, in its capacity as general partner of the Partnership (except as the context otherwise
requires). 
 “Governmental Authority” means any federal, state, tribal,
foreign or local governmental entity, authority, department, court or agency, including any political subdivision thereof, exercising, or entitled to exercise, any administrative, executive, judicial, legislative, police, regulatory or taxing
authority or power of any nature, and including any arbitrating body, commission or quasi-governmental authority or self-regulating organization of competent authority exercising or enlisted to exercise similar power or authority.

 “Group Member” means a member of the Partnership Group. 

“Hazardous Substance” means (a) any substance, whether solid, liquid, gaseous, semi-solid, or
any combination thereof, that is designated, defined or classified as a hazardous waste, solid waste, hazardous material, pollutant, contaminant or toxic or hazardous substance, or terms of similar meaning, or that is otherwise regulated under any
Environmental Law, including, without limitation, any hazardous substance as defined under the Comprehensive Environmental Response, Compensation, and Liability Act, as amended, and including asbestos and lead-containing paints or coatings, and
(b) petroleum, oil, gasoline, natural gas, fuel oil, motor oil, waste oil, diesel fuel, jet fuel, and other refined petroleum hydrocarbons. 
 “Identification Deadline” means the third anniversary of the Closing Date. 
 “Indemnified Party” means the Party entitled to indemnification in accordance with Article II. 
 “Indemnifying Party” means the Party from whom indemnification may be sought in accordance with Article II. 

“Limited Partner” means, unless the context otherwise requires, each Person that becomes a
Limited Partner pursuant to the terms of the Partnership Agreement and any Departing General Partner upon the change of its status from General Partner to Limited Partner pursuant to Section 11.3 of the Partnership Agreement, in each
case, in such Person’s capacity as a limited partner of the Partnership; provided, however, that when the term “Limited Partner” is used herein in the context of any vote or other approval, such term shall not, solely for such
purpose, include any holder of any Incentive Distribution Right (solely with respect to its Incentive Distribution Rights and not with respect to any other limited partner interest held by such Person) except as may otherwise be required by law.

 “Losses” means any losses, damages, liabilities, claims, demands, causes of action,
judgments, settlements, fines, penalties, costs and expenses (including, without limitation, court costs and reasonable attorney’s and expert’s fees) of any and every kind or character, known or unknown, fixed or contingent.

 “Mediation Notice” is defined in Section 5.2(b). 

  
 16 

 “Operating Company” has the meaning set forth in the preamble.

 “Partnership” has the meaning set forth in the preamble. 

“Partnership Agreement” means the First Amended and Restated Agreement of Limited Partnership of
the Partnership, dated as of the Closing Date. 
 “Partnership Change of
Control” means QEP ceases to control, directly or indirectly, the General Partner. For purposes of this definition, “control” means the possession, directly or indirectly, of the power to direct or cause the
direction of the management and policies of the General Partner, whether through ownership of voting securities, by contract, or otherwise. 
 “Partnership Group” means, collectively, the Partnership and its Subsidiaries. 
 “Partnership License” is defined in Section 4.3. 

“Partnership Marks” is defined in Section 4.3. 

“Party” has the meaning set forth in the preamble. 

“Person” means an individual or a corporation, firm, limited liability company, partnership, joint
venture, trust, unincorporated organization, association, government agency or political subdivision thereof or other entity. 
 “QEP” has the meaning set forth in the preamble. 

“QEP Entities” means QEP and each of its Affiliates, other than the General Partner and the Group Members.

 “QEP License” is defined in Section 4.1. 

“QEP Marks” is defined in Section 4.1. 

“Representatives” is defined in Section 5.1(a). 

“Retained Assets” means all pipelines, processing facilities, treating assets, vehicles, other
midstream infrastructure, offices and related equipment, real estate, contracts and other related assets, or ownership interests or portions thereof owned by Field Services that were not directly or indirectly conveyed, contributed or otherwise
transferred to the Partnership Group pursuant to the Contribution Agreement or the other documents referenced in the Contribution Agreement. 
 “Subsidiary” means, with respect to any Person, (a) a corporation of which more than 50% of the voting power of shares entitled (without regard to the occurrence
of any contingency) to vote in the election of directors or other governing body of such corporation is owned, directly or indirectly, at the date of determination, by such Person, by one or more Subsidiaries of such Person or a combination thereof,
(b) a partnership (whether general or limited) in which such Person or a Subsidiary of such Person is, at the date of determination, a general or limited partner  

  
 17 

 
of such partnership, but only if more than 50% of the partnership interests of such partnership (considering all of the partnership interests of the partnership as a single class) is owned,
directly or indirectly, at the date of determination, by such Person, by one or more Subsidiaries of such Person, or a combination thereof; or (c) any other Person (other than a corporation or a partnership) in which such Person, one or more
Subsidiaries of such Person, or a combination thereof, directly or indirectly, at the date of determination, has (i) at least a majority ownership interest or (ii) the power to elect or direct the election of a majority of the directors or
other governing body of such Person. 

  
 18 

 Schedule A 
 Pre-Closing Litigation 
  

															
	 Matter Name
	  	Matter
Type	  	Party	  	Matter
Description	  	Case/Docket #	 	  	Court/Agency	  	State
	 Questar Gas Company v. QEP Field Services Company1
	  	Litigation	  	QEP Field
Services
Company	  	Contract Dispute	  	 	120902969	  	  	Third Judicial
District Court	  	UT

  

	1 	QEP Resources, Inc. and QEP Field Services Company shall not be obligated to indemnify QEP Midstream Partners, LP or any other Group Member for Losses incurred as a
result of a decrease in the annual gathering rate charged under the 1993 Gathering Agreement subsequent to the date that this litigation is settled or resolved by a final, binding and non-appealable court order. 

  
 Schedule A-1

 Schedule B 
 Environmental Remediation Locations 
  

			
	 Responsible Party
	  	 Description

	 Field Services
	  	South Baxter Groundwater Monitoring (Rock Springs, Wyoming)

  
 Schedule B-1

 Schedule C 
 General and Administrative Services 
 Pursuant to Section 3.1 

 

	(1)	Management services of QEP and its Affiliates (other than the General Partner) provided by employees who devote less than 50% of their business time to the business and
affairs of the Partnership. This cost includes QEP-stock based compensation expense. 

  

	(2)	Financial and administrative services (including treasury and accounting) 

  

	(3)	Information technology services—professional services 

  

	(4)	Legal services 

  

	(5)	Health, environmental, safety and security services (including third party security services) 

 

	(6)	Human resources services 

  

	(7)	Tax services 

  

	(8)	Procurement services 

  

	(9)	Investor relations; Government & public affairs services 

  

	(10)	Analytical & engineering services 

  

	(11)	Business development services 

 Pursuant to
Section 3.2 
 The fixed portion of the Administrative Fee for calendar year 2014, as described in Section 3.2, will be
$1,400,000. For the avoidance of doubt, the fixed portion of the Administrative Fee for the remainder of calendar year 2013 will be the same annual amount as calendar year 2014 pro-rated based on the number of days remaining in 2013 from the Closing
Date. 
 The portion of the Administrative Fee attributable to any marketing and transportation engineering services, information technology
services, administrative/office services, and public company expenses will be a variable amount based on the costs actually incurred by QEP and its Affiliates on behalf of the Partnership Group (other than any costs for which QEP and its Affiliates
are reimbursed pursuant to Section 3.3). The portion of the variable amount of the Administrative Fee attributable to any marketing and transportation engineering services described in the preceding sentence will be based on the costs
incurred by QEP and its Affiliates on behalf of the Partnership Group (other than any costs for which QEP and its Affiliates are reimbursed pursuant to Section 3.3). 
 Pursuant to Section 3.2(b) 
 The fixed portion of the Administrative Fee for calendar
year 2014 includes as a part thereof, the following amounts attributable to services provided by officers of the Partnership Group: 
  

							
	(1)	  	 Charles B. Stanley, Chairman of the Board, President and Chief Executive Officer
	  	$	 650,000	  
		  	 Richard J. Doleshek, Executive Vice President and Chief Financial Officer
	  	$	350,000	  
		  	 Perry H. Richards, Senior Vice President and General Manager
	  	$	400,000	  
		  	 Total
	  	$	1,400,000	  

  
 Schedule C-1EX-10.6

 Exhibit 10.6 
 GAS GATHERING AGREEMENT 
 Between 

MOUNTAIN FUEL SUPPLY COMPANY 

AND 
 QUESTAR PIPELINE COMPANY 

EFFECTIVE SEPTEMBER 1, 1993 

 GAS GATHERING AGREEMENT 

Table of Contents 
  

					
		
	 Recitals
	  	 	1	  
		
	 Article I – Dedication
	  	 	2	  
		
	 Article II – Gathering Service, Receipts and Deliveries
	  	 	2	  
		
	 Article III – Gathering Charges, Reimbursements and Credits
	  	 	3	  
		
	 (a) Gathering Rates
	  	 	3	  
	 (1) Through August 31, 1995
	  	 	3	  
	 (2) September 1, 1995—August 31, 1997
	  	 	4	  
	 (3) After August 31, 1997
	  	 	4	  
	 (b) Independent Facilities
	  	 	5	  
	 (c) New Well Connection Reimbursement
	  	 	5	  
		
	 Article IV – Effective Date and Term
	  	 	5	  
		
	 Article V – 1984 Gas Gathering Agreement
	  	 	5	  
		
	 Article VI – Government Authorization
	  	 	5	  
		
	 Article VII – Notices
	  	 	6	  
		
	 General Terms and Conditions
	  	 	GTC-1	  
	 1 DEFINITIONS
	  	 	GTC-1	  
	 2 SCHEDULING OF GAS RECEIPTS AND
DELIVERIES
	  	 	GTC-1	  
	 3 WARRANTY
	  	 	GTC-2	  
	 4 QUALITY
	  	 	GTC-2	  
	 5 MEASUREMENT
	  	 	GTC-2	  
	 6 FUEL GAS REIMBURSEMENT
	  	 	GTC-3	  
	 7 BILLING AND PAYMENT
	  	 	GTC-3	  
	 8 LIABILITY
	  	 	GTC-4	  
	 9 FORCE MAJEURE
	  	 	GTC-4	  
	 10 ASSIGNMENT
	  	 	GTC-5	  
	 11 MISCELLANEOUS
	  	 	GTC-5	  
		
	 Appendix A—Receipt and Delivery Points
	  	 	A-1	  
	 Appendix B—Cost of Service and Rate Derivation
	  	 	B-1	  
	 Appendix C—New Well Connection Reimbursement Under § III(c)
	  	 	C-1	  

 GAS GATHERING AGREEMENT 

This Agreement is entered into on this 11th day of October 1993, between Mountain Fuel, Supply Company (Mountain Fuel), 180 East First
South Street, Salt Lake City, Utah 84111, and QUESTAR PIPELINE COMPANY (QUESTAR), 79 South State Street, Salt Lake City, Utah 84111. Mountain Fuel and Questar are collectively referred to as “the Parties.” 

The Parties represent that: 
 1. On October 14, 1982, Mountain Fuel, Wexpro Company, the Utah Division of Public Utilities, the Utah Committee of Consumer Services and the Staff of the Public Service Commission of Wyoming entered
into an agreement (the Wexpro Agreement) that provides for the operation and development of certain oil-and-gas properties previously owned by Mountain Fuel and Wexpro Company. 
 2. Pursuant to the provisions of the Wexpro Agreement, Mountain Fuel owns or has the right to purchase certain supplies of natural gas that are produced by Wexpro Company. 

3. Mountain Fuel requires that certain of this Wexpro Agreement production be gathered and transported from points at which it is made
available or produced to Mountain Fuel’s retail distribution facilities. 
 4. Questar currently provides gas-gathering
services for Mountain Fuel for certain Wexpro Agreement gas in part pursuant to a Gas Gathering Agreement, dated July 1, 1984. 
 5. Up through August 31, 1993, Mountain Fuel purchased gas from Questar under Questar’s FERC firm sales Rate Schedule CD-1. This service incorporated, among other things, the field gathering of
certain gas supplies by Questar that were necessary to support firm sales service to Mountain Fuel. In partial support of its contractual obligation to provide CD-1 sales service, Questar has built or acquired, and maintains and operates, a
gathering system that is contiguous to its interstate transmission system. 
 6. Pursuant to Questar’s FERC gas tariff, firm
sales service was provided to Mountain Fuel under two Rate Schedule CD-1 service agreements executed by Mountain Fuel and Questar on March 1, 1991, and amended as of December 1, 1992, with a primary term that was to expire on June 30,
1999. 
 7. Pursuant to Federal Energy Regulatory Commission (FERC) Order No 636 and related FERC orders, Questar submitted a
comprehensive restructuring of its transportation, storage and gathering operations in FERC Docket No. RS92-9. Under the restructuring, approved by the FERC in Docket No RS92-9, Questar has (a) restructured its various services, and
(b) terminated its sales function by assigning to Mountain Fuel all the gas purchase agreements that supported Rate Schedule CD-1 sales service. 64 FERC ¶61,157 (Aug. 2, 1993). 

8. As a result of Questar’s restructuring, described above, Mountain Fuel requires gathering services to transport gas purchased by
Mountain Fuel from its purchase points to points on Questar’s transmission system. 

  
 -1-

 9. Pursuant to the Docket No. RS92-9 restructuring, Questar transports Mountain Fuel’s
gas on its transmission system under its FERC Gas Tariff. 
 10. Questar and Mountain Fuel wish to enter into a new agreement,
under which Questar will gather designated Wexpro Agreement gas and Mountain Fuel-purchased gas, including certain gas that formerly supported the Rate Schedule CD-1 sales service. This Agreement is intended to replace the July 1, 1984, Gas
Gathering Agreement and the gathering services formerly provided under Rate Schedule CD-1. 
 Therefore, the Parties agree as follows:

 Article I – Dedication 
 (a) Except as limited in §§ I(b) and I(d), the following categories of gas are dedicated under this Agreement, up to a combined maximum daily quantity (MDQ) of 322,812 Dth: (1) gas
purchased by or produced for Mountain Fuel pursuant to the Wexpro Agreement, and (2) gas purchased by Mountain Fuel at the wellhead or any other point on or near Questar’s gathering system that is upstream from the interstate transmission
system into which the gas will be delivered for Mountain Fuel’s account. 
 (b) The Parties acknowledge that Questar does
not provide exclusive service to Mountain Fuel in certain fields. Excluded from dedication under this Agreement, at Mountain Fuel’s discretion, is gas from (i) wells, producing at the initial effective date [defined in § IV(a)] and
gathered exclusively through facilities not owned by Questar, or (ii) wells completed in the future that would require reimbursement when evaluated under the criteria described in § III(c) of this Agreement. 

(c) Subject to the physical and contractual limitations of Questar’s system, Mountain Fuel may adjust its MDQ to reflect its
anticipated 12-month service requirement upon at least 180 days’ advanced written notice to Questar to be effective the next September 1. Any reduction under this provision will be effective no sooner than September 1, 1997.

 (d) After August 31, 1997, gas produced for or purchased by Mountain Fuel under the Wexpro Agreement will remain subject
to the terms of this Agreement In addition, any gas being purchased by Mountain Fuel from a third party and dedicated to this Agreement under §I(a)(2) on August 31, 1997, may, at Mountain Fuel’s option, continue to be dedicated under
this Agreement from year to year (September 1 through August 31) until Mountain Fuel’s underlying gas-purchase agreement expires or until Mountain Fuel, on 180 days’ prior written notice, terminates dedication on the next
August 31. The MDQ for use under this Agreement shall be accordingly modified to reflect the demonstrated deliverability of Wexpro Agreement gas and such third-party purchases. 

Article II – Gathering Service, Receipts and Deliveries 

(a) Questar shall gather up to the MDQ of 322,812 Dth/day of gas dedicated under this Agreement on a firm basis for delivery for Mountain
Fuel’s account into Questar’s transmission system or the pipelines of others connected to Questar’s gathering facilities. 

  
 -2-

 (b) The gathering service shall include essential wellhead gas conditioning, collection and
measurement through Questar’s gathering laterals, and field compression to enable delivery into connected pipelines. 
 (c)
At the request of Mountain Fuel, Questar shall install all necessary facilities to connect any new well to Questar’s then-existing gathering system. If requested, Questar shall provide an estimate of the costs to connect any new well under this
Agreement. Reimbursement of Questar’s costs, if any, shall be determined under § III(c). A “new well” is one that was not identified on Appendix A on the initial effective date. Except when prevented by a force majeure event,
Questar shall connect each new well from which gas is to be gathered under this Agreement within 30 days of the later of: 
 (1) Authorization from Mountain Fuel to connect the well, or 
 (2)
Receipt of all rights of way, permits and necessary authorizations. 
 (d) Mountain Fuel shall be permitted to change or add new
receipt and delivery points, within its MDQ, upon 10 days’ advance written notification to Questar, subject to available capacity at the desired points. 
 (e) Questar shall receive gas from Mountain Fuel at the receipt points listed on Appendix A. 
 (f) So long as Mountain Fuel does not exceed the MDQ under § II(a), Mountain Fuel may use any gathering receipt or delivery point on an interruptible basis at any time. 

(g) Mountain Fuel shall tender gas at pressures sufficient for delivery into Questar’s facilities against the existing pressures, but
not exceeding the maximum allowable operating pressures (MAOPs) of Questar’s facilities. 
 (h) Questar shall deliver
equivalent quantities of gas for Mountain Fuel’s account, less fuel and lost-and-unaccounted-for gas under § 6 of the General Terms and Conditions of this Agreement Delivery for Mountain Fuel’s account by Questar shall take place at
the delivery points listed on Appendix A. Questar shall deliver these volumes of gas at the existing pressures, but not exceeding the MAOP in Questar’s facilities at the delivery points. 

Article III – Gathering Charges, Reimbursements and Credits 

(a) Gathering Rates. 
 (1) Through August 31, 1995. From the initial effective date of this Agreement until August 31, 1995, rates for gathering services and their derivation are set forth in Appendix B and
were calculated on the basis of: 
  

	 	(i)	The annual cost of service assigned to Questar’s gathering function for calendar year 1992, as adjusted to establish rates in FERC Docket No. RS92-9, and reduced
by $2.5 million, which is representative of the value of gathering service rendered by Questar to third parties. 

  
 -3-

	 	(ii)	An assignment of 60% of the resultant annual gathering cost of service to reservation charges and 40% to usage charges. 

 

	 	(iii)	Billing determinants. Reservation charges: 322,812 Dth/day, Usage charges: 30,336,677 Dth (annual). 

(2) September 1, 1995—August 31, 1997. For the period from September 1, 1995, through
August 31, 1997, rates will be determined by an application of the methodology shown in Appendix B and will be based on: 
  

	 	(i)	The annual cost of service attributable to Questar’s gathering function for calendar year 1994, reduced by the actual revenues received by Questar for providing
gathering services to third parties during 1994, and adjusted in accordance with § 1 of Appendix B. 

  

	 	(ii)	An assignment of 60% of the resultant annual gathering cost of service to reservation charges and 40% to usage charges. 

 

	 	(iii)	Billing determinants. Reservation charge: 322,812 Dth/day, unless adjusted under § 1(c), Usage charge: the actual quantity gathered under this Agreement during
calendar 1994. 

 (3) After August 31, 1997. From September 1, 1997, until the
termination of this Agreement, rates will be redetermined each year, to be effective from September 1 through the following August 31, and will be based on: 
  

	 	(i)	An allocated portion of the annual cost of service for the prior calendar year that is attributable to Questar’s gathering function through which any gas dedicated
under § 1(d) flows during that year, in accordance with the methodology shown in Appendix B. The allocation under this subparagraph shall be the ratio of the annual deliverability of the volumes dedicated and flowing under § I(d) to
total deliverability of volumes flowing through the same facilities. 

  

	 	(ii)	An assignment of 60% of the resultant annual gathering cost of service to reservation charges and 40% to usage charges. 

 

	 	(iii)	Billing determinants. Reservation charge: according to the MDQ established under § 1(d). Usage charge: the actual quantity gathered under this Agreement
during the prior calendar year. 

  
 -4-

 (b) Independent Facilities. Questar may construct new gathering facilities that will
be operated independently of systems in operation on the initial effective date (i.e., facilities through which gas will flow that do not require the use of any part of Questar’s gathering system as it existed on the initial effective date). To
the extent these facilities are not operated to provide service for Mountain Fuel, the costs and revenues associated with or derived from these systems shall be excluded when determining Mountain Fuel’s gathering rates under this Agreement.

 (c) New Well Connection Reimbursement. For any new well to be connected to Questar’s gathering system at Mountain
Fuel’s request under this Agreement that was not subject to this Agreement on the initial effective date, Mountain Fuel shall reimburse Questar according to the formula set forth in Appendix C of this Agreement. 

Article IV – Effective Date and Term 
 (a) For all purposes in this Agreement, the “initial effective date” is September 1, 1993, the date of implementation of Questar’s restructuring in FERC Docket No. RS92-9. 

(b) This Agreement will become effective on the initial effective date and will remain in full force and effect so long as Mountain Fuel
is producing or purchasing gas pursuant to the Wexpro Agreement. 
 (c) Upon termination of this Agreement, deliveries and
receipts shall continue for as long as necessary to eliminate any imbalance in quantities of gas owed by either Party to the other. 
 Article V – 1984 Gas Gathering Agreement 
 Upon implementation of the
terms of this Agreement on the initial effective date, the July 1, 1984, Gas Gathering Agreement shall be terminated and superseded by this Agreement 
 Article VI – Government Authorization 
 (a) The Parties shall cooperate
to obtain any necessary governmental authorization to implement this Agreement. To the extent that a governmental agency with jurisdiction over the rates, facilities or services addressed by this Agreement imposes terms or conditions on this
Agreement that materially alter the rights or obligations of either party, this Agreement may be terminated or rescinded, as appropriate, by either party upon 15 days’ written notice to the other party. 

(b) The Parties have entered into this Agreement with the expectation that the facilities, services and rates that are the subject of this
Agreement do not come within the jurisdiction of the FERC. The Parties may, however, seek FERC approval of all or part of the Agreement to expedite its implementation. Any such action by the Parties will not be construed as a concession,
acquiescence or waiver by either party of any legal position concerning the regulation of gathering facilities, service or rates. 
 (c) If the rates for Questar’s gathering services are deemed to be subject to regulation by an administrative agency that prescribes rates other than those specified in this Agreement for any period
governed by this Agreement, the rates so specified shall be substituted for the rates 

  
 -5-

 
provided for in Article III, Any substitution under this provision will apply only to the extent that, and for the period during which, the administrative agency lawfully exercises rate
regulation over the services. Nothing in this provision will preclude either party from exercising its termination rights under § VI(a). 
 Article VII – Notices 
 All notices required in this agreement shall
be in writing and shall be considered as having been given if delivered personally, by mail or facsimile transmission to either Questar or Mountain Fuel at the designated address. Normal operating instructions can be delivered by telephone or any
electronic means. Notice of events of force majeure may be made by any electronic means and confirmed in writing. Monthly statements, payments, and any communications will be considered as delivered when mailed to the addresses listed below or to
such other address as either Party designates in writing: 
  

			
	 QUESTAR:

CONTACT ADMINISTRATOR
 Gathering Division
 Questar Pipeline Company

79 South State Street
 Salt Lake City, Utah
84111
	  	 MOUNTAIN FUEL:

Vice President, Gas Supply
 Mountain Fuel Supply Company
 141 East First South Street

Salt Lake City, Utah 84111

 THIS AGREMENT is entered into by the authorized representatives of the
Parties, whose signatures appear below. 
  

			
	 QUESTAR PIPELINE COMPANY:

 
 /s/ J. B. Carricaburu
 J. B. Carricaburu
 Vice President, Gas Supply & Marketing

Signature date: October 12, 1993
	  	 MOUNTAIN FUEL SUPPLY COMPANY:

 
 /s/ M. E. Benefield

M. E. Benefield
 Vice
President, Gas Supply
 Signature date: October 12, 1993

  
 -6-

 GENERAL TERMS AND CONDITIONS

 OF 
 GAS GATHERING AGREEMENT 

 

 1 DEFINITIONS 

1.1 “Firm,” as applied to service under this Agreement, refers to Questar’s contractual obligation to render the
specified service unless the obligation is otherwise waived, reduced, modified or terminated by force-majeure events. 
 1.2
“Interruptible” means subject to reduction, suspension or termination of the receipt or delivery of gas. 
 1.3
“Questar’s gathering system” refers to all facilities owned or operated by Questar for the purposes of conveying natural gas on all or a portion of its movement from the production of the gas at the wellhead to the delivery of the gas
into a pipeline that provides transportation of the gas in interstate commerce, as defined under § 1 of the Natural Gas Act. 
 1.4 Questar’s FERC Gas Tariff Vol. No.1. as amended and revised from time to time, will be used to define terms that are otherwise not defined in this Agreement. 

2 SCHEDULING OF GAS RECEIPTS AND DELIVERIES 

2.1 Scheduling. (All times are Mountain Standard or Daylight Time, as applicable.) If Mountain Fuel desires to have gas
gathered on gas day one of each month, Mountain Fuel must notify Questar’s nomination department no later than 10:00 a.m. three working days prior to the commencement of service. For all succeeding days of the month, Mountain Fuel shall notify
Questar’s nomination department no later than 10:00 a.m. each day of the quantity of natural gas it desires to have gathered from specific sources and receipt points commencing at 12:00 noon on the succeeding calendar day.

 By electronic means or in writing by 12:00 noon of the nomination day, Questar shall then
notify Mountain Fuel of the quantity that it can receive and deliver. Starting no later than 12:00 noon on the day following the calendar day of receipt of Mountain Fuel’s nomination, Questar shall commence to deliver an equivalent volume of
natural gas. All scheduling of deliveries of gas between Mountain Fuel and Questar shall take this scheduled timing difference into account. Upon written agreement or telephone agreement (to be confirmed in writing) between Questar and Mountain
Fuel, receipts and deliveries may commence earlier than provided by this schedule. 
 2.2 In connection with service provided
to Mountain Fuel under Questar’s FERC Rate Schedule NNT (no-notice service), Mountain Fuel may modify its nominations under this § 2 at any time. 
 2.3 Operating Information and Estimates. Upon request of Questar, Mountain Fuel shall from time to time submit its best estimates of the daily, monthly and annual quantities of gas it
expects to be gathered, together with such other operating data as Questar may require in order to schedule its operations. 

2.4 Operating Requirements. 
 2.4.1 Mountain Fuel shall use reasonable efforts to deliver and receive gas at uniform hourly and daily rates of flow. 
 2.4.2 Mountain Fuel shall deliver gas to Questar at the receipt points at a pressure sufficient to allow the gas to enter Questar’s gathering system. Questar shall not be required to compress natural
gas into its system. If requested by Questar, Mountain Fuel shall provide equipment acceptable to Questar at each receipt point to prevent overpressuring Questar’s system.

 

  
 GTC-1

 2.4.3 Questar shall deliver gas at each transfer point to the receiving party at the
pressure in Questar’s system after required measurement, flow control or regulation. 
 2.5 Limitations On
Questar’s Gathering Obligations. 
 2.5.1 On any day, Questar shall not be obligated to deliver to Mountain Fuel a
quantity of gas different from the equivalent volume received from Mountain Fuel during the same day, as adjusted under § 6 below. 
 2.5.2 For gathering service provided under this Agreement, Questar shall not be obligated to receive from or deliver to Mountain Fuel a quantity of gas in excess of the MDQ, unless Mountain Fuel has
requested and Questar has agreed to provide overrun service. 
 3 WARRANTY 

Mountain Fuel warranties title to and the right to deliver and use the gas shipped or committed to use under this Agreement and further
warrants that the gas is free from all liens and adverse claims, including tax liens. Mountain Fuel will have the obligation to make settlements for all royalties due and payments owed to Mountain Fuel’s mineral and royalty owners. Mountain
Fuel agrees to indemnify Questar and save it harmless from all suits, actions, claims, debts, accounts, damages, costs, losses, liens, license fees, and expenses which arise from Mountain Fuel’s ownership or control of the gas. 

4 QUALITY 
 4.1 Questar may refuse to receive gas from Mountain Fuel if the gas does not meet the quality specifications of the party to whom the gas is to be delivered (including the interstate transmission
facilities of Questar) for the following: hydrogen sulfide and other forms of sulfur; inert substances; liquids; dust, gums, gum-forming constituents, dirt, impurities or other solid or liquid matter that might interfere with the merchantability of
the gas; oxygen; or water vapor. 

 4.2 The gas tendered to Questar at each receipt point shall contain a gross heating value
of at least 950 Btu per cubic foot. 
 4.3 The gas tendered to Questar at each receipt point shall be at a temperature between
35°F. and 120°F. 
 4.4 If the gas tendered to Questar under this Agreement fails to meet the specifications, as
described in ¶¶ 4.1, 4.2 and 4.3, Questar shall notify Mountain Fuel and may, at its option, refuse to accept further receipt of gas pending correction. 
 4.5 Mountain Fuel shall indemnify Questar and hold it harmless from all suits, actions, regulatory proceedings, damages, costs, losses and expenses (including reasonable attorney fees) arising out of the
failure of the gas tendered by Mountain Fuel to conform to the quality specifications, including any injury or damage done to Questar’s facilities. 
 4.6 Acceptance of gas that does not meet quality specifications is at Questar’s option. Acceptance of the gas does not constitute any waiver of Questar’s right to refuse to accept similarly
nonconforming gas. 
 5. MEASUREMENT 
 5.1 The volumes of gas delivered to Questar by Mountain Fuel shall be measured by Questar according to its current FERC tariff. The meters shall be installed and tested and any discrepancies in the
volumes measured shall be resolved according to Questar’s current FERC tariff. 
 5.2 All claims of any party as to the
quantity of gas tendered and delivered must be submitted in writing by the party within 180 days from the date of commencement of the claimed discrepancy. 
 5.3 Either party may, at its option and expense, install and operate check measuring equipment, provided that the equipment is installed in a way that does not interfere with the operations of the other
party. However, 

 

  
 GTC-2

 
measurement of gas for the purpose of this Agreement shall be measured under ¶ 15.1. Either party’s check meters will be subject at all reasonable times to inspection and examination by
a representative of the other party, but the reading, calibration, adjustment, and changing of charts will be done only by the party installing the check meters. 
 5.4 Each party shall, upon request, furnish to the other party at the earliest possible time all charts upon which it has based any statement. Each party shall return to the other party all charts after a
30-day period. Each party shall have access to the other party’s records and books at all reasonable business hours so far as they affect measurement and settlement for the gas received or delivered. 

5.5 Questar shall integrate the charts and data obtained by the metering and measurement of the gas gathered under this Agreement. Upon
written request, Questar shall furnish Mountain Fuel copies of measurement charts used in compiling any monthly statements. Mountain Fuel may compute the volume of gas from Questar’s charts and data. If Mountain Fuel’s computation of the
volume of gas varies from Questar’s computation by less than the greater of 2% or 50 Dth, Questar’s computation will be deemed correct. If Mountain Fuel’s computation differs from Questar’s by more than the greater of 2% or 50
Dth, then Questar shall reintegrate and redetermine the volume of gas purchased. If Questar’s second computation varies from Mountain Fuel’s computation by less than the greater of 2% or 50 Dth, Mountain Fuel’s computation will be
deemed correct. However, if Questar’s second computation still varies from Mountain Fuel’s computation by more than the greater of 2% or 50 Dth, then Questar’s initial computation will be deemed correct. 

6 FUEL GAS REIMBURSEMENT 
 6.1 Fuel Reimbursement. For all gas tendered by Mountain Fuel under this Agreement, Mountain Fuel shall reimburse Questar with gas provided in-kind for:

 6.1.1 The actual fuel used to treat or condition the gas to permit compliance with any
quality requirements under § 4 and compressor fuel required to effect receipt or delivery of the gas, and 
 6.1.2
Mountain Fuel’s proportionate share of lost-and-unaccounted-for gas on Questar’s gathering system. 
 6.2
Nomination Adjustment. Mountain Fuel’s total nominations into Questar’s gathering system must include the amount of gas required to reimburse Questar for fuel use and lost-and-unaccounted-for gas.

 7 BILLING AND PAYMENT 

7.1 Monthly Bill. 
 7.1.1 On the 20th day of each month, Questar shall bill Mountain Fuel any applicable reservation charges for the current month. 
 7.1.2 By the 25th day of each month, Questar shall bill Mountain Fuel usage charges for all volumes of gas gathered for delivery during the immediately previous month as well as any other applicable
charges. If actual quantities are not reasonably available, Questar may use estimates of the quantity of gas gathered for Mountain Fuel in computing the amounts due. Any necessary adjustment shall be made in later billings for differences between
the estimated and actual qualities 
 7.2 Access to Billing Data. Both Parties will have the right to
examine at reasonable times books, records and charts of the other to the extent necessary to verify the accuracy of any statement, charge or computation made under or pursuant to any of the provisions of such statement. 

7.3 Payment. Mountain Fuel shall pay Questar on or before the last day of each month or within 10 days of the date the
bill is received by Mountain Fuel under this section, whichever is later. 

 

  
 GTC-3

 7.4 Late Payments. 

7.4.1 Should Mountain Fuel fail to make timely payment of any part of the amount of any bill, the unpaid amount will be deemed late, and
Questar shall charge interest from the date payment is due until the actual date of receipt of payment. The interest will be compounded quarterly until paid. 
 7.4.2 Interest will be calculated at the rate prescribed for the applicable period by 18 C.F.R. § 154.67(c). 
 7.4.3 Questar shall bill Mountain Fuel for any interest due in its next billing to Mountain Fuel, and Mountain Fuel shall pay the amount due according to this section. Questar may waive the interest on
late payment made within Eve days of the due date. If an uncontested bill remains unpaid for 30 days or more after payment is due, Questar, in addition to any other remedy it may have, may, after giving Mountain Fuel 15 days’ written notice,
suspend further receipt and delivery of gas for Mountain Fuel until full payment for all service rendered to date is made. 

7.5 Contested Bills. Any billing or statement may be contested within 180 days from its receipt by Mountain Fuel. If
Mountain Fuel (i) contests all or any part of a bill in good faith, (ii) pays to Questar the amounts it concedes to be correct, and (iii) within 30 days of a demand made by Questar furnishes a surety bond guaranteeing payment in the
amount of the disputed portion of the bill, then Questar may not suspend further delivery of gas unless default has occurred under the conditions of the bond. No payment by Mountain Fuel of the amount of a disputed bill will prejudice its right to
claim an adjustment of the disputed bill. Mountain Fuel shall pay interest of disputed portions of a bill for which it has withheld payment, and which ultimately are found due. 

7.6 Billing Errors. If an error is discovered in the amount of any bill, the error shall be adjusted within 30 days of the
determination that an adjustment is required, provided that the

 
claim for adjustment will have been made within 180 days from the date of the bill. If it is determined that Mountain Fuel has been overcharged and has paid the statement containing the
overcharge, then, within 30 days after the final determination, Questar shall refund the amount overcharged with interest. If it is determined that Mountain Fuel has been undercharged, Mountain Fuel shall pay the amount undercharged with interest.
The rate of any interest to be paid by either party under this provision will be governed by 18 C.F.R. § 154.67(c). In the event that any portion of a statement is in dispute, payment of the disputed portion will not be deemed a waiver of the
right to contest such disputed portion in any forum having jurisdiction. 
 8 LIABILITY 

Each party assumes full responsibility and liability arising from the operation of the facilities it owns and agrees to hold the other
party harmless from any liability whatever arising from the owning party’s installation, ownership or operation of its facilities. 
 9
FORCE MAJEURE 
 9.1 Definition. The term “force majeure” as employed
in this agreement will mean acts of God, strikes, lockouts or other labor or industrial disturbances, acts of the public enemy, wars, blockades, insurrections, riots, epidemics, landslides, lightning, earthquakes, fires, tornadoes, severe weather,
storms floods, washouts, arrest and restraint from rulers of people, necessity for compliance with any court order, law ordinance or regulations promulgated by a governmental authority having jurisdiction, civil disturbances, explosions, breakage or
accident to machinery, instrumentation, or lines of pipe, sudden partial or sudden entire failing of wells, freezing of wells or pipelines, inability to secure right-of-way, materials, supplies or labor, including inability or failure to obtain
materials and 

 

  
 GTC-4

 
supplies due to governmental regulations, and causes of like or different kind, whether enumerated in this agreement or not, and not within the control of the parry claiming force
majeure, and which by the exercise of due diligence such party is unable to overcome. 
 9.2
Notice. If either party is rendered wholly or partially unable to carry out its obligations under this Agreement due to force majeure, the party shall give written notice describing the event of force majeure as soon as is reasonably
possible after the occurrence. The obligations of the Parties, other than to make payments of amounts due so far as they are affected by such force majeure, will be suspended during the continuance of the event of force majeure, but for no longer
period. The affected party shall remedy the event of force majeure in a commercially reasonable manner. Nothing in this Agreement shall be construed to require either party to settle a strike or labor dispute against its better judgment. 

10 ASSIGNMENT 
 All rights
and duties under this Agreement shall inure to and be binding upon the successors and assignees of the Parties. No

 
conveyance or transfer of any interest of either party, except a transfer to an affiliate, will be binding upon the other party until the other party has been furnished with notice and a true
copy of the conveyance or transfer. The successor or assignee agrees in writing to be bound by all the terms and conditions of the agreement and that the successor or assignee assumes all the obligations under this Agreement. 

11 MISCELLANEOUS 
 11.1 A waiver by either party of any one or more defaults by the other party shall not operate as a waiver of any future default. 
 11.2 This Agreement, including any appendices and these General Terms and Conditions, contains the entire understanding of the Parties and may only be amended by an instrument in writing signed by the
Parties. 
 11.3 In interpreting this Agreement, the recitals will be considered as part of this Agreement and not as
surplusage. 
 11.4 This Agreement shall be construed under the laws of Utah.

 

  
 GTC-5

 APPENDIX A 

TO THE 
 GAS GATHERING AGREEMENT 

DATED: OCTOBER 11, 1993 
 BETWEEN 
 MOUNTAIN FUEL
SUPPLY COMPANY 
 AND 

QUESTAR PIPELINE COMPANY 

RECEIPT POINTS 
 The
interconnection of Questar’s gathering facilities and the production facilities associated with the following wells: 
 Receipt points
associated with Wexpro Agreement. 
  

					
	Well
Num	  	Form
Code	  	Well Name
	02259	  	2896	  	N BAX UP 11-19-104 1
	00734	  	2168	  	ES LAUZER A 1
	00735	  	2896	  	ES LAUZER B 2
	00738	  	3128	  	C R HETZLER 2
	01029	  	2168	  	WE MULLEN A 2
	00999	  	2896	  	SO BAXTER UNIT 15
	01014	  	2168	  	SO BAXTER UNIT 2
	01016	  	2168	  	SO BAXTER UNIT 6
	01019	  	2168	  	WT NIGHTINGALE A 1
	01018	  	2168	  	A COOPER 1
	00686	  	1600	  	JACKKNIFE SPRINGS 2
	00685	  	1600	  	JACKKNIFE SPRINGS 1
	01837	  	2168	  	SO BAXTER UNIT 17
	01036	  	2896	  	SO BAXTER UNIT 12
	01033	  	2168	  	SO BAXTER UNIT 8
	01026	  	2168	  	MF WHELAN 1
	01025	  	2168	  	UP 21-16-104 2
	01022	  	2168	  	U P 11-16-104-1
	02124	  	2168	  	CLAY BASIN UNIT 62
	00402	  	2168	  	CLAY BASIN UNIT 23
	00401	  	2168	  	CLAY BASIN UNIT 22
	00400	  	2168	  	CLAY BASIN UNIT 20
	00399	  	2168	  	CLAY BASIN UNIT 19
	00398	  	2168	  	CLAY BASIN UNIT 18
	00397	  	2168	  	CLAY BASIN UNIT 17
	00396	  	2168	  	CLAY BASIN UNIT 16
	00504	  	0912	  	F WILSON B UNIT 2

  
 A-1

					
	Well
Num	  	Form
Code	  	Well Name
	00504	  	0784	  	F WILSON B UNIT 2
	00504	  	0784	  	F WILSON B UNIT 2
	00500	  	0784	  	F WILSON A 18
	00499	  	0784	  	E HIA F WILSON A17
	00494	  	0912	  	F WILSON B 12
	00494	  	0912	  	F WILSON B 12
	00491	  	0784	  	F WILSON A 9
	00536	  	0784	  	W W WILSON A 2
	00535	  	0784	  	W W WILSON A 1
	00534	  	0912	  	W W WILSON A UNIT 6
	00533	  	0912	  	NEWBERGER B UNIT 5
	00532	  	0912	  	W W WILSON A UNIT 4
	00531	  	0784	  	W W WILSON A UNIT 3
	00531	  	0784	  	W W WILSON A UNIT 3
	00522	  	0912	  	F WILSON B 25
	02131	  	0912	  	E HIA MW NEWBERGER 7
	02059	  	0912	  	E. HIA F. WILSON 26
	01404	  	3944	  	HIAWATHA DEEP 2
	01403	  	3944	  	HIAWATHA DEEP 3
	00549	  	3944	  	HIAWATHA DEEP 1
	00547	  	0912	  	AMELIA HORROCKS 2
	00544	  	0912	  	MW NEWBERGER A 6
	00543	  	0784	  	MW NEWBERGER C 5
	01241	  	0912	  	WM WHEELER A 3
	01240	  	0912	  	WM WHEELER A 2
	01240	  	0912	  	WM WHEELER A 2
	01240	  	0784	  	WM WHEELER A 2
	01240	  	0784	  	WM WHEELER A 2
	01238	  	0912	  	W B LASHAR A 4
	01238	  	0912	  	W B LASHAR A 4
	01236	  	0784	  	W B LASHAR A 2
	01113	  	1600	  	TRAIL UNIT 6
	01111	  	1600	  	TRAIL UNIT 4
	01110	  	1600	  	TRAIL UNIT 3
	01109	  	1600	  	TRAIL UNIT 2
	00854	  	1600	  	PIONEER UNIT 8
	00854	  	1600	  	PIONEER UNIT 8
	00674	  	2896	  	KINNEY UNIT 6
	00669	  	2896	  	KINNEY UNIT 5
	00927	  	0912	  	J C DONNELL B 12
	00926	  	0912	  	J C DONNELL A 11
	00925	  	0912	  	POWDER WASH GOVT 2
	00924	  	0912	  	POWDER WASH GOVT 1
	00923	  	0912	  	B W MUSSER B 20

  
 A-2

					
	Well
Num	  	Form
Code	  	Well Name
	00922	  	0912	  	B W MUSSER B 19
	00921	  	0912	  	B W MUSSER B 18
	00920	  	0912	  	B W MUSSER B 17
	00919	  	0912	  	B W MUSSER A 16
	00918	  	0912	  	B W MUSSER B 15
	00917	  	0912	  	B W MUSSER A 14
	00916	  	0912	  	B W MUSSER B 13
	00912	  	0912	  	HAL STEWART A 1
	00911	  	0912	  	J C DONNELL B 10
	00910	  	0912	  	J C DONNELL B 9
	00910	  	0912	  	J C DONNELL B 9
	00908	  	0784	  	J C DONNELL B 7
	00906	  	0912	  	JC DONNELL B 5
	00906	  	0912	  	JC DONNELL B 5
	00904	  	0784J	  	J C DONNELL B 3
	00903	  	0912	  	B W MUSSER B 11
	00902	  	0912	  	B W MUSSER B 10
	00901	  	0784	  	B W MUSSER A 9
	00899	  	0784	  	B W MUSSER B 7
	00898	  	0784	  	B W MUSSER B 6
	00897	  	0784	  	B W MUSSER B 5
	00896	  	0784	  	B W MUSSER A 4
	00895	  	0912	  	B W MUSSER B 21
	00894	  	0784	  	B W MUSSER A 2
	00893	  	0784	  	B W MUSSER A 1
	00892	  	0912	  	CARL ALLEN A 20
	00891	  	0912	  	CARL ALLEN A 19
	00889	  	0784	  	CARL ALLEN 17
	00887	  	0784	  	CARL ALLEN B 15
	00886	  	0784	  	CARL ALLEN A 14
	00884	  	0784	  	CARL ALLEN B 12
	00883	  	0912	  	CARL AI-LEN A 11
	00882	  	0784	  	CARL ALLEN B 10
	00879	  	0912	  	CARL ALLEN B 7
	00878	  	0912	  	CARL ALLEN B 6
	00876	  	0784	  	CARL ALLEN B 4
	00876	  	0784	  	CARL ALLEN B 4
	00875	  	0784	  	CARL ALLEN B 3
	00662	  	0912	  	JACKS DRAW UNIT 8
	00661	  	0912	  	JACKS DRAW UNIT 5
	00659	  	0784	  	JACKS DRAW UNIT 4
	00658	  	0912	  	JACKS DRAW UNIT 15
	00657	  	0912	  	JACKS DRAW UNIT 13
	00656	  	0912	  	JACKS DRAW UNIT 9

  
 A-3

					
	Well
Num	  	Form
Code	  	Well Name
	00655	  	0912	  	JACKS DRAW UNIT 3
	00654	  	0912	  	JACKS DRAW UNIT 2
	00006	  	0912	  	ACE UNIT WELL 7
	00003	  	0912	  	ACE UNIT WELL 3
	00002	  	0912	  	ACE UNIT WELL 2
	00001	  	0912	  	ACE UNIT WELL 1
	01096	  	0912	  	NIGHTINGALE B-1
	01085	  	1600	  	STATELAND 3-11-101 2
	01081	  	1600	  	DONNELL GOV’T 15
	01080	  	1600	  	NIGHTINGALE GOV’T 14
	01079	  	1600	  	NIGHTINGALE GOV’T 12
	01078	  	1600	  	DONNELL GOV’T 10
	01077	  	0912	  	HETZLER GOV’T 9
	01076	  	1600	  	ROBERTS GOV’T 8
	01075	  	1600	  	NIGHTINGALE GOV’T 6
	03360	  	8500	  	MOSU SALES GAS MM
	03975	  	2168	  	LAWLER FED 2-30
	04001	  	2168	  	LANSDALE FED 28-3
	03829	  	2168	  	LANSDALE FED 28-2
	03959	  	2168	  	LANSDALE FED 10-3
	03830	  	2168	  	LANSDALE FED 4-2
	01031	  	2168	  	SL 36-18-104 2
	04013	  	2168	  	BRUFF UNIT 28
	00954	  	2416	  	M F FEDERAL 8-1
	00700	  	2416	  	LOWER HORSE DR 12-1
	00699	  	2416	  	LOWER HORSE DR 11-4
	00698	  	2416	  	LOWER HORSE DR 10-2
	00697	  	2416	  	LOWER HORSE DR 10-1
	00695	  	2416	  	LOWER HORSE DR 12-2
	00694	  	2416	  	LOWER HORSE DR 11-1
	02109	  	8500	  	HORSESHOE BND MS 205
	02291	  	0784	  	ISLAND UNIT 30
	02290	  	0784	  	ISLAND UNIT 29
	02289	  	0784	  	ISLAND UNIT 32
	02245	  	0784	  	ISLAND UNIT 27
	02244	  	0784	  	ISLAND UNIT 26
	02243	  	0784	  	ISLAND UNIT 25
	02130	  	0784	  	ISLAND UNIT 24
	02129	  	0784	  	ISLAND UNIT 23
	02128	  	0784	  	ISLAND UNIT 22
	02127	  	0784	  	ISLAND UNIT 20
	02126	  	0784	  	ISLAND UNIT 19
	02113	  	0784	  	ISLAND UNIT 21
	02092	  	0784	  	ISLAND UNIT 17

  
 A-4

					
	Well
Num	  	Form
Code	  	Well Name
	02091	  	0784	  	ISLAND UNIT 18
	01418	  	0784	  	ISLAND UNIT 12
	01417	  	0784	  	ISLAND UNIT 13
	01416	  	0784	  	ISLAND UNIT 11
	01415	  	0784	  	ISLAND UNIT 15
	01414	  	0784	  	ISLAND UNIT 14
	00681	  	0784	  	ISLAND UNIT 10
	00680	  	0784	  	ISLAND UNIT 9
	00677	  	0784	  	ISLAND UNIT 3
	02300	  	5632	  	BUG 15 LP
	02299	  	5632	  	BUG 13 LP
	02149	  	5680	  	PATTERSON CNYN 3 LP
	02143	  	5632	  	BUG 9 LP
	02140	  	5680	  	BUG 16 LP
	02140	  	5680	  	BUG 16 LP
	02139	  	5632	  	BUG 14 LP
	01838	  	5680	  	PATTERSON UNIT 5 WD
	01687	  	5680	  	PATTERSON UNIT 3 LP
	01683	  	5632	  	BUG 17 LP
	01682	  	5632	  	BUG 10 LP
	01681	  	5632	  	BUG 14 HP
	01680	  	5632	  	BUG 4 LP
	00851	  	5680	  	PATTERSON CNYN 3 HP
	00842	  	5680	  	PATTERSON UNIT 1 LP
	00431	  	5680	  	PATTERSON CANYON 1
	03328	  	2416	  	MOUNTAIN FUEL 3-1
	03327	  	2416	  	MOUNTAIN FUEL 26-2
	03326	  	2416	  	MOUNTAIN FUEL 23-2
	02082	  	2416	  	MIKULICH MFS 28-1
	00150	  	2416	  	BIG HORSE DRAW 35-1
	00120	  	2416	  	BIG HORSE DRAW 2-1
	02147	  	2168	  	FOX FED 1-8 LP
	02146	  	2168	  	FOX FED 1-5 LP
	01069	  	2168	  	SPRHD RANCH 18 HP
	01057	  	2168	  	SPRHD RANCH 6 HP
	01055	  	2168	  	SPRHD RANCH lA LP
	00592	  	2168	  	JUDSON FED 1-11 HP
	00578	  	2896	  	SPRHD RANCH 3
	00578	  	2896	  	SPRHD RANCH 3
	00430	  	8520	  	CRESTON FED 22-1
	00430	  	8520	  	CRESTON FED 22-1
	03571	  	0784	  	CARL ALLEN 2
	03048	  	0784	  	J C DONNELL B 4
	02566	  	0784	  	JC DONNELL B 8

  
 A-5

					
	Well
Num	  	Form
Code	  	Well Name
	02383	  	0784	  	ACE UNIT 5
	02308	  	0784	  	P W H. STEWART 4
	02308	  	0784	  	P W H. STEWART 4
	02302	  	0784	  	POWDER WSH STEWART 2
	02293	  	0784	  	PW CARL ALLEN 16 GVT
	00939	  	0912	  	POWDER WASH 20-1
	00929	  	0912	  	J C DONNELL A 1
	00928	  	0912	  	J A LEE 1
	01074	  	1600	  	DONNELL GOV’T 4
	01073	  	1600	  	DONNELL GOV’T 3
	01072	  	1600	  	DONNELL GOV’T 2
	01071	  	1600	  	DONNELL GOV’T 1
	02118	  	1600	  	TRAIL UNIT 12
	01721	  	8520	  	KINNEY UNIT WELL 3
	01479	  	1600	  	TRAIL UNIT 13
	01114	  	1600	  	TRAIL UNIT 8
	00668	  	2896	  	KINNEY UNIT 4
	00667	  	2896	  	KINNEY UNIT 2
	00665	  	1600	  	PIONEER UNIT 4
	00664	  	1600	  	PIONEER UNIT 3
	00663	  	3944	  	KINNEY UNIT 1
	00663	  	3944	  	KINNEY UNIT 1
	01259	  	0912	  	W B LASHAR A 5
	01259	  	0912	  	W B LASHAR A 5
	03402	  	0912	  	F WILSON 20
	03402	  	0912	  	F WILSON 20
	03349	  	0912	  	G KUYKENDALL #9
	03348	  	0912	  	F WILSON 28 ES
	02310	  	0912	  	STATE LAND 6
	02309	  	0912	  	KUYKENDALL 10
	02309	  	0912	  	KUYKENDALL 10
	02132	  	0912	  	E HIA MW NEWBERGER 8
	00543	  	0784	  	MW NEWBERGER C 5
	00542	  	0784	  	MW NEWBERGER B 4
	00541	  	0784	  	MW NEWBERGER A 3
	00540	  	0912	  	MW NEWBERGER D 2
	00540	  	0912	  	MW NEWBERGER D 2
	00539	  	0784	  	MW NEWBERGER A 1
	00538	  	0912	  	W W WILSON B 4
	00537	  	0912	  	W W WILSON C 3
	00520	  	0912	  	F WILSON B 24
	00517	  	0784	  	K S WHITFORD 1
	00516	  	0912	  	G KUYKENDALL A 8
	00511	  	0912	  	ST LAND 37-12-100 5

  
 A-6

					
	Well
Num	  	Form
Code	  	Well Name
	00510	  	0784	  	ST LAND 37-12-100 4
	00508	  	0784	  	ST LAND 37-12-100 2
	00505	  	0912	  	F WILSON A 22
	00504	  	0912	  	F WILSON B UNIT 2
	00488	  	0784	  	F WILSON B 6
	00488	  	0784	  	F WILSON B 6
	00485	  	0784	  	F WILSON B 3
	00484	  	0784	  	F WILSON A 2
	00483	  	0912	  	F WILSON A 1
	00483	  	0912	  	F WILSON A 1
	00483	  	0912	  	F WILSON A 1
	02133	  	2168	  	CLAY BASIN UNIT 61
	00395	  	2168	  	CLAY BASIN UNIT 15
	00394	  	2168	  	CLAY BASIN UNIT 14
	00393	  	2168	  	CLAY BASIN UNIT 13
	00392	  	2168	  	CLAY BASIN UNIT 12
	00391	  	2168	  	CLAY BASIN UNIT 9
	00390	  	2168	  	CLAY BASIN UNIT 8
	00389	  	2168	  	CLAY BASIN UNIT 1
	00386	  	2168	  	CLAY BASIN UNIT 7
	01021	  	2168	  	AJ POSTON A 3
	01015	  	2168	  	SO BAXTER UNIT 3
	01000	  	2896	  	SO BAXTER UNIT SR 1
	01030	  	2168	  	SL 10-17-104 1
	00738	  	3128	  	C R HETZLER 2
	00735	  	2896	  	ES LAUZER B 2
	00185	  	2896	  	BUTCHERKNIFE SPR 6
	00231	  	2896	  	BUTCHERKNIFE SPR 5
	00619	  	2896	  	HENRY FORK UNIT 1
	00231	  	2896	  	BUTCHERKNIFE SPR 5
	01410	  	2896	  	HENRY FORK UNIT 10
	01871	  	2896	  	HENRY FORK UNIT 14
	02121	  	2896	  	HENRY FORK UNIT 9A
	00197	  	2168	  	CHAMPLIN 149 B-1
	00206	  	2168	  	BRUFF UNIT 8
	00205	  	2896	  	LANSDALE FED 4-1
	00217	  	2168	  	BRUFF UNIT 4
	00216	  	2168	  	BRUFF UNIT 6
	00215	  	2896	  	LANSDALE FED 10-1
	00213	  	2168	  	BRUFF UNIT 9
	00212	  	2168	  	BRUFF UNIT 5
	00211	  	2168	  	BRUFF UNIT A-1
	00209	  	2168	  	BRUFF UNIT 3
	00208	  	2168	  	BRUFF UNIT 2

  
 A-7

					
	Well
Num	  	Form
Code	  	Well Name
	01474	  	2168	  	SHUTE CREEK 9
	01287	  	2168	  	WHISKEY BUTTES 3
	00752	  	2168	  	CLIFTON FEDERAL 28-1
	00553	  	2168	  	HARRINGTON FED 1
	00447	  	2168	  	HALEY FEDERAL 4-1
	00439	  	2168	  	BRUFF FEDERAL 2-26
	00429	  	2168	  	CLIFTON FEDERAL 34-1
	00409	  	2896	  	PANDO FEDERAL 32-1
	00408	  	2896	  	W G MCNAMARA (NCT) 1
	00408	  	2896	  	W G MCNAMARA (NCT) 1
	00408	  	2168	  	W G MCNAMARA (NCT) 1
	00408	  	2168	  	W G MCNAMARA (NCT) 1
	00373	  	2896	  	WYO ‘U’ (NCT 2) 1
	00261	  	2168	  	DONLEY (NCT #1) 1
	00229	  	2896	  	DONLEY (NCT #2) 1
	00229	  	2896	  	DONLEY (NCT #2) 1
	00453	  	2168	  	DRY PINEY UNIT 1
	03991	  	2896	  	MFS FEE 10-3
	03991	  	2896	  	MFS FEE 10-3
	03960	  	2168	  	LANSDALE FED 10-4
	03957	  	2168	  	CLIFTON FEDERAL 34-4
	03941	  	2168	  	BRUFF FEDERAL 4-26
	03940	  	2896	  	BRUFF FEDERAL 3-26
	03940	  	2896	  	BRUFF FEDERAL 3-26
	00473	  	2168	  	DRY PINEY UNIT 23
	00473	  	2168	  	DRY PINEY UNIT 23
	00465	  	2168	  	DRY PINEY UNIT 14
	00464	  	2168	  	DRY PINEY UNIT 11
	00463	  	2168	  	DRY PINEY UNIT 9
	00462	  	2168	  	DRY PINEY UNIT 8
	00461	  	2168	  	DRY PINEY UNIT 6
	00460	  	2168	  	DRY PINEY UNIT 5
	00813	  	3640	  	U P 11-19-104 3
	00812	  	2896	  	U P 11-19-104 2
	00810	  	3640	  	MFS CHAMPLIN 11-8
	00809	  	3640	  	NORTH BAXTER 14-1
	00808	  	2896	  	G W CAPPERS B 3
	00807	  	2896	  	G W CAPPERS A 2
	00724	  	2896	  	LEUCITE HILLS 2
	00723	  	2896	  	LEUCITE HILLS 1
	00817	  	2896	  	TERESA LAURUNEN 1
	00817	  	2896	  	TERESA LAURUNEN 1
	00817	  	2168	  	TERESA LAURUNEN 1
	00817	  	2168	  	TERESA LAURUNEN 1

  
 A-8

					
	Well
Num	  	Form
Code	  	Well Name
	00816	  	2896	  	O F FEATHERSTONE 1
	00815	  	2896	  	U P 35-20-104 1
	00814	  	2896	  	U P 23-20-104 1
	00723	  	2896	  	LEUCITE HILLS 1
	00723	  	2168	  	LEUCITE HILLS 1
	00723	  	2168	  	LEUCITE HILLS 1
	01466	  	0912	  	MESA UNIT 2
	01465	  	0912	  	MESA UNIT 1
	00474	  	2760	  	DRY PINEY UNIT 26
	00473	  	2760	  	DRY PINEY UNIT 23
	00473	  	2760	  	DRY PINEY UNIT 23
	00459	  	2168	  	DRY PINEY UNIT 3
	00458	  	2168	  	DRY PINEY UNIT 27
	00457	  	2760	  	DRY PINEY UNIT 22
	00457	  	2760	  	DRY PINEY UNIT 22
	00457	  	2168	  	DRY PINEY UNIT 22
	00457	  	2168	  	DRY PINEY UNIT 22
	00456	  	2168	  	DRY PINEY UNIT 13
	00455	  	2168	  	DRY PINEY UNIT 10
	03932	  	2168	  	CLIFTON FEDERAL 34-3
	03901	  	2168	  	HAGOOD FEDERAL 12-2
	03890	  	2896	  	PANDO FEDERAL 32-2
	03890	  	2896	  	PANDO FEDERAL 32-2
	03889	  	2168	  	CLIFTON FEDERAL 28-2
	03887	  	2168	  	BRUFF UNIT 21
	03887	  	2168	  	BRUFF UNIT 21
	03885	  	2168	  	BRUFF UNIT 19
	03884	  	2168	  	BRUFF UNIT 18
	03847	  	2168	  	HALEY FEDERAL 4-2
	03833	  	2168	  	CUMMINGS FEDERAL 2-8
	03828	  	2168	  	LAWLER FED 2-32
	03762	  	2896	  	MFS FEE 10-2
	03762	  	2896	  	MFS FEE 10-2
	03725	  	2168	  	CHAMP 149 AMOCO B-2
	01706	  	2168	  	CH BUTTES #1-9
	00207	  	5848	  	BRUFF UNIT 1
	00189	  	2168	  	BRUFF UNIT 7
	02052	  	2896	  	HENRY FORK UNIT 12
	01829	  	2896	  	HENRY FORK UNIT 11
	00620	  	2896	  	HENRY FORK UNIT 4A
	00619	  	2896	  	HENRY FORK UNIT 1

  
 A-9

 Non-Wexpro Agreement receipt points. 

 

					
	Well
Num	  	Form
Code	  	Well Name
	02217	  	0784	  	CHIVINGTON 1
	00949	  	0912	  	JOYCE WOLF 2
	00942	  	0912	  	KLAENHAMMER 2
	01471	  	1464	  	IMPERIAL FED 2-12
	01471	  	1464	  	IMPERIAL FED 2-12
	00944	  	0912	  	PTASYNSKI 4
	01769	  	0912	  	POWDER WASH MS 44
	00946	  	0912	  	KLAENHAMMER 3
	01770	  	0912	  	MILLISON 1
	00947	  	0912	  	PTASYNSKI 2
	02187	  	0912	  	V M KLAENHAMMER 1
	00931	  	0912	  	PTASYNSKI 5
	01771	  	0912	  	JOYCE WOLF 1
	00945	  	0912	  	PTASYNSKI 3
	02125	  	0912	  	PTASYNSKI 1X
	02125	  	0912	  	PTASYNSKI 1X
	00948	  	0912	  	JOYCE WOLF 3
	01773	  	8500	  	POWDER WASH MS 58
	00943	  	0912	  	JOYCE WOLF 4
	03906	  	8500	  	BIG GULCH MS 61
	01799	  	8500	  	W SIDE CANAL MS 41
	01214	  	1464	  	W SIDE CANAL UN 13
	01214	  	1464	  	W SIDE CANAL UN 13
	01214	  	1464	  	W SIDE CANAL UN 13
	01716	  	1464	  	W SIDE CANAL UN 16
	01716	  	1464	  	W SIDE CANAL UN 16
	01716	  	1464	  	W SIDE CANAL UN 16
	01717	  	1464	  	W SIDE CANAL UN 15
	01717	  	1464	  	W SIDE CANAL UN 15
	01717	  	1464	  	W SIDE CANAL UN 15
	01216	  	1464	  	W SIDE CANAL UN 14
	01216	  	1464	  	W SIDE CANAL UN 14
	01717	  	8536	  	W SIDE CANAL UN 15
	01717	  	8536	  	W SIDE CANAL UN 15
	01717	  	8536	  	W SIDE CANAL UN 15
	01214	  	1512	  	W SIDE CANAL UN 13
	01214	  	1512	  	W SIDE CANAL UN 13
	01214	  	1512	  	W SIDE CANAL UN 13
	01716	  	8536	  	W SIDE CANAL UN 16
	01716	  	8536	  	W SIDE CANAL UN 16
	01716	  	8536	  	W SIDE CANAL UN 16
	01216	  	1512	  	W SIDE CANAL UN 14

  
 A-10

					
	Well
Num	  	Form
Code	  	Well Name
	01216	  	1512	  	W SIDE CANAL UN 14
	03783	  	1464	  	W SIDE CANAL UN 3
	01215	  	1512	  	GLADHILL DR ST 1-13
	03907	  	2168	  	RUTH SWEZEY 1B
	03908	  	2168	  	RUTH SWEZEY 1C
	02054	  	1464	  	RUTH SWEZEY 2
	01212	  	1512	  	W SIDE CANAL JONS 2
	01798	  	1512	  	W SIDE CANAL MS 47-1
	01801	  	8500	  	W SIDE CANAL MS 47
	02258	  	1464	  	RUTH SWEZEY 2 LP
	02258	  	1464	  	RUTH SWEZEY 2 LP
	01213	  	1512	  	W SIDE CANAL JONS 3
	01872	  	1512	  	BAGGS LND & CATTLE 1
	01869	  	8520	  	DRIPPING ROCK UNIT 1
	01867	  	8520	  	DRIPPING ROCK UNIT 3
	03823	  	8520	  	DRIPPING ROCK 23-5
	03955	  	8500	  	CELSIUS FED 4-1 TAP
	03955	  	8500	  	CELSIUS FED 4-1 TAP
	03897	  	8520	  	RUGER FEDERAL #24-32
	00941	  	0912	  	PDR WASH GOV’T 33-7
	02383	  	0784	  	ACE UNIT 5
	00662	  	0912	  	JACKS DRAW UNIT 8
	02314	  	0912	  	ROSS GOV’T 44-7
	01710	  	0912	  	AMOCO FEDERAL 20-9
	00661	  	0912	  	JACKS DRAW UNIT 5
	00937	  	0912	  	MARLIN GOVERNMENT 1
	00933	  	0912	  	HUBER STATE 2
	00003	  	0912	  	ACE UNIT WELL 3
	00930	  	0912	  	HUBER CHAPMAN ST 1
	00002	  	0912	  	ACE UNIT WELL 2
	00935	  	1464	  	MTN FUEL FED 1-12
	00935	  	1464	  	MTN FUEL FED 1-12
	00938	  	0912	  	ROSS GOV’T 43-7
	00932	  	0912	  	HUBER CHAPMAN ST 2
	00001	  	0912	  	ACE UNIT WELL 1
	02238	  	8500	  	POWDER WASH MS 140
	00527	  	0784	  	V SCHAICK C GOVT 5
	00529	  	0784	  	F S DUNCAN B 2
	00528	  	0784	  	F S DUNCAN B 3
	01083	  	1600	  	GRYNBERG STATE LD 1
	01256	  	0912	  	LION OIL GOV’T 3
	01255	  	0912	  	LION OIL GOV’T 2
	01254	  	0912	  	LION OIL GOV’T 1
	01251	  	0912	  	HIAWATHA GOV’T B-1

  
 A-11

					
	Well
Num	  	Form
Code	  	Well Name
	01251	  	0912	  	HIAWATHA GOV’T B-1
	01242	  	0912	  	DUNCAN UNIT 1-1
	01084	  	1600	  	DYER C GOV’T 1
	01250	  	0912	  	A P VAN SCHAICK A 3
	01250	  	0912	  	A P VAN SCHAICK A 3
	03362	  	0912	  	FEDERAL 1-21
	03362	  	0912	  	FEDERAL 1-21
	03362	  	0912	  	FEDERAL 1-21
	01246	  	0912	  	F S DUNCAN B-6
	01481	  	0784	  	H W OBORNE 2
	01252	  	0912	  	H W OBORNE NO 1
	03905	  	8500	  	W HIAWATHA COMP #2
	01251	  	0784	  	HIAWATHA GOV’T B-1
	01251	  	0784	  	HIAWATHA GOV’T B-1
	01247	  	0912	  	D VAN SCHAICK 1
	01247	  	0912	  	D VAN SCHAICK 1
	01478	  	1600	  	UNIVERSAL RES 1-3
	03362	  	1512	  	FEDERAL 1-21
	03362	  	1512	  	FEDERAL 1-21
	03362	  	1512	  	FEDERAL 1-21
	00668	  	2896	  	KINNEY UNIT 4
	01111	  	1600	  	TRAIL UNIT 4
	00663	  	2168	  	KINNEY UNIT 1
	00663	  	2168	  	KINNEY UNIT 1
	01109	  	1600	  	TRAIL UNIT 2
	01114	  	1600	  	TRAIL UNIT 8
	01110	  	1600	  	TRAIL UNIT 3
	00667	  	2896	  	KINNEY UNIT 2
	00663	  	3944	  	KINNEY UNIT 1
	00663	  	3944	  	KINNEY UNIT 1
	01479	  	1600	  	TRAIL UNIT 13
	00664	  	1600	  	PIONEER UNIT 3
	00665	  	1600	  	PIONEER UNIT 4
	00854	  	1600	  	PIONEER UNIT 8
	00854	  	1600	  	PIONEER UNIT 8
	02118	  	1600	  	TRAIL UNIT 12
	01113	  	1600	  	TRAIL UNIT 6
	01223	  	1600	  	VERMILLION CR UNIT 1
	00669	  	2896	  	KINNEY UNIT 5
	00674	  	2896	  	KINNEY UNIT 6
	00980	  	2168	  	HUGHS UNIT 1
	01473	  	2896	  	SALT WELLS 11-11
	00977	  	3128	  	HUSKY FEDERAL 15-10
	01015	  	2168	  	SO BAXTER UNIT 3

  
 A-12

					
	Well
Num	  	Form
Code	  	Well Name
	01018	  	2168	  	A COOPER 1
	00999	  	2896	  	SO BAXTER UNIT 15
	01016	  	2168	  	SO BAXTER UNIT 6
	00685	  	1600	  	JACKKNIFE SPRINGS 1
	01020	  	2168	  	Al POSTON A 2
	01020	  	2168	  	Al POSTON A 2
	02093	  	2168	  	SO BAXTER UNIT 16
	02093	  	2168	  	SO BAXTER UNIT 16
	01019	  	2168	  	WT NIGHTINGALE A 1
	01033	  	2168	  	SO BAXTER UNIT 8
	01014	  	2168	  	SO BAXTER UNIT 2
	01025	  	2168	  	UP 21-16-104 2
	01000	  	2896	  	SO BAXTER UNIT SR 1
	01021	  	2168	  	AJ POSTON A 3
	01028	  	2168	  	SO BAXTER UNIT 9
	02093	  	2896	  	SO BAXTER UNIT 16
	02093	  	2896	  	SO BAXTER UNIT 16
	01029	  	2168	  	WE MULLEN A 2
	01026	  	2168	  	MF WHELAN 1
	01030	  	2168	  	SL 10-17-104 1
	00686	  	1600	  	JACKKNIFE SPRINGS 2
	01022	  	2168	  	U P 11-16-104-1
	01837	  	2168	  	SO BAXTER UNIT 17
	01475	  	2168	  	CREST FEDERAL 1-24
	00988	  	2896	  	LEAR FEDERAL 1-30
	00986	  	2168	  	POLUMBUS GOV’T 31-1
	00990	  	2168	  	TENNECO FEDERAL 1-30
	00987	  	2168	  	POLUMBUS GOV’T 19-1
	00989	  	2168	  	MTN FUEL FED 1-20
	00985	  	2168	  	POLUMBUS GOV’T 30-1
	03372	  	2896	  	N NITCHIE GULCH 20-6
	03372	  	2896	  	N NITCHIE GULCH 20-6
	00758	  	2896	  	NITCHIE GULCH 2
	00758	  	2896	  	NITCHIE GULCH 2
	03337	  	2168	  	N NITCHIE GULCH 2-5
	03380	  	2168	  	NITCHIE GULCH 20-19
	00756	  	2168	  	SAND DUNES FED 1
	00770	  	2168	  	WC MCBRIDE GOV’T 1-5
	03594	  	2896	  	NITCHIE GULCH 22-8
	03378	  	2896	  	ROGERS FED 20-12
	03488	  	2896	  	NITCHIE GULCH 21-21
	03488	  	2896	  	NITCHIE GULCH 21-21
	00773	  	2168	  	JAMIESON A 1
	00757	  	2896	  	NITCHIE GULCH 1

  
 A-13

					
	Well
Num	  	Form
Code	  	Well Name
	00757	  	2896	  	NITCHIE GULCH 1
	01730	  	2168	  	NITCHIE GULCH 12-18
	03391	  	2896	  	N NITCHIE 30-6
	01731	  	2168	  	NITCHIE GULCH 13-20
	00762	  	2168	  	NITCHIE GULCH 6
	03372	  	2168	  	N NITCHIE GULCH 20-6
	03372	  	2168	  	N NITCHIE GULCH 20-6
	00764	  	2168	  	NITCHIE GULCH 8
	03368	  	2896	  	NITCHIE GULCH 19-7
	00767	  	2168	  	ROGERS GOV’T 1-12
	02045	  	2168	  	NITCHIE GULCH 14-7
	00760	  	2896	  	NITCHIE GULCH 4
	00760	  	2896	  	NITCHIE GULCH 4
	02072	  	2168	  	FEDERAL 15-8X
	00757	  	2168	  	NITCHIE GULCH 1
	00757	  	2168	  	NITCHIE GULCH 1
	02262	  	2168	  	NO NITCHIE GULCH 2-6
	00760	  	2168	  	NITCHIE GULCH 4
	00760	  	2168	  	NITCHIE GULCH 4
	02288	  	2896	  	NITCHIE GULCH 3-21
	00763	  	2168	  	NITCHIE GULCH 7
	02294	  	2168	  	NITCHIE GULCH 17-16
	02294	  	2168	  	NITCHIE GULCH 17-16
	00769	  	2168	  	ANDERSON GOV’T 1
	02315	  	2168	  	NITCHIE GULCH 30-31
	02315	  	2168	  	NITCHIE GULCH 30-31
	03488	  	2168	  	NITCHIE GULCH 21-21
	03488	  	2168	  	NITCHIE GULCH 21-21
	03346	  	2896	  	NITCHIE GULCH 10-32
	00765	  	2168	  	NITCHIE GULCH 11
	00758	  	2168	  	NITCHIE GULCH 2
	00758	  	2168	  	NITCHIE GULCH 2
	03645	  	2168	  	N NITCHIE 3-5 FED
	03343	  	2168	  	NITCHIE GULCH 10-31
	02316	  	2896	  	PINE CANYON 40-31
	00846	  	2896	  	PINE CNYN LUFF 1-9
	00843	  	2896	  	PINE CANYON UNIT 1
	03338	  	8500	  	W PINE CANYON 10-5
	03338	  	8500	  	W PINE CANYON 10-5
	03377	  	2896	  	W PINE CYN 9-32
	03377	  	2896	  	W PINE CYN 9-32
	03347	  	2896	  	UPRR 1-33
	03379	  	2896	  	UPRR #1 1-3
	02313	  	2168	  	NITCHIE GULCH 18-29

  
 A-14

					
	Well
Num	  	Form
Code	  	Well Name
	02313	  	2168	  	NITCHIE GULCH 18-29
	03382	  	2168	  	W PINE CYN 10-5 X FS
	02311	  	2896	  	NO. 1 UPRR 1-27
	03384	  	2168	  	PINE CANYON 10-29
	03384	  	2168	  	PINE CANYON 10-29
	03355	  	2896	  	UPRR 2 2-33
	03355	  	2896	  	UPRR 2 2-33
	03384	  	2896	  	PINE CANYON 10-29
	03384	  	2896	  	PINE CANYON 10-29
	02239	  	2896	  	NITCHIE GULCH 16-28
	02239	  	2896	  	NITCHIE GULCH 16-28
	03386	  	2168	  	PINE CANYON 8-28
	03386	  	2168	  	PINE CANYON 8-28
	03361	  	2168	  	PINE CANYON 6-32
	03361	  	2168	  	PINE CANYON 6-32
	03386	  	2896	  	PINE CANYON 8-28
	03386	  	2896	  	PINE CANYON 8-28
	03389	  	2168	  	FEDERAL 1-28
	03389	  	2168	  	FEDERAL 1-28
	03387	  	2168	  	UPRR 3-33
	03387	  	2168	  	UPRR 3-33
	00850	  	2896	  	PINE CNYN LUFF 2-17
	03387	  	2896	  	UPRR 3-33
	03387	  	2896	  	UPRR 3-33
	00847	  	2896	  	PINE CNYN LUFF 1-17
	03389	  	2896	  	FEDERAL 1-28
	03389	  	2896	  	FEDERAL 1-28
	03388	  	2168	  	UPRR-TERRA 1 41 F-7
	03388	  	2168	  	UPRR TERRA 1 41 F-7
	03397	  	2168	  	W PINE CANYON 30-31
	02312	  	2168	  	PINE CANYON 4-29
	03491	  	2896	  	PINE CANYON 4-33
	03491	  	2896	  	PINE CANYON 4-33
	03357	  	2896	  	W PINE CANYON 30-5
	03662	  	3144	  	FEDERAL 18-H
	03361	  	2896	  	PINE CANYON 6-32
	03361	  	2896	  	PINE CANYON 6-32
	00724	  	2896	  	LEUCITE HILLS 2
	00849	  	2896	  	CENEX STATE 4-16
	00723	  	2168	  	LEUCITE HILLS 1
	00723	  	2168	  	LEUCITE HILLS 1
	02313	  	2896	  	NITCHIE GULCH 18-29
	02313	  	2896	  	NITCHIE GULCH 18-29
	00437	  	2896	  	LEUCITE HILLS 1-33

  
 A-15

					
	Well
Num	  	Form
Code	  	Well Name
	02239	  	2168	  	NITCHIE GULCH 16-28
	02239	  	2168	  	NITCHIE GULCH 16-28
	00272	  	2896	  	LEUCITE HILLS 1-19
	03338	  	2896	  	W PINE CANYON 10-5
	03338	  	2896	  	W PINE CANYON 10-5
	03377	  	2168	  	W PINE CYN 9-32
	03377	  	2168	  	W PINE CYN 9-32
	03355	  	2168	  	UPRR 2 2-33
	03355	  	2168	  	UPRR 2 2-33
	03735	  	8500	  	CEDAR CYN 30-16 TAP
	00447	  	2168	  	HALEY FEDERAL 4-1
	00189	  	2168	  	BRUFF UNIT 7
	00213	  	2168	  	BRUFF UNIT 9
	00752	  	2168	  	CLIFTON FEDERAL 28-1
	02066	  	2168	  	OWEN FEDERAL 1-18
	00199	  	2896	  	CHAMPLIN 358 G-1
	01707	  	2168	  	CPC 1-5 UPRR
	01707	  	2168	  	CPC 1-5 UPRR
	00439	  	2168	  	BRUFF FEDERAL 2-26
	00754	  	2168	  	MATHERLY FEDERAL 1-6
	00429	  	2168	  	CLIFTON FEDERAL 34-1
	03762	  	2896	  	MFS FEE 10-2
	03762	  	2896	  	MFS FEE 10-2
	00229	  	2896	  	DONLEY (NCT #2) 1
	00229	  	2896	  	DONLEY (NCT #2) 1
	01707	  	2896	  	CPC 1-5 UPRR
	01707	  	2896	  	CPC 1-5 UPRR
	00216	  	2168	  	BRUFF UNIT 6
	03833	  	2168	  	CUMMINGS FEDERAL 2-8
	01706	  	2168	  	CH BUTTES #1-9
	02201	  	2168	  	THOMPSON FED 12-1
	02201	  	2168	  	THOMPSON FED 12-1
	00214	  	2168	  	BRUFF CHAMPLIN 1-27
	00619	  	2896	  	HENRY FORK UNIT 1
	00619	  	2896	  	HENRY FORK UNIT 1
	01413	  	2896	  	MARATHON FED 1-16
	02071	  	2896	  	CONOCO 20-2
	02193	  	2896	  	HENRY FORK UNIT 15
	02191	  	2896	  	CONOCO FEDERAL 19-3
	00185	  	2896	  	BUTCHERKNIFE SPR 6
	00231	  	2896	  	BUTCHERKNIFE SPR 5
	00231	  	2896	  	BUTCHERKNIFE SPR 5
	01442	  	2896	  	BUTCHERKNIFE SPR 8
	01834	  	2896	  	BUTCHERKNIFE SPR 9

  
 A-16

					
	Well
Num	  	Form
Code	  	Well Name
	02192	  	2896	  	TAYLOR RANCH 25-33
	00971	  	4256	  	RYCKMAN CREEK 23
	01402	  	3944	  	CHAMPLIN 372 D-1
	01402	  	3944	  	CHAMPLIN 372 D-1
	00019	  	3784	  	CHAMP 372 AMOCO B-1
	00017	  	3944	  	ISLAND RANCHING B-1
	01402	  	8500	  	CHAMPLIN 372 D-1
	01402	  	8500	  	CHAMPLIN 372 D-1
	00014	  	3784	  	ANSCHUTZ RANCH 34-1
	00022	  	3944	  	CHAMP 387 AMOCO B-1
	00012	  	3784	  	CHAMPLIN 372 C-1
	03398	  	8500	  	DIVIDE CR CK STATION
	01595	  	2896	  	SHAEFFER NO 1
	02080	  	2416	  	LOWER HORSE DRAW A 5
	01654	  	2416	  	LOWER HORSE DRAW E 3
	03331	  	2896	  	RABBIT MOUNTAIN 6-1
	01653	  	2416	  	LOWER HORSE DRAW A 7
	01663	  	2416	  	LOWER HORSE DRAW A 9
	01650	  	2416	  	LOWER HORSE DRAW B15
	01660	  	2416	  	LOWER HORSE DRAW A14
	01648	  	2416	  	LOWER HORSE DRAW A 6
	01657	  	2416	  	LOWER HORSE DRAW C19
	01647	  	2416	  	LOWER HORSE DRAW A 4
	01666	  	2416	  	LOWER HORSE DRAW D17
	01646	  	2416	  	LOWER HORSE DRAW B16
	01658	  	2416	  	LOWER HORSE DRAW A12
	01662	  	2416	  	LOWER HORSE DRAW B11
	01656	  	2416	  	LOWER HORSE DRAW C20
	00693	  	2416	  	LOWER HORSE DRAW D18
	01391	  	0784	  	CHAPITA UNIT 217-23
	03920	  	0784	  	CHAPITA UNIT 339-25
	03937	  	0784	  	CHAPITA UNIT 324-22
	03819	  	0784	  	CHAPITA UNIT 312-23
	03820	  	0784	  	CHAPITA UNIT 319-14
	00289	  	0784	  	CHAPITA UNIT 7
	03821	  	0784	  	CHAPITA UNIT 321-26
	00294	  	0784	  	CHAPITA UNIT 13
	03822	  	0784	  	CHAPITA UNIT 323-22
	00299	  	0784	  	CHAPITA UNIT 21
	03893	  	0784	  	CHAPITA UNIT 306-27
	00301	  	0784	  	CHAPITA UNIT 24
	03894	  	0784	  	CHAPITA UNIT 307-28
	00306	  	0784	  	CHAPITA UNIT 15
	03917	  	0784	  	CHAPITA UNIT 311-26

  
 A-17

					
	Well
Num	  	Form
Code	  	Well Name
	00308	  	0784	  	CHAPITA UNIT 17
	03919	  	0784	  	CHAPITA UNIT 308-21
	00310	  	0784	  	CHAPITA UNIT 31-14
	03754	  	0784	  	CONOCO BLACK 6-35
	00312	  	0784	  	CHAPITA UNIT 35-15
	00287	  	0784	  	CHAPITA UNIT 5
	00314	  	0784	  	CHAPITA UNIT 36-26
	03938	  	0784	  	CHAPITA UNIT 342-22
	00316	  	0784	  	CHAPITA UNIT 38-9
	03962	  	0784	  	STAGECOACH UN 41-20
	00319	  	0784	  	CHAPITA UNIT 44-10
	03963	  	0784	  	CHAPITA UNIT 327-23
	00321	  	0784	  	CHAPITA UNIT 48-19
	03966	  	0784	  	CHAPITA UNIT 326-24
	00324	  	0784	  	BELCO 42-13
	03967	  	0784	  	CHAPITA UNIT 334-2
	00332	  	0784	  	CHAPITA UNIT 43-11
	03979	  	0784	  	CHAPITA UNIT 343-15
	00334	  	0784	  	CHAPITA UNIT 58-19
	03980	  	0784	  	CHAPITA UNIT 344-23
	01385	  	0784	  	CHAPITA UNIT 234-23
	03982	  	0784	  	CHAPITA UNIT 346-26
	01388	  	0784	  	CHAPITA UNIT 226-3
	03983	  	0784	  	CHAPITA UNIT 347-26
	01390	  	0784	  	CHAPITA UNIT 219-15
	03984	  	0784	  	CHAPITA UNIT 348-23
	01392	  	0784	  	CHAPITA UNIT 224-10
	03985	  	0784	  	CHAPITA UNIT 349-27
	01394	  	0784	  	CHAPITA UNIT 52-33
	03986	  	0784	  	CHAPITA UNIT 350-14
	01445	  	0784	  	CHAPITA UNIT 231-15
	03994	  	0784	  	CHAPITA UNIT 351-15
	01561	  	0784	  	CHAPITA UNIT 228-9
	00279	  	0784	  	DUNCAN FEDERAL 33-9
	01723	  	0784	  	CHAPITA UNIT 236-13
	00326	  	0784	  	MOUNTAIN LION 34-2
	01843	  	0784	  	CHAPITA UNIT 238-16
	00327	  	0784	  	FEDERAL 35-5
	02076	  	0784	  	CHAPITA UNIT 239-9
	00328	  	0784	  	PINNECOOSE 6-3
	02078	  	0784	  	CHAPITA UNIT 240-16
	00329	  	0784	  	ANKERPONT 2-6
	03764	  	0784	  	CHAPITA UNIT 301-26
	00745	  	0784	  	STAGECOACH UNIT 21-8

  
 A-18

					
	Well
Num	  	Form
Code	  	Well Name
	02246	  	8500	  	MS 203 WHITE RIVER
	00774	  	0784	  	CONOCO WEEKS 6-29
	00296	  	0784	  	CHAPITA UNIT 16
	00775	  	0784	  	PAWWINNEE 3-10
	00305	  	0784	  	CHAPITA UNIT 56-29
	00776	  	0784	  	CONOCO 35-19
	00309	  	0784	  	CHAPITA UNIT 30-22
	00777	  	0784	  	CONOCO JENKS 5-11
	00313	  	0784	  	CHAPITA UNIT 32-21
	00778	  	0784	  	UTE TRIBAL 35-16
	00318	  	0784	  	CHAPITA UNIT 34-28
	00779	  	0784	  	UTE TRIBAL 6-1
	00323	  	0784	  	CHAPITA UNIT 40-27
	00781	  	0784	  	ANKERPONT 31-12
	00333	  	0784	  	CHAPITA UNIT 49-25
	00783	  	0784	  	DM ICE FRIDAY 34-22
	01386	  	0784	  	CHAPITA UNIT 225-2
	00784	  	0784	  	SNOW KNIGHT 4-23
	03779	  	0784	  	ANKERPONT 35-36
	00785	  	0784	  	CONOCO POST 3-24
	01444	  	0784	  	CHAPITA UNIT 229-12
	00786	  	0784	  	CONOCO WYASKET 33-26
	01562	  	0784	  	CHAPITA UNIT 231-14
	00787	  	0784	  	CONOCO KURIP 1-27
	02075	  	0784	  	CHAPITA UNIT 244-25A
	00789	  	0784	  	CONOCO TABBEE 34-20
	03763	  	0784	  	CHAPITA UNIT 304-13
	00790	  	0784	  	CONOCO WISSIUP 36-15
	00292	  	0784	  	CHAPITA UNIT 11
	00791	  	0784	  	CONOCO WELL 36-17
	00307	  	0784	  	CHAPITA UNIT 20
	00792	  	0784	  	CONOCO HALL 31-18
	00315	  	0784	  	CHAPITA UNIT 37-11
	00793	  	0784	  	CONOCO STATE 32-21
	00330	  	0784	  	CHAPITA UNIT 47-30
	00955	  	0544	  	FS PRINCE 1
	01389	  	0784	  	CHAPITA UNIT 227-3
	01041	  	0784	  	BELCO 18-17
	01446	  	0784	  	CHAPITA UNIT 233-15
	01050	  	0784	  	STAGECOACH UNIT 6
	02077	  	0784	  	CHAPITA UNIT 241-16
	01430	  	0784	  	CONOCO STATE 31-32
	00300	  	0784	  	CHAPITA UNIT 22
	01778	  	8500	  	RIVER BEND MS 112

  
 A-19

					
	Well
Num	  	Form
Code	  	Well Name
	00320	  	0784	  	CHAPITA UNIT 45-25
	01779	  	8500	  	RIVER BEND MS 113
	01393	  	0784	  	CHAPITA UNIT 220-10
	01789	  	0784	  	STAGECOACH UN 22-17
	03765	  	0784	  	CHAPITA UNIT 303-22
	01823	  	0784	  	CONOCO SERAWOP 4.13
	01385	  	0784	  	CHAPITA UNIT 234-23
	00311	  	0784	  	CHAPITA UNIT 33-16
	01724	  	0784	  	CHAPITA UNIT 237-22
	02109	  	8500	  	HORSESHOE BND MS 205
	02324	  	0784	  	LITTLE PAPOOSE 1-26
	01761	  	8500	  	OLD SQUAW MS 79
	02063	  	2264	  	MT RESOURCE 22,27 MM
	02043	  	2264	  	MTN RESOURCE 18
	02321	  	2264	  	GOV’T 1
	01857	  	2264	  	MNT RESOURCE 20
	02319	  	2264	  	CONOVER STATE 1-22
	01856	  	2264	  	MNT RESOURCE 19
	02317	  	2264	  	SINGLETON FEE 23-14
	01855	  	2264	  	MT RESOURCE 17,12 MM
	02086	  	2264	  	MTN RESOURCE 27
	01819	  	2264	  	MTN RESOURCE 16
	02320	  	2264	  	FERRON UNIT 12-3
	01406	  	2264	  	MTN RESOURCE 2
	02087	  	2264	  	MT RESOURCE 18,21 MM
	02318	  	2264	  	BEHLING 41-22
	02322	  	2264	  	RALPHS FEE 41-9
	01740	  	8500	  	CLEAR CREEK MM
	00033	  	2168	  	AMOCO CHAMPLIN 4-25
	00006	  	0912	  	ACE UNIT WELL 7
	00211	  	2168	  	BRUFF UNIT A-1
	00212	  	2168	  	BRUFF UNIT 5
	00216	  	2168	  	BRUFF UNIT 6
	00217	  	2168	  	BRUFF UNIT 4
	03847	  	2168	  	HALEY FEDERAL 4-2
	03932	  	2168	  	CLIFTON FEDERAL 34-3
	03940	  	2168	  	BRUFF FEDERAL 3-26
	03940	  	2168	  	BRUFF FEDERAL 3-26
	03941	  	2168	  	BRUFF FEDERAL 4-26
	03957	  	2168	  	CLIFTON FEDERAL 34-4
	03991	  	2896	  	MFS FEE 10-3
	03991	  	2896	  	MFS FEE 10-3
	00668	  	2896	  	KINNEY UNIT 4
	00667	  	2896	  	KINNEY UNIT 2

  
 A-20

					
	Well
Num	  	Form
Code	  	Well Name
	01721	  	8520	  	KINNEY UNIT WELL 3
	00669	  	2896	  	KINNEY UNIT 5
	00674	  	2896	  	KINNEY UNIT 6
	00664	  	1600	  	PIONEER UNIT 3
	00665	  	1600	  	PIONEER UNIT 4
	00854	  	1600	  	PIONEER UNIT 8
	00854	  	1600	  	PIONEER UNIT 8
	01031	  	2168	  	SL 36-18-104 2
	02316	  	2896	  	PINE CANYON 40-31
	02294	  	2896	  	NITCHIE GULCH 17-16
	02294	  	2896	  	NITCHIE GULCH 17-16
	03830	  	2168	  	LANSDALE FED 4-2
	03959	  	2168	  	LANSDALE FED 10-3
	03960	  	2168	  	LANSDALE FED 10-4
	03829	  	2168	  	LANSDALE FED 28-2
	04001	  	2168	  	LANSDALE FED 28-3
	03828	  	2168	  	LAWLER FED 2-32
	01832	  	2168	  	HARDY RANCH NO. 1

 DELIVERY POINTS 
 Delivery points associated with Wexpro Agreement. 
  

			
	ID	  	Well Name
	35	  	POWDER WASH MM
	38	  	PW L.336 DEHY MS#23
	41	  	EAST HIAWATHA MM
	42	  	HIAWATHA DEEP CM
	44	  	SUGAR LOAF MM
	45	  	JL 6 OTHER HIAWATHA
	47	  	W. HIAWATHA COMPR #2
	49	  	TRAIL UNIT MM
	50	  	KINNEY CHECK METER
	59	  	SOUTH BAXTER
	60	  	MIDDLE BAXTER MM
	63	  	NORTH BAXTER MM
	64	  	LOWER NITCHIE AREA
	65	  	CLAY BASIN FRONTIER
	70	  	IL. 35 BYPASS
	72	  	ET OUTLET
	73	  	HENRY’S FORK MM

  
 A-21

			
	ID	  	Well Name
	74	  	BUTCHERKNIFE #6
	75	  	BUTCHERKNIFE #5
	111	  	BIG HORSE DRAW MM
	114	  	RABBIT MOUNTAIN MM
	119	  	FIDLAR OURAY/CHAPITA
	125	  	ISLAND 52-1
	127	  	ISLAND 52-2
	129	  	ISLAND 52-3
	131	  	ISLAND 52-4
	155	  	SPEARHEAD LAT 701
	183	  	DOVE CREEK

 Non-Wexpro Agreement Delivery Points. 

 

			
	ID	  	Well Name
	2	  	BIG GULCH MM #61
	9	  	WESTSIDE CANAL MS 41
	10	  	GLAD HILL DRAW 1-13
	11	  	SWEZEY MM #47 W.S.C
	12	  	M.S. NO. 45
	14	  	POLE GULCH MS 53
	23	  	CELSIUS DRIP RCK TAP
	26	  	DRIPPING ROCK #3
	31	  	DRIPPING ROCK 23-5
	32	  	CELSIUS FED 4-1
	33	  	RUGER 24-32
	35	  	POWDER WASH MM
	35	  	POWDER WASH MM
	38	  	PW L.336 DEHY MS#23
	38	  	PW L.336 DEHY MS#23
	41	  	EAST HIAWATHA MM
	43	  	VERMILLION COMP MM
	44	  	SUGAR LOAF MM
	45	  	JL 6 OTHER HIAWATHA
	47	  	W. HIAWATHA COMPR #2
	49	  	TRAIL UNIT MM
	50	  	KINNEY CHECK METER
	53	  	HUGHS UNIT 1
	54	  	SALT WELLS 11-11
	55	  	HUSKY FEDERAL 15-10
	59	  	SOUTH BAXTER
	60	  	MIDDLE BAXTER MM
	61	  	UPPER NITCHIE AREA

  
 A-22

			
	ID	  	Well Name
	64	  	LOWER NITCHIE AREA
	70	  	JL 35 BYPASS
	72	  	ET OUTLET
	73	  	HENRY’S FORK MM
	74	  	BUTCHERKNIFE #6
	75	  	BUTCHERKNIFE #5
	76	  	BUTCHERKNIFE #8
	78	  	BUTCHERKNIFE #9
	80	  	LUCKEY DITCH C.M.
	85	  	RYCKMAN CREEK MM
	93	  	ANSCHUTZ RANCH MM
	99	  	DIVIDE CR CK STATION
	101	  	SHAEFFER NO 1
	114	  	RABBIT MOUNTAIN MM
	119	  	FIDLAR OURAY/CHAPITA
	133	  	OLD SQUAW M&R MS 219
	134	  	RIVER BEND MM
	148	  	FERRON MM
	151	  	CLEAR CREEK MM
	155	  	SPEARHEAD LAT 701
	188	  	CHAMPLIN 4-25

  
 A-23

 APPENDIX B 
 TO THE 
 GAS
GATHERING AGREEMENT 
 DATED: OCTOBER 11, 1993

 BETWEEN 
 MOUNTAIN FUEL SUPPLY COMPANY 
 AND 
 QUESTAR PIPELINE
COMPANY 
 GATHERING RATE DETERMINATION 

The reservation and usage rates to be charged for gathering natural gas under the terms of this Agreement shall be determined according
to the following provisions and guidelines. 
 1. The calculation of the gathering rates under § III(a) of the Agreement
shall incorporate data and accounting and other information for the most recent calendar year for which complete data are available. For the initial rates, this will be the calendar year 1992, as adjusted to reflect the elements incorporated and
approved in FERC Docket No. RS92-9. For subsequent rate determinations under this Agreement, such information shall be adjusted as necessary to reflect known and measurable changes1 in Questar’s gathering operations that will be effective during the years for which rates are to be in effect.
Such changes shall be consistent with the provisions of ¶¶ 2 and 3. 
 2. The net costs to be included in determining
the gathering rates shall include: (a) operating and maintenance expenses; (b) depreciation and amortization expenses; (c) taxes other than income taxes; (d) return on rate base; (e) federal and state income taxes; and
(f) other operating revenue credits. 
 3. For purposes of ¶ 2, the following guidelines will apply: 

(a) Operation and Maintenance (O&M) Expenses. These expenses include gathering expenses recorded in FERC Account Nos. 750-754
and 756-769 and 807, including administrative and general (A&G) expenses in Account Nos. 920-932 (excluding 924.1, 928.1, 928.2 and 920.3) and 935. 
 (b) Depreciation and Amortization Expense. This includes gathering expenses recorded in FERC Account Nos. 403 and 404, including general and intangible amortization expense. 

(c) Taxes Other Than Income Taxes. This includes gathering expenses recorded in FERC Account Nos. 408.1 and 408.9, including
payroll and property tax expense associated with general plant. 
  

 

	1 	This shall include, but not be limited to, year-end annualization of labor costs; prior-period adjustments; removal of Cost or revenue abnormalities; depreciation and
costs associated with capital investments for system additions. 

  
 B-1

 (d) Federal and State Income Taxes. Questar Pipeline’s combined federal and
state income tax rate shall be applied to the equity portion of the return on rate base. 
 (e) Rate Base. The
end-of-period rate base shall be determined from accounting data for the last month for which data are being used pursuant to ¶ 1 above (adjusted as necessary pursuant to that paragraph) and shall include that portion of the following that are
directly related or allocable to the gathering services performed under this Agreement: 
 (i) Gas plant, 

(ii) Accumulated depreciation and amortization, 
 (iii) Working capital, 
 (iv) Deferred income taxes, and 

(v) Questar’s general and intangible plant 
 (f) Rate of Return. The rate of return on rate base shall be the pre-tax rate of return specified for or derivable from the FERC’s determination of Questar’s transmission-service rates as
they are effective at the end of the period. This shall incorporate: 
  

	 	(i)	The actual, embedded costs of debt and preferred stock dividend (if any) for Questar Pipeline Company. 

 

	 	(ii)	Questar Pipeline Company’s actual, end-of-period capital structure. 

 (g) The costs of Questar’s gathering activities determined under this Appendix shall be reduced by other operating revenues that are directly related to those costs. 

  
 B-2

													
	 Mountain Fuel Gathering Rates –
Effective through August 31, 1995
	 
	 	  	Rate2	 	  	Quantity3	 	 	Revenue	 
	 Reservation Charge
	  	$	2.61642/Dth	  	  	 	322,812	  	 	$	10,135,325	  
	 Usage Charge
	  	$	0.22273/Dth	  	  	 	30,336,677	4 	 	$	6,756,883	  
	 Other Revenue
	  				  				 	$	2,500,000	  
	 Total Revenue
	  				  				 	$	19,392,208	  

  

	2 	Rates have been derived from the cost of service, revenues, and volumes for the 12 months ended December 1992. The total gathering cost of service includes $1,255,122
of costs refunctionalized from the production function to the gathering function consistent with internal rates established in Docket No. RS92-9 (refer to page 1 of Exhibit G, of Questar’s October 1, 1992, filing in Docket No. RS92-9).

	3 	Quantities are stated in “dry” decatherms. 

	4 	The usage quantity for this rate-design period is a projection of both Mountain Fuel’s own production and its purchased gas. (Projections are for rate-design
purposes only; actual commodity quantities gathered will be used for billing purposes.) The projection of Questar-gathered Mountain Fuel production was taken from the most recent IRP or IRP update on file with the Public Service Commission of Utah.
The Mountain Fuel purchased gas to be gathered by Questar was a projection developed by Questar’s Accounting Department from actual 1992 data. 

  
 B-3

 APPENDIX C 

TO THE 
 GAS GATHERING AGREEMENT 

DATED: OCTOBER 11, 1993 
 BETWEEN 
 MOUNTAIN FUEL
SUPPLY COMPANY 
 AND 

QUESTAR PIPELINE COMPANY 

NEW WELL CONNECTION 
 REIMBURSEMENT UNDER § III(c) 
 For any new well to be connected to
Questar’s gathering system under this Agreement that was not subject to this Agreement on the initial effective date, Mountain Fuel shall reimburse Questar according to the following formula: 

 
 

 
 where 
  

							
				
		 	Cr	  	=	  	Amount to be reimbursed by Mountain Fuel to Questar.
				
		 	C	  	=	  	Total actual cost of all new Questar gathering facilities required to connect the new well.
				
		 	t	  	=	  	Combined marginal state and federal income tax rate applicable to Questar in the year of the well connection (as a decimal fraction).
				
		 	f	  	=	  	“Deficiency factor” = Lesser of 1.0 or B ÷ 2,000,
				
		 	B	  	=	  	“Baseline flow” = (F ÷ L) x I.
				
		 	F	  	=	  	Average daily production of the well during a period of 30 consecutive days (to be designated by Mountain Fuel) during the first 12 months following connection of the well (in
MMBtu/day).
				
		 	L	  	=	  	Length of new gathering lateral to be installed by Questar to connect the new well to its gathering system (in miles).
				
		 	J	  	=	  	Mountain Fuel’s working interest in the well to be connected (as a decimal fraction).

  
 C-1

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