Document:

exv10w4

 

Exhibit 10.4

 

OMNIBUS AGREEMENT

AMONG

DUKE ENERGY FIELD SERVICES, LLC

DCP MIDSTREAM GP, LLC

DCP MIDSTREAM GP, LP

DCP MIDSTREAM PARTNERS, LP

AND

DCP MIDSTREAM OPERATING, LP

 

 

 

OMNIBUS AGREEMENT

     THIS OMNIBUS AGREEMENT (“Agreement”) is entered into on, and effective as of, the Closing Date
(as defined herein), and is by and among Duke Energy Field Services, LLC, a Delaware limited
liability company (“DEFS”), DCP Midstream GP, LLC, a Delaware limited liability company (“DCP
LLC”), DCP Midstream GP, LP, a Delaware limited partnership (the “General Partner”), DCP Midstream
Partners, LP, a Delaware limited partnership (the “MLP”) and DCP Midstream Operating, LP (the
“OLP”). The above-named entities are sometimes referred to in this Agreement each as a “Party” and
collectively as the “Parties.”

R E C I T A L S:

     The Parties desire by their execution of this Agreement to evidence their understanding, (i)
as more fully set forth in Article II and Article III of this Agreement, with respect to certain
indemnification and reimbursement obligations of the Parties, and (ii) as more fully set forth in
Article IV of this Agreement, with respect to DEFS’ obligation to maintain certain specified credit
support for the Partnership Group (as defined herein).

     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 hereby agree as follows:

ARTICLE I

Definitions

     1.1 Definitions. (a) Capitalized terms used herein but not defined shall have the meanings
given them in the MLP Agreement.

          (b) As used in this Agreement, the following terms shall have the respective meanings set
forth below:

     “Agreement” means this Omnibus Agreement, as it may be amended, modified or
supplemented from time to time in accordance with the terms hereof.

     “Black Lake Holdings” means Black Lake Holdings, LLC, a Delaware limited liability
company.

     “Black Lake Pipeline” means the NGL pipeline located in Louisiana and Texas that is
owned by BLPLC.

     “BLPLC” means Black Lake Pipe Line Company, a Texas general partnership.

     “Cause” has the meaning ascribed thereto in the Partnership Agreement.

     “Cap” has the meaning given such term in Section 2.4(a).

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     “Change of Control” means, with respect to any Person (the “Applicable Person”), any of
the following events: (i) any sale, lease, exchange or other transfer (in one transaction or
a series of related transactions) of all or substantially all of the Applicable Person’s
assets to any other Person, unless immediately following such sale, lease, exchange or other
transfer such assets are owned, directly or indirectly, by the Applicable Person; (ii) the
dissolution or liquidation of the Applicable Person; (iii) the consolidation or merger of
the Applicable Person with or into another Person pursuant to a transaction in which the
outstanding Voting Securities of the Applicable Person are changed into or exchanged for
cash, securities or other property, other than any such transaction where (a) the
outstanding Voting Securities of the Applicable Person are changed into or exchanged for
Voting Securities of the surviving Person or its parent and (b) the holders of the Voting
Securities of the Applicable Person immediately prior to such transaction own, directly or
indirectly, not less than a majority of the outstanding Voting Securities of the surviving
Person or its parent immediately after such transaction; and (iv) a “person” or “group”
(within the meaning of Sections 13(d) or 14(d)(2) of the Exchange Act) being or becoming the
“beneficial owner” (as defined in Rules 13d-3 and 13d-5 under the Exchange Act) of more than
50% of all of the then outstanding Voting Securities of the Applicable Person, except in a
merger or consolidation which would not constitute a Change of Control under clause (iii)
above.

     “Closing Date” means the date of the closing of the initial public offering of common
units representing limited partner interests in the MLP.

     “Common Unit” has the meaning given such term in the MLP Agreement.

     “Conflicts Committee” has the meaning given such term in the MLP Agreement.

     “Covered Environmental Losses” means all environmental losses, damages, liabilities,
claims, demands, causes of action, judgments, settlements, fines, penalties, costs and
expenses (including, without limitation, costs and expenses of any Environmental Activity,
court costs and reasonable attorney’s and experts’ fees) of any and every kind or character,
by reason of or arising out of:

     (i) any violation or correction of violation, including without limitation performance
of any Environmental Activity, of Environmental Laws; or

     (ii) any event, omission or condition associated with ownership or operation of the MLP
Assets or the Black Lake Pipeline (including, without limitation, the exposure to or
presence of Hazardous Substances on, under, about or migrating to or from the MLP Assets or
the Black Lake Pipeline or the exposure to or Release of Hazardous Substances arising out of
operation of the MLP Assets or the Black Lake Pipeline at non-MLP Asset locations)
including, without limitation, (A) the cost and expense of any Environmental Activities, (B)
the cost or expense of the preparation and implementation of any closure, remedial or
corrective action or other plans required or necessary under Environmental Laws and (C) the
cost and expense for any environmental or toxic tort pre-trial, trial or appellate legal or
litigation support work; provided, in the

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case of clauses (A) and (B), such cost and expense shall not include the costs of and
associated with project management and soil and ground water monitoring;

but only to the extent that such violation complained of under clause (i), or such events or
conditions included in clause (ii), occurred before the Closing Date.

     “DCP LLC” has the meaning given such term in the introduction to this Agreement.

     “DEFS” has the meaning given such term in the introduction to this Agreement.

     “Environmental Activities” shall mean any investigation, study, assessment, evaluation,
sampling, testing, monitoring, containment, removal, disposal, closure, corrective action,
remediation (regardless of whether active or passive), natural attenuation, restoration,
bioremediation, response, repair, corrective measure, cleanup or abatement that is required
or necessary under any applicable Environmental Law, including, but not limited to,
institutional or engineering controls or participation in a governmental voluntary cleanup
program to conduct voluntary investigatory and remedial actions for the clean-up, removal or
remediation of Hazardous Substances that exceed actionable levels established pursuant to
Environmental Laws, or participation in a supplemental environmental project in partial or
whole mitigation of a fine or penalty.

     “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 (a)
pollution or protection of the environment or natural resources including, without
limitation, the federal Comprehensive Environmental Response, Compensation and Liability
Act, the Superfund Amendments and Reauthorization Act, the Resource Conservation and
Recovery Act, the Clean Air Act, the Clean Water Act, the Safe Drinking Water Act, the Toxic
Substances Control Act, the Oil Pollution Act of 1990, the Hazardous Materials
Transportation Act, the Marine Mammal Protection Act, the Endangered Species Act, the
National Environmental Policy Act and other environmental conservation and protection laws,
each as amended through the Closing Date, (b) any Release or threatened Release of, or any
exposure of any Person or property to, any Hazardous Substances and (c) the generation,
manufacture, processing, distribution, use, treatment, storage, transport or handling of any
Hazardous Substances.

     “Environmental Permit” means any permit, approval, identification number, license,
registration, consent, exemption, variance or other authorization required under or issued
pursuant to any applicable Environmental Law.

     “Exchange Act” means the Securities Exchange Act of 1934, as amended.

     “G&A Expenses Limit” has the meaning given such term in Section 3.3.

     “General Partner” has the meaning given such term in the introduction to this
Agreement.

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     “Hazardous Substance” means (a) any substance 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, (b)
oil as defined in the Oil Pollution Act of 1990, as amended, including oil, gasoline,
natural gas, fuel oil, motor oil, waste oil, diesel fuel, jet fuel and other refined
petroleum hydrocarbons and petroleum products and (c) radioactive materials, asbestos
containing materials or polychlorinated biphenyls.

     “Indemnified Party” means either the Partnership Group or DEFS, as the case may be, in
their capacity as the parties entitled to indemnification in accordance with Article II.

     “Indemnifying Party” means either the Partnership Group or DEFS, as the case may be, in
their capacity as the parties from whom indemnification may be required in accordance with
Article II.

     “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 experts’ fees) of any and every kind or character.

     “MLP” has the meaning given such term in the introduction to this Agreement.

     “MLP Agreement” means the Amended and Restated Agreement of Limited Partnership of the
MLP, dated as of the Closing Date, as such agreement is in effect on the Closing Date, to
which reference is hereby made for all purposes of this Agreement. An amendment or
modification to the MLP Agreement subsequent to the Closing Date shall be given effect for
the purposes of this Agreement only if it has received the approval of the Conflicts
Committee that would be required, if any, pursuant to Section 6.6 hereof if such amendment
or modification were an amendment or modification of this Agreement.

     “MLP Assets” means the pipelines, processing plants or related equipment or assets, or
portions thereof, conveyed, contributed or otherwise transferred or intended to be conveyed,
contributed or otherwise transferred to any member of the Partnership Group, or owned by or
necessary for the operation of the business, properties or assets or any member of the
Partnership Group, prior to or as of the Closing Date; provided, the MLP Assets do not
include the Partnership Group’s direct or indirect ownership interest in Black Lake
Holdings, BLPLC or the Black Lake Pipeline.

     “OLP” has the meaning given such term in the introduction to this Agreement.

     “Organizational Documents” means certificates of incorporation, by-laws, certificates
of formation, limited liability company operating agreements, certificates of

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limited partnership or limited partnership agreements or other formation or governing
documents of a particular entity.

     “Partnership Entities” means DCP LLC, the General Partner and each member of the
Partnership Group.

     “Partnership Group” means the MLP, the OLP and any Subsidiary of the MLP or the OLP.

     “Partnership Indemnitee” means any Person who is an Indemnitee (as defined in the
Partnership Agreement); provided, that the term “Partnership Indemnitee” shall exclude DEFS
and any Affiliate of DEFS (as defined in the Partnership Agreement) which is not a member of
the Partnership Group.

     “Party” or “Parties” have the meaning given such terms in the introduction to this
Agreement.

     “Person” means an individual, corporation, partnership, joint venture, trust, limited
liability company, unincorporated organization or any other entity.

     “Release” means any depositing, spilling, leaking, pumping, pouring, placing, emitting,
discarding, abandoning, emptying, discharging, migrating, injecting, escaping, leaching,
dumping or disposing into the environment.

     “Seabreeze Pipeline” the NGL pipeline located in Texas that is owned, directly or
indirectly, by the OLP.

     “Subsidiary” has the meaning given such term in the MLP Agreement.

     “Voting Securities” means securities of any class of Person entitling the holders
thereof to vote in the election of, or to appoint, members of the board of directors or
other similar governing body of the Person.

ARTICLE II

Indemnification

     2.1 Environmental Indemnification.

          (a) Subject to the provisions of Section 2.4 and Section 2.5, DEFS shall indemnify, defend and
hold harmless the Partnership Group and the Partnership Indemnitees from and against any Covered
Environmental Losses suffered or incurred by the Partnership Group or any Partnership Indemnitee
relating to the MLP Assets or the Black Lake Pipeline for a period of three (3) years from the
Closing Date; provided that, for purposes of determining the amount of any Covered Environmental
Loss suffered or incurred by the Partnership Group or any Partnership Indemnitee with respect to
the Black Lake Pipeline, the Partnership Group’s indirect ownership of only 45% of the partnership
interests in BLPLC shall be taken into account such that any Covered Environmental Loss suffered or
incurred by the Partnership Group or any

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Partnership Indemnitee with respect to the Black Lake Pipeline would be determined in a
proportionate manner to the Covered Environmental Loss suffered or incurred by BLPLC with respect
to the same matter.

          (b) The Partnership Group shall indemnify, defend and hold harmless DEFS and its Subsidiaries,
other than any Subsidiary constituting part of the Partnership Group, from and against any Covered
Environmental Losses suffered or incurred by DEFS and its Subsidiaries, other than any Subsidiary
constituting part of the Partnership Group, relating to the MLP Assets and the Black Lake Pipeline
occurring after the Closing Date, except to the extent that the Partnership Group is indemnified
with respect to any of such Covered Environmental Losses under Section 2.1(a), provided that in no
event shall the Partnership Group indemnify, defend or hold harmless DEFS and its Subsidiaries from
and against any Covered Environmental Losses relating to the Black Lake Pipeline arising from or
attributable to the 5% interest in BLPLC owned by DEFS and its Subsidiaries from and after the
Closing Date.

     2.2 Indemnification for Certain Repair Costs. Subject to the provisions of Section 2.4 and
Section 2.5, DEFS shall also indemnify, defend and hold harmless the Partnership Group and the
Partnership Indemnitees from and against:

          (a) any capital contributions required to be made by the Partnership Group to fund any repair
and/or replacement costs associated with, resulting from or identified during the 2006 pipeline
integrity testing of the Black Lake Pipeline that is ongoing as of the Closing Date and expected to
be completed in 2006 as required under the Pipeline Safety Improvement Act of 2002; provided that
the maximum amount that DEFS shall be required to contribute to the Partnership Group and the
Partnership Indemnitees pursuant to this Section 2.2(a) shall be $5.3 million; and

          (b) any repair and/or replacement costs suffered or incurred by the Partnership Group or
Partnership Indemnitees associated with, resulting from or identified during the 2006 pipeline
integrity testing of the Seabreeze Pipeline scheduled for 2006 as required under the Pipeline
Safety Improvement Act of 2002; provided that, for purposes of this subsection (a), DEFS shall not
be obligated to indemnify the Partnership Group or any Partnership Indemnitee for any incremental
operating costs suffered or incurred by the Partnership Group associated with or resulting from any
of the repair or replacement of all or any portion of the Seabreeze Pipeline, provided further
that, the maximum amount that DEFS shall be required to contribute to the Partnership Group and the
Partnership Indemnitees pursuant to this Section 2.2(b) shall be $4.0 million.

     2.3 Additional Indemnification

          (a) Subject to the provisions of Section 2.4 and Section 2.5, DEFS shall indemnify, defend and
hold harmless the Partnership Group and the Partnership Indemnitees from and against any Losses
suffered or incurred by the Partnership Group or any Partnership Indemnitee by reason of or arising
out of:

     (i) the failure of the Partnership Group to be the owner of valid and
indefeasible easement rights, leasehold and/or fee ownership interests in and to

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the lands on which are located any MLP Assets or the Black Lake Pipeline, or to have
valid and indefeasible ownership of a 45% partnership interest in BLPLC, and such
failure renders the Partnership Group liable or unable to use or operate the MLP
Assets or the Black Lake Pipeline in substantially the same manner that the MLP
Assets or the Black Lake Pipeline were used and operated by DEFS and its
Subsidiaries (and BLPLC, with respect to the Black Lake Pipeline) immediately prior
to the Closing Date as described in the Registration Statement; provided that, for
purposes of determining the amount of any Loss suffered or incurred by the
Partnership Group or any Partnership Indemnitee with respect to the Black Lake
Pipeline, the Partnership Group’s ownership of only 45% of the partnership interests
in BLPLC shall be taken into account such that any Loss suffered or incurred by the
Partnership Group or any Partnership Indemnitee with respect to the Black Lake
Pipeline would be determined in a proportionate manner to the Loss suffered or
incurred by BLPLC with respect to the same matter;

     (ii) the failure of the Partnership Group to have on the Closing Date any
consent or governmental permit necessary to allow (i) the transfer of any of the MLP
Assets or a 45% partnership interest in BLPLC to the Partnership Group on the
Closing Date or (ii) any such MLP Assets or the Black Lake Pipeline to cross the
roads, waterways, railroads and other areas upon which any such MLP Assets or the
Black Lake Pipeline are located as of the Closing Date, and any such failure
specified in such clause (ii) renders the Partnership Group unable to use or operate
the MLP Assets or the Black Lake Pipeline in substantially the same manner that the
MLP Assets or the Black Lake Pipeline were owned and operated by DEFS and its
Subsidiaries (and BLPLC, with respect to the Black Lake Pipeline) immediately prior
to the Closing Date as described in the Registration Statement; provided, that, for
purposes of determining the amount of any Loss suffered or incurred by the
Partnership Group or any Partnership Indemnitee with respect to the Black Lake
Pipeline, the Partnership Group’s ownership of only 45% of the partnership interests
in BLPLC shall be taken into account such that any Loss suffered or incurred by the
Partnership Group or any Partnership Indemnitee with respect to the Black Lake
Pipeline would be determined in a proportionate manner to the Loss suffered or
incurred by BLPLC with respect to the same matter;

     (iii) all federal, state and local income tax liabilities attributable to the
ownership or operation of the MLP Assets or the Black Lake Pipeline prior to the
Closing Date, including any such income tax liabilities of DEFS and its Subsidiaries
that may result from the consummation of the formation transactions for the
Partnership Group occurring on or prior to the Closing Date, but excluding any
federal, state and local income taxes reserved on the books of the Partnership Group
as of the Closing Date;

     (iv) the assets, liabilities, business or operations of any of (a) Discovery
Producer Services, LLC, a [          ] limited liability company (“Discovery”), (b)
PanEnergy Dauphin Island LLC, a Delaware limited liability company

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(“PanEnergy”), (c) Gulf Coast NGL Pipeline, LLC, a Delaware limited liability company (“Gulf
Coast”), (d) Centana Gathering LLC, a Delaware limited liability company
(“Centana”), (e) DEFS Industrial Gas Co., LLC, a Delaware limited liability company
(“DIGC”), and (f) Centana Intrastate Pipeline LLC, a Delaware limited liability
company (“CIP”); and

     (v) all currently pending legal actions against one or more members of the
Partnership Group or involving or otherwise relating to the MLP Assets, BLPLC or the
Black Lake Pipeline;

provided, however, that, in the case of clauses (i) and (ii) above, such indemnification
obligations shall survive for three (3) years from the Closing Date; and that in the case of clause
(iii) above, such indemnification obligations shall survive until sixty (60) days after the
expiration of any applicable statute of limitations.

          (b) In addition to and not in limitation of the indemnification provided under this Article
II, the Partnership Group shall indemnify, defend, and hold harmless DEFS and its Subsidiaries,
other than any Subsidiary constituting part of the Partnership Group, from and against any Losses
suffered or incurred by DEFS and its Subsidiaries, other than any Subsidiary constituting part of
the Partnership Group, by reason of or arising out of events and conditions associated with the
operation of the MLP Assets or Black Lake Pipeline that occurs on or after the Closing Date;
provided that in no event shall the Partnership Group indemnify, defend or hold harmless DEFS and
its Subsidiaries pursuant to this Section 2.3(b) from and against any Losses relating to the Black
Lake Pipeline arising from or attributable to the 5% interest in BLPLC owned by DEFS and its
Subsidiaries from and after the Closing Date.

     2.4 Limitations Regarding Indemnification.

          (a) The aggregate liability of DEFS under Sections 2.1(a) shall not exceed $15.0 million (the
“Cap”).

          (b) No claims may be made against DEFS for indemnification pursuant to Sections 2.1(a) unless
the aggregate dollar amount of the Losses suffered or incurred by the Partnership Group or
Partnership Indemnitees exceed $250,000, after such time DEFS shall be liable for the full amount
of such claims, subject to the limitations of Section 2.4(a).

          (c) Notwithstanding anything herein to the contrary, in no event shall DEFS have any
indemnification obligations under this Agreement for claims made as a result of additions to or
modifications of Environmental Laws promulgated after the Closing Date.

     2.5 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 pursuant to this Article II,
they will provide notice thereof in writing to the Indemnifying Party specifying the nature of
and specific basis for such claim; provided, however, that the Indemnified Party shall not submit

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claims more frequently than once a calendar quarter (or twice in the case of the last calendar
quarter prior to the expiration of the applicable indemnity coverage under this Agreement).

          (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 set forth in 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 matter or any issues relating thereto; provided, however, that no such settlement shall
be entered into without the consent (which consent shall not be unreasonably withheld, conditioned
or delayed) of the Indemnified Party unless it includes a full release of the Indemnified Party
from such matter or issues, as the case may be.

          (c) The Indemnified Party agrees to cooperate fully with the Indemnifying Party with respect
to all aspects of the defense of any claims covered by the indemnification set forth in 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 names of the Indemnified Party to be utilized in connection with such defense, 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 the making available to
the Indemnifying Party of any employees 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 2.5. In no event shall the obligation of the Indemnified Party to
cooperate with the Indemnifying Party as set forth in the immediately preceding sentence be
construed as imposing upon the Indemnified Party an obligation to hire and pay for counsel in
connection with the defense of 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. The Indemnifying Party agrees to keep any
such counsel hired by the Indemnified Party reasonably informed as to the status of any such
defense, but the Indemnifying Party shall have the right to retain sole control over such defense.

          (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, (ii) all amounts recovered by the
Indemnified Party under contractual indemnities from third Persons and (iii) any proceeds realized
by the Indemnified Party from rate increases associated with the repair costs set forth in Section
2.2. The Partnership hereby agrees to use commercially reasonable efforts to realize any applicable
insurance proceeds, amounts recoverable under such contractual indemnities or recover any repair
costs incurred to comply with the Pipeline Safety Improvement Act of 2002 through the rates on the
Black Lake Pipeline or the SeaBreeze Pipeline.

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ARTICLE III

Reimbursement Obligations

     3.1 Reimbursement for Operating and General and Administrative Expenses.

          (a) DEFS hereby agrees to continue to provide the Partnership Group with certain general and
administrative services, such as legal, accounting, treasury, insurance administration and claims
processing, risk management, health, safety and environmental, information technology, human
resources, credit, payroll, internal audit, taxes and engineering. These general and
administrative services shall be substantially identical in nature and quality to the services of
such type previously provided by DEFS in connection with their management and operation of the MLP
Assets during the one-year period prior to the Closing Date.

          (b) Subject to the provisions of Section 3.3, the Partnership Group hereby agrees to reimburse
DEFS for all expenses and expenditures it incurs or payments it makes on behalf of the Partnership
Group for these general and administrative services.

          (c) The Partnership Group hereby agrees to reimburse DEFS for all other expenses and
expenditures it incurs or payments it makes on behalf of the Partnership Group, including, but not
limited to, (i) salaries of operational personnel performing services on the Partnership Group’s
behalf and the cost of employee benefits for such personnel, (ii) capital expenditures, (iii)
maintenance and repair costs and (iv) taxes.

          (d) The General Partner shall be entitled to allocate any such expenses and expenditures
between the Partnership Group, on the one hand, and DEFS, on the other hand, in accordance with the
foregoing provision on any reasonable basis.

     3.2 Reimbursement for Insurance. The Partnership Group hereby agrees to reimburse DEFS and
its Subsidiaries other than any Subsidiary constituting part of the Partnership Group for all
expenses it incurs or payments it makes on behalf of the Partnership Group and the Partnership
Indemnitees for (i) insurance coverage with respect to the MLP Assets and the Black Lake Pipeline
(excluding any insurance coverage relating to the 5% interest in BLPLC owned by DEFS and its
Subsidiaries from and after the Closing Date), (ii) insurance coverage with respect to claims
related to fiduciary obligations of officers, directors and control persons of the Partnership
Group and (iii) insurance coverage with respect to claims under federal and state securities laws.

     3.3 Limitations on Reimbursement.

          (a) The amount for which DEFS shall be entitled to reimbursement from the Partnership Group
pursuant to Section 3.1(b) for general and administrative expenses shall not exceed $4.8 million in
the aggregate in the first year following the date of this Agreement (the
“G&A Expenses Limit”). Thereafter, the G&A Expenses Limit shall be increased annually over
the next two years by the percentage increase in the Consumer Price Index – All Urban Consumers,
U.S. City Average, Not Seasonally Adjusted for the applicable year. In the event that the
Partnership Group makes any acquisitions of assets or businesses or the business of the Partnership
Group otherwise expands during the first three years following the date of this

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Agreement, then the G&A Expenses Limit shall be appropriately increased in order to account for adjustments in the
nature and extent of the general and administrative services by DEFS to the Partnership Group, with
any such increase in the G&A Expense Limit subject to the approval of the Conflicts Committee.
After the third anniversary of the date of this
Agreement, the General Partner will determine the
amount of general and administrative expenses that will be properly allocated to the Partnership in
accordance with the terms of the Partnership Agreement.

          (b) The obligation of the Partnership Group to reimburse DEFS and its Subsidiaries pursuant to
Section 3.2 shall not be subject to any monetary limitation.

ARTICLE IV

Continuance of Credit Support

     4.1 Credit Support. DEFS shall maintain in full force and effect any and all credit support
arrangements, including without limitation guarantees and letters of credit, in effect as of the
Closing Date with respect to (i) any derivative financial instruments, including swap contracts
relating to the price of natural gas, crude oil or natural gas liquids and other hedging contracts,
related to the business or operations of the Partnership Group until the earlier to occur of (A)
the fifth anniversary of the Closing Date or (B) such time as the MLP obtains a credit rating of at
least B1 by Moody’s Investors Services, Inc. or B+ by Standard & Poor’s Ratings Groups, a division
of The McGraw Hill Companies, with respect to any of its unsecured indebtedness and (ii) any
commercial contract related to the business or operations of the Partnership Group until the
expiration of such commercial contract, without giving effect to any renewal thereof beyond the
stated termination date of such contract.

ARTICLE V

Voting of DEFS’ Interest in BLPLC

     5.1 Voting of DEFS’ Interest in BLPLC. From and after the Closing Date and so long as DEFS
and its Subsidiaries own any interest in BLPLC, DEFS will, and will cause its Subsidiaries to,
vote, take action by written consent or take any other action pursuant to the terms of the
partnership agreement of BLPLC or otherwise with respect to any such interest in BLPLC as directed
in writing by the Partnership Group to DEFS.

ARTICLE VI

Miscellaneous

     6.1 Choice of Law; Submission to Jurisdiction. This Agreement shall be subject to and governed by the laws of the State of Colorado,
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 Party hereby submits to the
jurisdiction of the state and federal courts in the State of Colorado and to venue in Colorado.

     6.2 Notice. All notices, requests or consents provided for or permitted to be given pursuant
to this Agreement must be in writing and must be given by depositing same in the 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 telecopier or telegram

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to such Party. Notice given by personal delivery or mail shall be effective upon actual receipt. Notice
given by telegram or telecopier 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 6.2.

For notices to DEFS:

370 17th Street, Suite 2500

Denver, Colorado 80202

Phone: (303) 595-3331

Fax: (303) 605-2226

Attention: General Counsel

For notices to DCP LLC, the General Partner, the MLP or the OLP:

370 17th Street, Suite 2775

Denver, Colorado 80202

Phone: (303) 633-2900

Fax: (303) 633-2921

Attention: General Counsel

     6.3 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.

     6.4 Termination. Notwithstanding any other provision of this Agreement, if the General Partner is
removed as general partner of the Partnership under circumstances where Cause does not exist and
Units held by the General Partner and its Affiliates are not voted in favor of such removal, this
Agreement, other than the provisions set forth in Article II hereof, may immediately thereupon
be terminated by DEFS. The provisions of Article III of this Agreement shall also terminate upon a
Change of Control of DCP LLC, the General Partner or the MLP.

     6.5 Effect of Waiver or Consent. No waiver or consent, express or implied, by any Party to or
of any breach or default by any Person in the performance by such Person of its obligations
hereunder shall be deemed or construed to be a consent or waiver to or of any other breach or
default in the performance by such Person of the same or any other obligations of such Person
hereunder. Failure on the part of a Party to complain of any act of any Person or to declare any
Person in default, irrespective of how long such failure continues, shall not constitute a waiver
by such Party of its rights hereunder until the applicable statute of limitations period has run.

     6.6 Amendment or Modification. This Agreement may be amended or modified from time to time
only by the written agreement of all the Parties; provided, however, that the MLP

DCP MIDSTREAM PARTNERS, LP

Omnibus Agreement

-12-

 

and the OLP may
not, without the prior approval of the Conflicts Committee, agree to any amendment or modification
of this Agreement that, in the reasonable discretion of the General Partner, will adversely affect
the holders of Common Units. Each such instrument shall be reduced to writing and shall be
designated on its face an “Amendment” or an “Addendum” to this Agreement.

     6.7 Assignment; Third Party Beneficiaries. No Party shall have the right to assign its rights
or obligations under this Agreement without the consent of the other Parties. Each of the Parties
hereto specifically intends that DEFS and each entity comprising the Partnership Entities, as
applicable, whether or not a Party to this Agreement, shall be entitled to assert rights and
remedies hereunder as third-party beneficiaries hereto with respect to those provisions of this
Agreement affording a right, benefit or privilege to any such entity.

     6.8 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. All counterparts shall be
construed together and shall constitute one and the same instrument.

     6.9 Severability. If any provision of this Agreement or the application thereof to any Person
or circumstance shall be held invalid or unenforceable to any extent, the remainder of this
Agreement and the application of such provision to other Persons or circumstances shall not be
affected thereby and shall be enforced to the greatest extent permitted by law.

     6.10 Gender, Parts, Articles and Sections. Whenever the context requires, the gender of all words used in this Agreement shall include
the masculine, feminine and neuter, and the number of all words shall include the singular and
plural. All references to Article numbers and Section numbers refer to Articles and Sections of
this Agreement.

     6.11 Further Assurances. In connection with this Agreement and all transactions contemplated
by this Agreement, each Party 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.

     6.12 Withholding or Granting of Consent. Each Party may, with respect to any consent or
approval that it is entitled to grant pursuant to this Agreement, grant or withhold such consent or
approval in its sole and uncontrolled discretion, with or without cause, and subject to such
conditions as it shall deem appropriate.

     6.13 Laws and Regulations. Notwithstanding any provision of this Agreement to the contrary, no
Party shall be required to take any act, or fail to take any act, under this Agreement if the
effect thereof would be to cause such Party to be in violation of any applicable law, statute, rule
or regulation.

     6.14 Negation of Rights of Limited Partners, Assignees and Third Parties. The provisions of
this Agreement are enforceable solely by the Parties, and no limited partner, member, or assignee
of DEFS, the MLP or the OLP or other Person shall have the right, separate

DCP MIDSTREAM PARTNERS, LP

Omnibus Agreement

-13-

 

and apart from DEFS, the
MLP or the OLP, to enforce any provision of this Agreement or to compel any Party to comply with
the terms of this Agreement.

     6.15 No Recourse Against Officers or Directors. For the avoidance of doubt, the provisions of
this Agreement shall not give rise to any right of recourse against any officer or director of DEFS
or any Partnership Entity.

DCP MIDSTREAM PARTNERS, LP

Omnibus Agreement

-14-

 

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

	 	 	 	 	 	 	 
	 	 	DUKE ENERGY FIELD SERVICES, LLC	 	 
	 
	 	 	 	 	 	 
	 

	 	By:	 	 	 	 
	 

	 	 	 	 	 	 
	 	 	Name:	 	 
	 	 	Title:	 	 
	 
	 	 	 	 	 	 
	 	 	DCP MIDSTREAM GP, LLC	 	 
	 
	 	 	 	 	 	 
	 

	 	By:	 	 	 	 
	 

	 	 	 	 	 	 
	 	 	Name:	 	 
	 	 	Title:	 	 
	 
	 	 	 	 	 	 
	 	 	DCP MIDSTREAM GP, LP	 	 
	 
	 	 	 	 	 	 
	 

	 	By:
	 	DCP MIDSTREAM GP, LLC, its general partner	 	 
	 
	 	 	 	 	 	 
	 

	 	By:	 	 	 	 
	 

	 	 	 	 	 	 
	 	 	Name:	 	 
	 	 	Title:	 	 
	 
	 	 	 	 	 	 
	 	 	DCP MIDSTREAM PARTNERS, LP	 	 
	 
	 	 	 	 	 	 
	 

	 	By:
	 	DCP MIDSTREAM GP, LP, its general partner	 	 
	 
	 	 	 	 	 	 
	 

	 	By:
	 	DCP MIDSTREAM GP, LLC, its general partner	 	 
	 
	 	 	 	 	 	 
	 

	 	By:	 	 	 	 
	 

	 	 	 	 	 	 
	 	 	Name:	 	 
	 	 	Title:	 	 

 

 

	 	 	 	 	 	 	 
	 	 	DCP MIDSTREAM OPERATING, LP	 	 
	 
	 	 	 	 	 	 
	 

	 	By:
	 	DCP MIDSTREAM OPERATING GP, LLC, its general

partner	 	 
	 
	 	 	 	 	 	 
	 

	 	By:	 	 	 	 
	 

	 	 	 	 	 	 
	 	 	Name:	 	 
	 	 	Title:	 	 

DCP MIDSTREAM PARTNERS, LP

Omnibus Agreement

-2-exv10w5

 

Exhibit 10.5

SPECIFIC TERMS IN THIS EXHIBIT HAVE BEEN REDACTED BECAUSE

CONFIDENTIAL TREATMENT FOR THOSE TERMS HAS BEEN REQUESTED. THE

REDACTED MATERIAL HAS BEEN SEPARATELY FILED WITH THE SECURITIES

AND EXCHANGE COMMISSION, AND THE TERMS HAVE BEEN MARKED AT THE

APPROPRIATE PLACE WITH [CONFIDENTIAL].

NATURAL GAS GATHERING AGREEMENT

     THIS AGREEMENT, is made and entered into this 1st day of June, 1987, by and
between CORNERSTONE NATURAL GAS COMPANY, a Delaware corporation, (hereinafter referred to as
“Gatherer”) and PHILLIPS PETROLEUM COMPANY, a Delaware corporation, (hereinafter referred
to as “Producer”) both hereinafter collectively referred to as the “Parties”, and individually as a
“Party”.

W I
T N E S S E T
H :

     WHEREAS, Producer desires that Gatherer gather volumes of gas produced from wells in a certain
specified area; and

     WHEREAS, Gatherer will have available as a gathering system in such area and agrees to gather
such gas for Producer in accordance with the terms and conditions hereinafter set forth;

     NOW, THEREFORE, in consideration of the mutual covenants herein contained, together with the
other good and valuable consideration, the receipt and sufficiency of which is hereby acknowledged
by both Gatherer and Producer, the Parties hereto do hereby agree as follows:

ARTICLE I

DEFINITIONS

     For the purposes of this Agreement, the following definitions shall be applicable.

     1.1 The term “gas” shall include casinghead gas produced with crude oil, natural gas from gas
wells and residue gas resulting from processing both casinghead gas and gas well gas.

 

 

     1.2 A “day” shall begin at 7:00 a.m. local time on each calendar day and end at 7:00 a.m.
local time on the following calendar day; a “month” shall mean that period of time beginning at
7:00 a.m. local time on the first day of a calendar month and ending at 7:00 a.m. local time on the
first day of the following calendar month; a “year” shall mean a period of twelve (12) consecutive
months beginning on the first day of the month during the occurrence of initial deliveries of gas
hereunder; each succeeding year shall be a succeeding twelve (12) month period; provided, however,
the last year of this Agreement shall end at the termination hereof as provided in Article IX of
this Agreement.

     1.3 The term “MCF” shall mean one thousand (1,000) cubic feet, and MMCF shall mean one million
(1,000,000) cubic feet, at a pressure of fifteen and twenty-five thousandths (15.025) psia and at a
temperature of sixty degrees (60o) Fahrenheit.

     1.4 The term “BTU” shall mean British Thermal Units.

     1.5 The term “MMBTU” shall mean 1,000,000 BTU’s.

     1.6 The term “Heating Value” shall mean the gross number of BTU’s which would be contained in
a volume of one (1) cubic foot of gas at a temperature of sixty degrees (60o) Fahrenheit when
saturated with water vapor and under a pressure of fifteen and twenty-five thousandths (15.025)
pounds per square inch absolute and adjusted to reflect the actual water vapor content of the gas
delivered; however, if the water vapor content is seven (7) pounds per million cubic feet or less,
the gas shall be deemed dry.

     1.7 The term “psig” shall mean pounds per square inch gauge.

     1.8 The term “psia” shall mean pounds per square inch absolute.

     1.9 “Equivalent Quantities” shall mean the quantities of gas delivered to Producer by Gatherer
at the Points of Delivery, which quantities shall be volumetric equivalent, as measured

2

 

in MMBTU’s of the quantities of gas received by Gatherer at the Points of Receipt, less and
except such quantities of gas (measured in MMBTU) retained by Gatherer as an allowance for
compressor fuel and line loss as provided in section 6.2.

     1.10 “Points of Receipt” shall mean the point or points, as described in paragraph 3.1, at
which Producer will deliver or cause to be delivered, and Gatherer will receive, the volumes of gas
produced from wells subject to this Agreement.

     1.11 “Points of Delivery” shall mean the point or points, as described in paragraph 3.2, at
which Gatherer will redeliver the gas gathered hereunder to Producer or for its account.

     1.12 “Ada System” shall meant that gathering system shown in heavy red lines on Exhibit “A”
attached hereto.

     1.13 “Ada Field” shall mean that area lying within the heavy black lines on Exhibit “A”
attached hereto.

     1.14 “Payout Period” shall mean that period of time commencing as of the date first
hereinabove written and continuing until such time as there has been gathered and delivered through
the Ada System a total volume of gas equal to twenty-three billion cubic feet, said total volume to
include Producer’s gas and gas of third-parties produced from wells located within the Ada Field,
as herein defined. There shall not be credited against said twenty-three (23) billion cubic feet
amount any gas produced from wells located in areas outside such Ada Field, as herein defined.

     1.15 The terms “gas owned or controlled by Producer” or “Producer’s gas” shall mean all gas
produced from wells located in the Ada Field, as herein defined, in which Producer now owns or
hereafter acquires an ownership interest or which Producer now has or hereafter acquires the right
to sell or the right to control the gathering thereof; provided, however, there

3

 

shall not be included within such terms any gas which Producer has, prior to June 1, 1987,
dedicated or committed to third parties by contracts which prevent Producer from performing
hereunder with respect to such gas, it being further provided that such committed or dedicated gas
shall be included within such terms upon the termination of such contracts or other release
therefrom.

ARTICLE II

GATHERING

     2.1 Upon the execution hereof, Gatherer shall proceed with due diligence to make available and
to have operational all of the facilities necessary to perform the services contemplated hereunder.
In the event that said facilities are not available and operational within one hundred and twenty
(120) days following the date first hereinabove written (said one hundred and twenty day period to
be extended for periods of delay due to events of force majeure as defined in Article XII),
Producer shall have the right to terminate this Agreement in accordance with the procedures and
subject to the conditions hereinafter set forth.

	 	a.	 	Producer’s right of termination shall be effected by giving to Gatherer not
less than ninety days written notice of Producer’s intent to terminate this Agreement.
Said written notice shall be served upon Gatherer after the expiration of the
above-referenced 120-day period (as such period may be extended by reasons of force
majeure).
	 
	 	b.	 	Gatherer shall have a period of ninety days (such ninety day period to be
extended during periods of delay due to events of force majeure as defined in Article
XII) (such period to be hereinafter referred to as the “Notice Period”) following
Gatherer’s receipt of Producer’s written notice to make available and operational all
facilities necessary to perform the services contemplated hereunder. Should

4

 

	 	 	 	Gatherer have such facilities available and operational prior to the expiration of
the Notice Period, as such period may be extended by force majeure, then this
Agreement shall not terminate but shall continue in full force and effect in
accordance with its terms.
	 
	 	c.	 	Notwithstanding the provisions of subparagraph b above, in the event that the
facilities are not available and operational upon the expiration of the Notice Period,
Gatherer shall have the right, but not the obligation, to extend the period of time
allowed to have the facilities available and operational beyond the Notice Period by
serving written notice upon Producer on or before the last day of the Notice Period of
Gatherer’s intent to continue to proceed under this Agreement. In the event that
Gatherer makes such election, and serves written notice upon Producer as herein
provided, Gatherer shall pay to Producer a penalty of five hundred dollars ($500.00)
per day for each day of such extension until the earlier of: (i) the date upon which
such facilities become available and operational, or (ii) the date upon which Gatherer
serves a subsequent written notice upon Producer stating that Gatherer is abandoning
the project and terminating this Agreement. Gatherer shall pay to Producer any amounts
due hereunder within ten days following the occurrence of either of the
above-referenced events.

In the event that this Agreement is terminated in accordance with the procedures set forth above,
this Agreement shall be of no further force or effect and neither Party hereto shall have any
further rights or obligations hereunder, save and except the obligation of Gatherer to pay for any
periods of extension as provided in subparagraph c above.

5

 

     2.2 Upon the first day that such facilities become operational, and continuing thereafter for
the term of this Agreement, [CONFIDENTIAL] as herein provided. Subject to the other terms hereof,
Gatherer agrees to receive, at the Points of Receipt all such gas owned or controlled by Producer
within said area, and to deliver Equivalent Quantities of gas to Producer (or for its account) at
the Points of Delivery. Such agreements by Producer and by Gatherer apply both to wells presently
producing within said area and to wells hereafter drilled during the term of this agreement within
said area which are connected to the Ada System as provided in paragraph 2.3 below. As stated in
Section 1.9 hereof, “Equivalent Quantities” refers to that same quantity of gas as was made
available by Producer to Gatherer at the various Points of Receipt, less the allowance for
compressor fuel and line loss, as provided in Section 6.2 hereof.

     2.3 As to wells hereafter drilled during the term of this Agreement and as to any wells from
which gas is currently being produced, such gas production, however, not being “gas owned or
controlled by Producer” as defined in Paragraph 1.15 as of the date hereof but hereafter being
included within such definition, Gatherer agrees to have each such well connected to the Ada System
within ninety (90) days of Gatherer’s receipt of: (i) all deliverability information; (ii) a plat
showing the precise well location; and (iii) a specific written notice by Producer that such well
is ready for connection; provided, that such obligation of Gatherer to connect such wells is
subject to the following: (1) extension of the ninety (90) day period due to events of force
majeure, including but not limited to difficulties in obtaining rights-of-way; and (2) Gatherer
shall not be obligated to connect any well unless such well is determined by Gatherer, in its sole
opinion, to be capable of producing a minimum of one billion cubic feet of gas owned or controlled
by Producer for each single mile of gathering line which is required to be laid. In the event that
Gatherer determines that any well is not capable of producing at least

6

 

one billion cubic feet of gas owned or controlled by Producer for each mile of gathering line
required and elects not to connect such well in accordance herewith, Producer shall have the right,
at its sole cost, risk and expense to construct the necessary facilities required to connect such
well to Gatherer’s Ada System. Gatherer hereby agrees that at such time, if ever, that the well
connected by Producer produces a volume of one billion cubic feet of gas owned or controlled by
Producer for each mile of gathering line constructed for such well, Gatherer will reimburse
Producer for Producer’s actual documented out-of-pocket cost of constructing the facilities
necessary to connect the well in an amount up to, but not to exceed eighty thousand dollars per
mile of gathering line constructed. Upon such payment, Producer shall, at Gatherer’s request,
convey to Gatherer the subject facilities by the execution of mutually agreeable documents of
title.

     2.4 Subject to all other provisions of this Agreement, Producer shall make available to
Gatherer at the Points of Receipt, and Gatherer shall receive such daily quantities of gas owned or
controlled by Producer and produced from wells located in the Ada Field. Gatherer shall, as nearly
as practicable each day, given the operating requirements and constraints of Gatherer’s Ada System,
redeliver to Producer, or for its account, and Producer shall accept (or cause to be accepted)
delivery at the Points of Delivery Equivalent Quantities of gas, such being the quantity of gas
received, less the quantity of gas retained by Gatherer as an allowance for compressor fuel and
line loss as provided in paragraph 6.2.

ARTICLE III

POINT OF RECEIPT AND DELIVERY

     3.1 The Points of Receipt for gas gathered hereunder shall be at the inlet flange of
Gatherer’s facilities at the points of interconnection between the gathering facilities of Gatherer
with the facilities of Producer at each well and at other mutually agreeable points.

7

 

     3.2 The Points of Delivery for gas gathered hereunder shall be at Gatherer’s outlet flange of
the measurement and delivery facilities to be located at a point of interconnection of Gatherer’s
gathering facility with the Texas Gas Transmission Company’s twenty-inch pipeline, or some facility
connected thereto, and at any other mutually agreeable points.

     3.3 Points of Receipt and Delivery may be at existing points through which other volumes of
gas are being measured; therefore, the measurement of gas under this Agreement may involve the
allocation of gas deliveries. Each Party hereto will furnish or cause to be furnished to the other
Party hereto all data required to accurately account for all gas received and delivered hereunder.

ARTICLE IV

PRESSURE

     4.1 Producer shall deliver gas to Gatherer at the Points of Receipt at pressures sufficient to
effect delivery of said gas; provided, however, Producer shall in no event be required to deliver
gas at pressures in excess of 500 psig, nor shall Producer deliver gas at pressures in excess of
1,100 psig.

     4.2 Gatherer shall deliver gas to Producer, or for its account, at pressures sufficient to
effect delivery of said gas at the Points of Delivery; provided, however, Gatherer shall in no
event be required to deliver gas at pressures in excess of 1,000 psig.

ARTICLE V

QUALITY OF GAS

     5.1 The Parties hereto agree that Producer is obligated to make available to Gatherer gas
which is merchantable and which will, upon delivery, be commercially free of dust, gum, gumforming
constituents, gasoline, water and any other substance of any kind that may become

8

 

separated from the gas during the handling thereof, and such gas shall conform to the
following specifications:

	 	 	 	 	 	 	 
	 

	 	a.
	 	dust, rust and other solids
	 	none;
	 
	 	 	 	 	 	 
	 

	 	b.
	 	carbon dioxide
	 	not more than 3% by volume;
	 
	 	 	 	 	 	 
	 

	 	c.
	 	oxygen
	 	not more than 2/10 of 1% by volume;
	 
	 	 	 	 	 	 
	 

	 	d.
	 	hydrogen sulfide
	 	not more than 1/4 grain per 100 cubic feet;
	 
	 	 	 	 	 	 
	 

	 	e.
	 	total sulfur
	 	not more than 20 grains per 100 cubic feet;
	 
	 	 	 	 	 	 
	 

	 	f.
	 	free water
	 	none;
	 
	 	 	 	 	 	 
	 

	 	g.
	 	heating value
	 	not less than 950, nor more than 120° BTU per Mcf;
	 
	 	 	 	 	 	 
	 

	 	h.
	 	temperature
	 	not more than 120° F, nor less than 40° F;
	 
	 	 	 	 	 	 
	 

	 	i.
	 	water vapor
	 	not more than 7# per million cubic feet;
	 
	 	 	 	 	 	 
	 

	 	j.
	 	nitrogen
	 	not more than 3% by volume.

     5.2 In addition to the above-specifications, all gas delivered to Gatherer shall also conform
to the quality specifications required by any transporting pipeline at the Points of Delivery. If,
at any time, the quality of the gas delivered hereunder is such that it does not meet both the
requirements of Gatherer as stated herein, and the requirements of any such transporting pipeline,
Gatherer, at its option, may refuse to accept deliveries of said gas until Producer corrects such
condition. Gatherer shall give Producer notice of such nonspecification gas before refusing to
accept deliveries.

9

 

ARTICLE VI

GATHERING FEE

     6.1 The fee which Producer shall pay to Gatherer for the gathering and redelivery of gas as
described herein shall be as follows:

     a. during the Payout Period, as herein defined, Producer shall pay the following fees
according to the indicated volumes:

	 	(i)	 	during each calendar month in which Producer’s average daily
delivery of gas to Gatherer at the Points of Receipt is less than 18 MMCF, the
gathering fee shall be twenty-two cents ($0.22) per MCF;
	 
	 	(ii)	 	during each calendar month in which Producer’s average daily
delivery of gas to Gatherer at the Points of Receipt equals or exceeds 18 MMCF,
but is less than 27 MMCF, the gathering fee shall be eighteen cents ($0.18) per
MCF; and
	 
	 	(iii)	 	during each calendar month in which Producer’s average daily
delivery of gas to Gatherer at the Points of Receipt equals or exceeds 27 MMCF,
then said gathering fee shall be sixteen cents ($0.16) per MCFI.

     b. At the conclusion of the Payout Period, commencing at 7:00 a.m. on the morning
following the final day of the Payout Period, the gathering fee payable hereunder for all of
Producer’s gas shall be fixed at fifteen ($0.15) cents per MCF for the remaining term of
this Agreement.

In computing the average daily deliveries for the purpose of calculating the fee per MCF due to
Gatherer under this Paragraph 6.1, there shall not be included in the average daily delivery
calculation any day or days (nor any volumes of gas delivered to Gatherer on such day or days)
during which Gatherer’s performance hereunder was interrupted in whole or in part by reasons of

10

 

force majeure; provided, that if during such day or days of interruption, Producer had available
for delivery to Gatherer volumes of gas in excess of those volumes actually received by Gatherer,
Producer shall pay Gatherer the applicable fee, calculated in accordance with the foregoing, for
each MCF of Producer’s gas produced and delivered to Gatherer at the Points of Receipt less the
three percent (3%) retained by Gatherer as an allowance for compressor fuel and line loss as
provided in paragraph 6.2 below.

     6.2 As additional consideration for the gathering of gas hereunder, Gatherer shall retain
three percent (3%) of that quantity of gas (measured on an MMBtu basis) delivered to Gatherer at
the Points of Receipt as an allowance for the compressor fuel and line loss. Accordingly, Gatherer
shall redeliver to Producer, or for its account, at the Points of Delivery, Equivalent Quantities
of gas which shall be that volume of gas gathered by Gatherer at the Points of Receipt, less such
three percent (3%) retained hereunder for compressor fuel and line loss.

ARTICLE VII

BILLINGS AND PAYMENTS

     7.1 On or before the twenty-fifth (25th) day of each month following the date on which the
gathering of gas commenced hereunder, Gatherer shall render to Producer a statement for the
preceding month properly identifying the applicable receipt location(s) and showing the daily and
total volume of gas received and gathered for Producer hereunder and the amount due therefor.

     7.2 Producer shall pay Gatherer for services rendered hereunder, at Gatherer’s address given
in Article X, on or before the last day of each such month.

     7.3 Each Party hereto shall have the right at any and all reasonable times to examine the
books and records of the other Party to the extent necessary to verify the accuracy of any
statement, charge, computation or demand made under or pursuant to this Agreement; provided,

11

 

however, that any such statement or charge hereunder shall be final as to both Parties unless
questioned within two (2) years from the date such is paid.

ARTICLE VIII

MEASUREMENT AND TESTS

     The measurement and tests for quality of gas received and delivered hereunder shall be
governed by the following:

     8.1 The volume shall be measured by orifice meters with linear charts, 24-hour rotation, or
other mutually agreeable measuring devices installed and operated, and computations made, as
prescribed by the American Petroleum Institute and published as Gas Measurement Committee Report
No. 3, American Gas Association, as revised and reprinted in September 1969, including any
appendices or amendments thereto, or such other method as may be mutually acceptable.

     8.2 The unit of volume for purposes of measurement shall be one (1) cubic foot of gas at a
temperature base of sixty degrees (60°) Fahrenheit and at a pressure base of fifteen and
twenty-five thousandths (15.025) pounds per square inch absolute.

     8.3 The arithmetical average of the hourly temperature recorded during each day, and if a
recording gravitometer is installed, the hourly specific gravity recorded each day, the factors for
the average hourly temperature and specific gravity according to the latest test therefor and the
correction for deviation from Boyle’s Law applicable during each day shall be used to make proper
computations of volumes hereunder. Chart integration and volume computations shall be made by the
Party (or its agent) that owns the measurement facilities at the Points of Receipt and Points of
Delivery as accurately as possible and within the accuracy prescribed by the manufacturer of the
computing equipment used.

12

 

     8.4 Temperature shall be determined by a twenty-four (24) hour continuously recording
thermometer installed so as to record the temperature of the gas flowing through the meters. The
average temperature, to the nearest one degree (1°) Fahrenheit, obtained while gas is being
delivered, shall be the applicable flowing gas temperature for the twenty-four (24) hour period
under consideration.

     8.5 The specific gravity of the gas delivered hereunder shall be determined at each point of
measurement by spot tests made with an instrument of standard manufacture acceptable to the parties
or by a recording gravitometer or other mutually agreeable means. If spot tests are made, the
specific gravity of the gas delivered hereunder shall be determined monthly or as frequently as is
found necessary in practice to insure accurate measurement.

     8.6 Adjustment for the effect of supercompressibility shall be determined by test or by mutual
consent of the parties hereto according to the provisions of said Report No. 3, hereinabove
identified for the average conditions of pressure, flowing temperature and specific gravity at
which the gas was measured during the period under consideration and with the respective
proportionate values for carbon dioxide and nitrogen fraction values and to obtain subsequent
values of these components as may be required from time to time.

     8.7 The BTU content of the gas shall be determined by using a continuous accumulator, a spot
sample, a continuously recording calorimeter, or any other method in general use in the gas
industry. Any recording calorimeter required shall be at the Point(s) of Delivery.

     8.8 Tests to determine sulfur, hydrogen sulfide, oxygen, carbon dioxide, nitrogen and water
content shall be made by approved standard methods in general use by the gas industry. Such tests
shall be made at the request of any party hereto.

13

 

     8.9 All new measuring and testing equipment, housing devices and materials shall be of
standard manufacture and type and shall, with all related equipment, appliances and buildings, be
installed, maintained and operated or caused to be installed, maintained and operated by Gatherer
at the Points of Receipt and by Producer, Gatherer, or such other third persons owning or
controlling same at the Points of Delivery. Either Party may install and operate check measuring
and testing equipment, which shall not interfere with the use of equipment of the Party responsible
for measurement at the point.

     8.10 The accuracy of the measuring and testing equipment shall be verified at least once each
month and at other times upon request of Producer or Gatherer. Tests for quality of the gas may be
made at times of testing equipment or at other times. Notices of the time and nature of each test
shall be given by the measuring Party sufficiently in advance to permit convenient arrangement for
the witnessing Party to have a representative present. Measuring and testing equipment shall be
tested by means and methods approved by both Producer and Gatherer (which approval shall not be
unreasonably withheld). Tests and adjustments shall be made in the presence of and observed by
representatives of both Parties, if present. If after proper notice, Producer or Gatherer fails to
have a representative present, the results of the tests shall nevertheless be considered accurate
until the next tests are made. All regular monthly tests of measuring equipment shall be made at
the expense of the owner of same. All tests made at the special request of a Party shall be made
at the expense of the Party requesting same.

     8.11 If at any time any of the measuring or testing equipment is found to be out of service or
registering inaccurately in any percentage, it shall be adjusted at once to read accurately within
the limit prescribed by the manufacturer. If such equipment is out of service or inaccurate by an
amount exceeding two percent (2%) at any reading or upon any test, registration

14

 

thereof and any payment based thereon shall be corrected at the rate of such inaccuracy for
any period which the Parties agree upon, and if the Parties cannot agree, then for a period
extending back one-half (1/2) of the time elapsed since the date of the last calibration, not
exceeding, however, sixteen (16) days. The volume of gas received during such period shall be
estimated: (i) by using the data recorded by any check measuring equipment if installed arid
accurately registering; or, if not installed or if registering inaccurately, (ii) by correcting the
error if the percentage of error is ascertainable by calibration, test or mathematical calculation;
or, if neither such method is feasible, (iii) by estimating the quantity delivered based upon
deliveries under similar conditions during a period when the equipment was registering accurately.
No adjustment shall be made for recorded inaccuracies of two percent (2%) or less.

     8.12 Each Party hereto shall have the right to inspect equipment installed or furnished by the
other Party or third parties and the charts and other measurement or testing data of all such
parties at all times during business hours; but the reading, calibration and adjustment of such
equipment and changing of charts shall be done only by the Party installing and furnishing the
same. Each Party hereto shall preserve all original test data, charts and other similar records in
such Party’s possession for a period of at least twenty-four (24) months.

ARTICLE IX

TERM

     9.1 Subject to all of the terms and conditions contained herein, this Agreement shall remain
in full force and effect for a primary term of ten (10) years from the date first hereinabove
written, and shall continue year to year thereafter unless and until either Party terminates this
Agreement effective at the end of such ten (10) year primary term or any successive one (1) year
term by giving written notice of same at least thirty (30) days prior to the last day thereof.

15

 

ARTICLE X

NOTICE

     10.1 Any notice, request, statement, correspondence or payment provided for in this Agreement
shall be given in writing, delivered in person or by United States mail to the Parties hereto at
the addresses shown below or at such other addresses as may be hereafter furnished by one Party to
the other Parties in writing. Notices shall be effective as of the date same is received.

	 	 	 	 	 
	 

	 	PRODUCER —
	 	NOTICES AND CORRESPONDENCE:
	 

	 	 	 	Phillips 66 Natural Gas Company
	 

	 	 	 	P.O. Box 1967
	 

	 	 	 	Houston, Texas 77251-1967
	 
	 	 	 	 
	 

	 	 	 	STATEMENTS AND BILLING:
	 

	 	 	 	Phillips 66 Natural Gas Company
	 

	 	 	 	910 G-POB
	 

	 	 	 	Bartlesville, Oklahoma 74004
	 
	 	 	 	 
	 

	 	GATHERER —
	 	Cornerstone Natural Gas Company
	 

	 	 	 	8080 N. Central Expressway
	 

	 	 	 	Twelfth Floor, L. B. 47
	 

	 	 	 	Dallas, Texas 75206

ARTICLE XI

WARRANTY OF TITLE

     11.1 Producer hereby warrants that it has good title and the right to produce and deliver all
the gas received by Gatherer hereunder free and clear of all liens, encumbrances and claims
whatsoever and agrees to indemnify Gatherer against any loss or cost incurred by it on account of
any such liens, encumbrances and claims whatsoever. Gatherer warrants that at the time of delivery
for the account of Producer the gas delivered hereunder shall be free and clear of all liens,
encumbrances and claims whatsoever resulting from Gatherer’s receipt and gathering of

16

 

the gas pursuant to this Agreement and agrees to indemnify Producer against any loss or cost
incurred by it on account of any such liens, encumbrances and claims whatsoever.

ARTICLE
XII

FORCE MAJEURE

     12.1 If either Party is rendered unable, wholly or in part, by force majeure or any other
cause of any kind not reasonably within its control, other than financial, to perform or comply
with any obligation or condition of this Agreement, upon giving notice and reasonably full
particulars to the other Party, as soon as reasonably possible, such obligation or condition shall
be suspended during the continuance of the inability so caused and such Party shall be relieved of
liability and shall suffer no prejudice for failure to perform the same during such period;
provided, obligations to make any payment then due for gas gathered and delivered hereunder shall
not be suspended. The cause for suspension (other than labor disputes, strikes or lockouts) shall
be remedied so far as possible with reasonable dispatch. Settlement of strikes, lockouts and labor
disputes shall be wholly within the discretion of the Party having the difficulty. The term “force
majeure” shall include, without limitation by the following enumeration, acts of God and the public
enemy, the elements, fire, accidents, breakouts, strikes and any other industrial, civil or public
disturbance, inability to obtain or delay in obtaining rights-of-way, material, supplies, permits
or labor, failure of equipment or markets, any act or omission by parties not subject to control by
the Party having the difficulty, and any laws, orders, rules, regulations, acts or restraints of
any government or governmental body or authority, civil or military.

ARTICLE XIII

GOVERNMENTAL RULES, REGULATIONS, AND AUTHORIZATIONS

     13.1 This Agreement is subject to all valid orders, laws, rules and regulations of duly
constituted governmental authorities having jurisdiction or control over the Parties, their

17

 

facilities or gas supplies, this Agreement or any provisions hereof. If at any time during
the term hereof, any such governmental authority shall take any action as to either Party which
subjects the receipt or delivery of gas hereunder to terms, conditions, restraints or regulations,
including rate or price controls or ceilings that in the sole judgment of the Party affected are
unduly burdensome to that Party, such Party may cancel and terminate this Agreement without further
liability hereunder.

     13.2 The Parties agree to timely file and prosecute all applications, statements and notices
required by any governmental regulatory authority having appropriate and applicable jurisdiction.

ARTICLE XIV

MISCELLANEOUS

     14.1 Any modification of terms or amendment of provisions shall become effective only upon
execution, by both Gatherer and Producer, of a supplemental written agreement.

     14.2 No waiver by Producer or Gatherer of any default of the other under this Agreement shall
operate as a waiver of any other default, whether of a like or a different character.

     14.3 As between the Parties hereto, Producer shall be in control and in possession of the gas
prior to such gas being received by Gatherer at the Points of Receipt and responsible for any
damages, losses or injuries caused thereby, except injuries and damages which shall be occasioned
solely and proximately by the negligent acts or omissions of Gatherer. Between the Points of
Receipt of said gas and the Points of Delivery, Gatherer shall be deemed to be in exclusive control
and possession of such gas and responsible for any injuries or damages caused thereby, except
injuries and damages which shall be occasioned solely and proximately by the negligent acts or
omissions of Producer (or its agents). At the Points of Delivery of said gas to

18

 

Producer (or its nominees) by Gatherer, and thereafter, Producer shall be deemed to be in
exclusive control and possession of such gas and responsible for any injuries or damages caused
thereby, except injuries and damages which shall be occasioned solely and proximately by the
negligent acts or omissions of Gatherer.

     14.4 This agreement to gather gas for Producer, as provided herein, shall not prevent Gatherer
from making similar gathering agreements, or amendments to existing agreements with other parties.

     14.5 As to all matters of construction and interpretation, this Agreement shall be
interpreted, construed and governed by the laws of the State of Texas.

     14.6 This Agreement may be assigned by either Party hereto but no assignment shall relieve
such Party of its obligations hereunder without the written consent of the other Parties. No
assignment of this Agreement shall be effective as to the other Party until 30 days after written
notice of same is received by the non-assigning Party.

     14.7 Gatherer is acting hereunder as an independent contractor and nothing contained herein
shall be construed or is intended to create a partnership, joint venture or relationship other than
that of Gatherer as an independent contractor, as between the Parties hereto.

19

 

     IN WITNESS WHEREOF, the Parties hereto have executed this Agreement as of the day and year
first hereinabove written.

	 	 	 	 	 	 	 
	 	 	CORNERSTONE NATURAL GAS COMPANY	 	 
	 
	 	 	 	 	 	 
	 

	 	By:
	 	/s/ Kelcy L. Warren
 

Kelcy L. Warren
	 	 
	 

	 	 	 	President	 	 
	 
	 	 	 	 	 	 
	 	 	PHILLIPS PETROLEUM COMPANY	 	 
	 
	 	 	 	 	 	 
	 

	 	By:

Its:
	 	/s/ C. B. Friley
 

Attorney-In-Fact
	 	 

20

 

ACKNOWLEDGEMENTS

	 	 	 	 	 	 	 
	STATE OF OKLAHOMA

	 	 	)	 	 	 
	 

	 	 	)	 	 	 
	COUNTY OF WASHINGTON

	 	 	)	 	 	 

     Personally appeared before me, the undersigned Notary Public in and for the State and County,
the within named C. B. Friley, Attorney-In-Fact, of Phillips Petroleum
Company, who acknowledged that he signed and delivered the foregoing instrument on the day and
year therein mentioned, as the free and voluntary act and deed of said corporation, being thereunto
duly authorized.

     Given under my hand and seal this 19th day of May, 1987.

	 	 	 	 	 
	 

	 	 

Connie D. Pignet
	 	 
	 

	 	Notary Public	 	 

My Commission Expires 9-19-88

	 	 	 	 	 	 	 
	STATE OF

	 	 	)	 	 	 
	 

	 	 	)	 	 	 
	COUNTY OF

	 	 	)	 	 	 

     Personally appeared before me, the undersigned Notary Public in and for the State and County,
the within named Kelcy L. Warren, President of Cornerstone Natural Gas
Company, who acknowledged that he signed and delivered the foregoing instrument on the day and
year therein mentioned, as the free and voluntary act and deed of said corporation, being thereunto
duly authorized.

     Given under my hand and seal this 1st day of June, 1987.

	 	 	 	 	 
	 

	 	 

Kimberly H. Johnson
	 	 
	 

	 	Notary Public	 	 

My Commission Expires 2-9-91

21

 

EXHIBIT A

ADA FIELD AND SYSTEM

Webster and Bienville Parishes, Louisiana

[CONFIDENTIAL]

A-1

 

 

     THIS Amendment to the Natural Gas Gathering Agreement dated June 1, 1987, by and between
NATURAL GAS COMPANY, as Gatherer, and PHILLIPS PETROLEUM COMPANY, as Producer, is made and entered
into effective January 1, 1989.

WITNESSETH:

     WHEREAS, Producer is drilling and completing wells on acreage committed under the Natural Gas
Gathering Agreement that will produce gas at pressures sufficient to avoid compression by Gatherer;

     NOW, THEREFORE, in consideration of the mutual covenants contained hereinafter, Gatherer and
Producer do hereby agree the terms and conditions of the Natural Gas Gathering Agreement cited
above are amended as follows:

1. In the event Producer drills and completes wells capable of delivering gas at pressures
considerably greater than Gatherer’s compressor discharge pressure, then Producer will
advise Gatherer of said well’s delivery pressure capability in conjunction with Producer’s
request to Gatherer to connect the well to Gatherer’s Ada System (as defined in the
Agreement).

2. If Gatherer desires to connect said well to that portion of its Ada System that accepts
gas at the Points of Receipt and redelivers gas at the Points of Delivery without being
compressed, hereinafter defined as Gatherer’s “High Pressure Ada System”, then Producer and
Gatherer shall

i) Raise the maximum Point of Receipt pressure specified in Article 4.1 of the
Agreement from 500 psig to 1000 psig, as it applies only to those wells entering
Gatherer’s High Pressure Ada System, and

ii) Reduce the fuel and line loss quantity specified in Article 6.2 of the Agreement
from three percent (3%) to zero percent (0%) as it applies only to gas from those
wells entering Gatherer’s High Pressure Ada System.

3. If, in the future, Producer determines that any well then connected to Gatherer’s High
Pressure Ada System is incapable of satisfactorily producing gas against the pressure
maintained therein, then upon request by Producer, Gatherer will disconnect said well from
its High Pressure Ada System and reconnect the well to its Ada System. Furthermore, the
Agreement conditions affecting Point of Receipt pressure and fuel and line loss as amended
herein shall revert to those of the Agreement as they apply to that well.

 

 

4. The terms and conditions as amended herein shall immediately apply to the following four
(4) wells:

[CONFIDENTIAL]

     Producer and Gatherer agree to this Amendment as stated above by executing two (2) originals
of this document in the space provided below.

	 	 	 
	GATHERER:	 	PRODUCER:
	 
	CORNERSTONE NATURAL GAS COMPANY

	 	PHILLIPS PETROLEUM COMPANY

	 	 	 	 	 	 	 	 	 	 	 
	By:

	 	/s/ Kelcy L. Warren
	 	 	 	By:
	 	/s/ H. F. Zeiler	 	 
	Title:

	 	 

President
	 	 
	 	Title:
	 	 

Attorney-in-Fact
	 	 
	Date:

	 	9-27-89
	 	 	 	Date:
	 	February 21, 1989	 	 
	WITNESS:	 	 	 	WITNESS:	 	 
	/s/ Vanessa Replogle	 	 	 	/s/ Karen R. Toby	 	 

3

 

[CORNERSTONE NATURAL GAS COMPANY LETTERHEAD]

October 29, 1993

Phillips Petroleum Company

Post Office Box 1967

Houston, TX 77251-1967

			
	Re:	 	Gas Gathering Agreement by and between Cornerstone Natural Gas
Company and Phillips Petroleum Company, Dated June 1, 1987,

Contract Number CGGA-1000

Ladies and Gentlemen:

As you may be aware, Endevco, Inc. and certain of its subsidiaries, excluding however, Cornerstone
Natural Gas Company, filed for relief under Chapter 11 of the United States Bankruptcy code on June
4, 1993. A confirmation hearing on Endevco’s First Amended Joint Plan of Reorganization was held
on September 27 and 29, 1993 at which time the Court confirmed the Plan and ordered Endevco, Inc.
and certain of its subsidiary corporations to immediately begin implementing the Plan.

Endevco, Inc.’s First Amended Joint Plan of Reorganization requires certain of Endevco, Inc.’s and
various subsidiary corporations’ assets including the Cornerstone Natural Gas Company contract
referenced above (the “Contract”) to be distributed (“Distribution Assets”) according to the
direction of holders (“Noteholders”) of certain Senior and Subordinated Notes of Endevco, Inc. The
Noteholders have in turn directed that the Distribution Assets be conveyed to Associated Natural
Gas Corporation (ANGC) or its subsidiaries, which has its principal offices in Denver, Colorado.

 

 

October 29, 1993

Page 2

To effectuate the transfer of the above Contract from Cornerstone Natural Gas Company to ANGC, we
request your consent and verification to both Cornerstone Natural Gas Company and ANGC of the
following:

	1.	 	Phillips Petroleum Company consents to the assignment of the Contract to Associated Natural
Gas Corporation or its designated subsidiary and confirms that same shall not constitute a
breach of the Contract.
	 
	2.	 	The Contract is in full force and effect.
	 
	3.	 	Phillips Petroleum Company has not given notice of any action to terminate or cancel the
Contract.
	 
	4.	 	Company acknowledges that ANGC will rely on the foregoing statements in consummating the
purchase of the Distribution Assets.

To confirm that you are in agreement with the foregoing please sign and return a copy of this
letter to the undersigned.

	 	 	 	 	 	 	 
	 	 	Very truly yours,
	 
	 	 	 	 	 	 
	 	 	Cornerstone Natural Gas Company
	 
	 	 	 	 	 	 
	 

	 	By:
	 	/s/ Kelcy L. Warren	 	 
	 

	 	 	 	 

	 	 

By signature hereto, Phillips Petroleum Company agrees and accepts the consents to this assignment
of the referenced Contract to Associated Natural Gas Company or one of its subsidiaries.

	 	 	 	 	 	 	 
	 

	 	Phillips Petroleum Company	 	 

 

 

October 29, 1993

Page 3

	 	 	 	 	 	 	 
	 

	 	By:
	 	/s/ R. D. Wimer
	 	 
	 	 	   	 	 
	 

	 	Name:
	 	R. D. Wimer	 	 
	 

	 	Title:
	 	Attorney-in-Fact	 	 
	 

	 	Date:
	 	November 1, 1993	 	 

 

 

[ENDEVCO, INC. LETTERHEAD]

November 11, 1993

VIA TELECOPY

Phillips Petroleum Company

Post Office Box 1967

Houston, TX 77251-1967

Attention: Rod Wimer

			
	Re:	 	Natural Gas Gathering Agreement, dated June 1, 1987, between
Cornerstone Natural Gas, Inc. (successor by merger to ANGIC
formerly known as Cornerstone Natural Gas Company)

Dear Mr. Wimer:

We are in receipt of your telecopied consent and thank you for consenting to the assignment of the
above agreement to Associated Natural Gas, Inc. We, however, request the following clarification
to the consent.

Phillips Petroleum Company acknowledges that Associated Natural Gas, Inc. will have no obligations
or liabilities under the contract relating to the period of time prior to November 1, 1993, the
effective date of the assignment of the contract to Associated Natural Gas, Inc.
Phillips Petroleum Company acknowledges that the party to look to regarding the above gas gathering
agreement prior to November 1, 1993 is Cornerstone Natural Gas, Inc.

Very truly yours,

CORNERSTONE NATURAL GAS COMPANY

	 	 	 
	/s/ Kelly Jameson
	 	 
	 

Kelly Jameson

	 	 

 

 

October 29, 1993

Page 2

Agreed and Accepted to this 16 day of November, 1993.

Phillips Petroleum Company

	 	 	 	 	 
	By:

	 	/s/ R D. Wimer	 	 
	Name:

	 	 

R. D. Wimer
	 	 
	Title:

	 	Attorney-in-Fact	 	 

2

 

SECOND AMENDMENT TO GAS GATHERING AGREEMENT

     This Second Amendment to Gas Gathering Agreement (this “Second Amendment”) is entered into
this 1st day of January, 1995 between Associated Natural Gas, Inc. (as “Gatherer”) and
Phillips Petroleum Company (as “Producer”), and amends that certain Gas Gathering Agreement dated
June 1, 1987 between Cornerstone Natural Gas Company, Gatherer’s predecessor, and Producer
(referred to herein as the “Agreement”, including any prior amendments).

     In consideration of their mutual promises, the parties hereto agree to amend the Agreement as
follows:

	 	1.	 	A. This Second Amendment shall amend the Agreement as to the following wells,
which wells are referred to herein collectively as the “Second Amendment Wells”:

[CONFIDENTIAL]

B. Gatherer shall be obligated to provide high pressure lines as defined herein to
connect the Second Amendment Wells to Gatherer’s Ada gathering system, subject to
the other provisions of Section 2.3 of the Agreement (Notwithstanding the foregoing,
Gatherer shall not be obligated to receive gas at pressures in excess of the
applicable MAOP). For purposes hereof, where a gathering line to a Second Amendment
Well causes gas production therefrom to flow through Gatherer’s compression
facilities, such line shall be considered a low pressure line. Where a gathering
line to a Second Amendment Well does not cause Producer’s gas produced therefrom to
flow through Gatherer’s compression facilities, such line shall be referred to
herein as a high pressure line.

C. As to those of the Second Amendment Wells whose gas is produced and delivered to
Gatherer into a high pressure line at the applicable Point of Receipt, the gathering
fee shall be ten cents (10¢) per Mcf, notwithstanding Section 6.1 of the Agreement,
and Gatherer shall not retain a portion of Producer’s gas for compressor fuel,
notwithstanding Section 6.2 of the Agreement.

D. The parties acknowledge that there may be circumstances where one or more of the
Second Amendment Wells are connected to flow gas temporarily to a low pressure line
prior to the well being connected to a high pressure line. As to those of the Second
Amendment Wells whose gas is produced and delivered to Gatherer into a low pressure
line, or at such time that the wellhead pressure of any of the Second Amendment
Wells is incapable of sustaining delivery into a high

 

 

October 29, 1993

Page 4

pressure line, the gathering fee for all of Producer’s gas delivered from such
well(s) shall be fifteen cents (15¢) per Mcf, the compressor fuel charge identified
in Section 6.2 of the Agreement shall apply to gas deliveries from such well(s), and
Gatherer agrees to connect such well(s) to a low pressure line or to convert the
applicable gathering line to a low pressure line as, applicable, if economically
feasible to Gatherer.

E. Producer hereby agrees to spud with the reasonable intent to complete the
Willamette A-l, Bates D-l, Copeland C-2, Walker D-5 and Shaffer E wells during 1995.
In the event Producer fails to spud all of these wells in 1995, the amended
gathering fee of ten cents (10¢) per Mcf described in subparagraph C, above, for
volumes delivered into high pressure lines will be increased by one cent (1¢) per
Mcf for each such well not spudded during 1995 (e.g., if Producer does not spud one
of the five wells, the amended gathering fee will be eleven cents (11¢) per Mcf).
This increased fee will be charged retroactively to the date of first production
under this Second Amendment for all gas delivered into high pressure lines from all
of the Second Amendment Wells.

     2. Section 9.1 of the Agreement shall be amended to provide that the primary term of the
Agreement shall last until June 1, 1998.

     3. The effective date of this Second Amendment shall be November 1, 1994, notwithstanding its
date of execution.

     4. Except as amended hereby, the remaining provisions of the Agreement shall remain in full
force and effect.

4

 

October 29, 1993

Page 5

     IN WITNESS WHEREOF, the parties have executed this Second Amendment as of the date first above
written.

	 	 	 	 	 	 	 
	 	 	PRODUCER:	 	 
	 	 	PHILLIPS PETROLEUM COMPANY	 	 
	 
	 	 	 	 	 	 
	 

	 	By:
	 	/s/ R. D. Wimer	 	 
	 

	 	Name:
	 	 

R. D. Wimer
	 	 
	 

	 	Title:
	 	 Attorney-in-Fact	 	 
	 
	 	 	 	 	 	 
	 	 	GATHERER:	 	 
	 	 	ASSOCIATED NATURAL GAS, INC.	 	 
	 
	 	 	 	 	 	 
	 

	 	By
	 	/s/ Kelly J. Krattenmaker	 	 
	 

	 	 	 	 

Kelly J. Krattenmaker
	 	 
	 

	 	 	 	Vice President	 	 

5

 

AMENDATORY AGREEMENT

     This Amendatory Agreement (“Amendment”), is made and entered into effective September 1, 2000,
by and between Duke Energy Field Services, LP (“Gatherer”) and Phillips Petroleum Company
(“Producer”).

WHEREAS, Gatherer and Producer are parties to that certain Natural Gas Gathering Agreement dated
June 1, 1987 as amended on January 1, 1989, January 1, 1995 and on November 1, 1997 (“Agreement”);
and

WHEREAS, Gatherer and Producer desire to further amend the Agreement.

NOW THEREFORE, in consideration of the premises and mutual covenants set forth herein, it is
mutually agreed between the parties hereto that the Agreement shall be amended as follows:

I.

Paragraph 1.2 of the Agreement, as amended by any previous amendment thereto, shall be further
amended to change the definition of “day” to begin at 9:00 a.m. Central Clock Time (CCT) and end at
9:00 a.m. Central Clock Time the following day.

The following new paragraph 1.16 shall be added to Article I, Definitions,:

The term “well” or “wells” shall mean a single well bore regardless of the number of completions in
that well bore.

II.

Article VI, Paragraphs 6.1 of the Agreement, as amended by any previous amendment thereto, shall be
deleted in its entirety and replaced with the following new provision:

6.1 The fee which Producer shall pay to Gatherer for the gathering and redelivery of gas as
described herein shall be as follows:

     (a) The rate for low pressure gathering shall be $0.13 per Mcf. The rate for high pressure
gathering shall be $0.09 per Mcf but shall increase to $0.10/Mcf as of the earlier of (i)

 

 

October 29, 1993

Page 7

Gatherer having gathered 10,000,000 Mcf of high pressure gas for Producer’s account or (ii)
two (2) years from initial deliveries to the plant.

     (b) Subject to the terms and conditions below, Gatherer agrees that it will diligently connect
any well of Producer within the lands, leases and other sources described in Exhibit “A” to
Gatherer’s Ada System provided that Producer has provided Gatherer with an estimated production
rate and desired line pressure for the subject well. Gatherer shall construct, own and operate the
metering facility and pipeline required to connect such well(s), hereinafter referred to as the
“Facilities”, provided, however, Gatherer shall only be economically responsible for the costs of
the measurement facilities and the first 1000 feet of pipeline associated with each well connect
project (such 1000 feet shall begin at the point of interconnect with Gatherer’s system, as such
system exists on the date which Producer requests Gatherer to connect such well(s)) (“Gatherer’s
Connection Cost Obligation”). As consideration for Gatherer laying pipeline beyond the first 1000
feet (if necessary) and connecting the subject well, Producer shall pay Gatherer for the actual
costs and expenses associated with the purchase, construction and installation of the pipeline
beyond the first 1000 feet required to connect the subject well(s) to Gatherer’s Ada System
(“Producer’s Connection Cost Obligation”). Such pipeline shall be owned and operated by Gatherer.
Producer shall pay any such invoice to Gatherer within fifteen (15) days after receipt thereof.

     Should Producer desire Gatherer to connect any well before such well is proven to be
commercially productive, Producer shall fully indemnify Gatherer for all reasonable costs incurred
by Gatherer to connect such well (regardless of the length of pipe required to connect such well)
if such well proves to be unproductive within thirty (30) days of its connection to Gatherer’s Ada
System. In such event, in addition to reimbursement of Producer’s Connection

7

 

October 29, 1993

Page 8

Cost Obligation as calculated above, Producer shall reimburse Gatherer for the Gatherer’s
Connection Cost Obligation. Producer shall pay any such invoice to Gatherer within fifteen (15)
days after receipt thereof.

     Subject to force majeure, Gatherer shall have all well connects, located within 1000 feet of
Gatherer’s Ada System, completed and in-service within thirty (30) days after receiving written
notice from Producer that Producer desires Gatherer to connect such well. Any notice received
after 4:00 p.m. CCT or any weekend or holiday shall be deemed to be received the following business
day. For wells located greater than 1000 feet from Gatherer’s Ada System, Gatherer shall have an
additional ten (10) days for each additional 1000 feet or any portion thereof to complete the
subject well connect.

III.

     Article VIII — Measurement and Tests, as amended by any previous amendment thereto shall be
deleted in its entirety and replaced with the following new provisions:

8.1 The volume of gas received hereunder for purposes of measurement shall be one (1) cubic foot of
gas and shall be measured by a meter installed and operated, and computations made, as prescribed
in Gas Measurement Committee Report No. 3 of the American Gas Association, including the Appendix
and Amendments thereof. Chart integration and volume computations shall be made by Gatherer as
accurately as possible and within the accuracy prescribed by the manufacturer of the computing
equipment used.

8.2 The specific gravity of the gas received hereunder shall be determined with accuracy to the
nearest one-thousandth (1/1,000) by taking samples of the gas at the point of measurement of by the
use of a method generally accepted in the gas industry or other apparatus approved in

8

 

October 29, 1993

Page 9

advance by both parties at the beginning of receipts, and thereafter once each quarter or as often
as mutually deemed necessary.

8.3 The flowing temperature of the gas shall be determined by periodic tests conducted by Gatherer
with a mercurial thermometer or, by means of a recording thermometer of standard make acceptable to
Producer and Gatherer, in which event the arithmetical average of hourly readings each Day shall be
deemed the gas temperature and shall be used in computing the volumes of gas received during such
Day.

8.4 The gross heating value of the gas received hereunder, shall be determined once each quarter,
or at other intervals agreeable to both parties. The gross heating value shall be determined by
means of a recording chromatograph or by mutual agreement to take a spot sample or composite sample
each month at each Point of Receipt. If a recording chromatograph is used, the arithmetical
average of the hourly gross heating value recorded each Day shall be considered as the heat content
of the gas received during such Day. If spot samples are used, the gross heating value, specific
gravity, and CO2 and N2 content so determined shall be effective the first of
the following month and shall remain effective until the next such determination.

8.5 Tests for water vapor, sulphur and hydrogen sulphide content of the gas received hereunder
shall be made by approved standard methods from time to time as requested by any party hereto, but
not more often than once each quarter.

8.6 Gatherer shall calibrate, maintain and operate at the Points of Receipt, meters and appurtenant
equipment for the measurement of the quantity and quality of the gas received hereunder. Gatherer
shall read such meters and change meter charts as mutually agreed, or cause same to be done. The
meter charts shall at all reasonable times be accessible for inspection and examination by
Producer.

9

 

October 29, 1993

Page 10

8.7 For the purpose of measurement and meter calibration, the atmospheric pressure shall be
assumed, unless otherwise determined by the Standard Gas Measurement Law, to be fourteen and
seventy-three hundredths (14.73) psia.

8.8 At least once each quarter, or at other intervals agreeable to both parties, Gatherer shall
test and calibrate or have tested and calibrated its meters, thermometers and other measuring
devices. Producer shall have the right to require the meters to be calibrated at any time, but
calibrations made at Producers request shall be at the expense of Producer unless the percentage of
inaccuracy is found to be two percent (2%) or more, in which case the calibration shall be made at
the expense of Gatherer. Readings, calibrations, and adjustments of the meters and changing of
charts shall be done only by Gatherer or its agent, but all data with respect thereto shall at all
reasonable times be available to Producer for inspection. If, upon any test, the percentage of
inaccuracy shall be two percent (2%) or more, registrations thereof shall be corrected at the rate
of such inaccuracy for any period which is definitely known or agreed upon, but in case the period
is not definitely known or agreed upon, then for a period extending back one-half (1/2) of the time
elapsed since the last date of calibration. No correction shall be made for recorded inaccuracies
of less than two percent (2%). Gatherer shall cause metering equipment found inaccurate to be
immediately restored to a condition of accuracy. If for any reason any meter is out of service or
out of repair, so that the amount of gas received cannot be ascertained or computed from the
reading thereof, the amount of gas received during the period such meter was out of service or out
of repair shall be estimated based upon the best data available, using the first of the following
methods which is feasible:

8.8.1 By using the data recorded by any check meter, if installed and accurately
registering, or if not installed or registering accurately;

10

 

October 29, 1993

Page 11

8.8.2 By correcting the error if the percentage of error is ascertainable by calibration,
test or mathematical calculation, or if neither such method is feasible;

8.8.3 By estimating the quantity received based upon receipts during preceding periods under
similar conditions when the equipment was registering accurately.

8.9 Each party shall have the right to be present at the time of installing, reading, cleaning,
changing, repairing, inspecting, testing, calibrating or adjusting done in connection with the
other’s measuring equipment in measuring receipts hereunder. The records from such measuring
equipment shall remain the property of their owner, who shall keep them on file for a period of not
less than two (2) years, but upon request, each will submit to the other its records and charts,
together with calculations therefrom subject to return within fifteen (15) days after receipt
thereof.

     Unless otherwise specified by this Amendment, the terms used herein shall have the same
meaning as provided in the Agreement. Except as herein amended and previously amended, all other
terms and provisions of the Agreement shall remain in full force and effect as originally written.

IN WITNESS HEREOF, the parties have executed this Amendatory Agreement effective as of the date
herein written above.

	 	 	 	 	 	 	 	 	 	 	 
	GATHERER	 	 	 	PRODUCER	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	Duke Energy Field Services, LP	 	 	 	Phillips Petroleum Company	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	By

	 	/s/ Robert Poe Reed
	 	 	 	By:
	 	/s/ W. W. Hussey	 	 
	 

	 	 
	 	 	 	 	 	 	 	 
	 

	 	Robert Poe Reed
	 	 	 	Name:
	 	W. W. Hussey	 	 
	 

	 	Vice President
	 	 	 	Title:
	 	Attorney-In-Fact	 	 

11

 

TENTH AMENDMENT

To

NATURAL GAS GATHERING AGREEMENT

This Tenth Amendment (“Amendment”) is made and entered into effective August 1, 2004 (the
“Effective Date”), by and between Duke Energy Services Field Services, LP, (“Gatherer”) and
ConocoPhillips Company, successor by merger to Phillips Petroleum Company (“Producer”).

WHEREAS, Gatherer and Producer are parties to that certain Natural Gas Gathering Agreement dated
June 1, 1987, as amended (the “Agreement”); and

WHEREAS, Gatherer and Producer desire to further amend the Agreement as set forth below.

NOW THEREFORE, in consideration of the premises and mutual covenants set forth herein, it is
mutually agreed between the parties hereto that the Agreement shall be amended as of the Effective
Date, as follows:

1. ARTICLE III, POINTS OF RECEIPT AND DELIVERY, Section 3.4 shall be deleted in its
entirety and replaced with the following new Section 3.4:

     “3.4 All gas quantities shall be delivered to Gatherer and redelivered to Producer (or on
behalf of Producer) as nearly as practicable at uniform hourly and daily rates of flow. The
parties recognize that certain gas imbalances may occur between the quantity of gas received for
the account of Producer and the quantity of gas delivered by Gatherer. During each month the
parties agree to cooperate with each other and with any interconnecting pipeline to remedy any
imbalance as soon as either party becomes aware of an imbalance.

     At the end of each month, any imbalance in MMBtu between the quantity of gas received by
Gatherer hereunder from all Points of Receipt and redelivered by Gatherer hereunder at the Points
of Delivery, less the applicable fuel, loss and unaccounted for as outlined herein, shall be
balanced by means of a payment to Producer from Gatherer or a payment from Producer to Gatherer, as
applicable, valued at the Cash-Out price. The Cash-Out price during the month in

 

 

which the imbalance was generated shall be determined using the table below for either the
excess (due Producer) or shortage (due Gatherer from Producer).

	 	 	 	 	 
	Imbalance %	 	Cash-Out Price due Gatherer	 	Cash-Out Price due Producer
	0% to 3%

	 	100% of Average Price
	 	100% of Average Price
	>3% to 5%

	 	110% of Average Price
	 	90% of Average Price
	>5% to 10%

	 	120% of Average Price
	 	80% of Average Price
	>10%

	 	150% of Average Price
	 	50% of Average Price

     The “Average Price” shall be equal to the arithmetic average during the applicable month of
the daily gas prices per MMBtu for Texas Gas Transmission Co. — Zone 1 as published daily by Gas
Daily in the table entitled “Daily Price Survey” in the column entitled “Midpoint.” Should the
information necessary to calculate the Average Price cease to be available, Gatherer and Producer
shall mutually agree upon substitute publication(s) providing equivalent data for gas prices for
gas delivered into TGT’s system.”

2. ARTICLE VI, GATHERING FEE. Commencing October 1, 2004, Sections 6.1 and 6.2 of the
Agreement shall be deemed to be deleted in their entirety and replaced with the following new
Sections 6.1, 6.2 and 6.3.

     “6.1 Standard Gathering and Compression Service: Producer shall pay Gatherer the following
fees with respect to the provision of gathering and related services as to Producer’s Gas on the
Ada System (hereafter defined):

          (a) Producer shall pay a fee $[CONFIDENTIAL]/MMBtu for gathering, and $[CONFIDENTIAL]/MMBtu
for compressor service (the “Fees”) plus actual fuel and system loss as allocated by Gatherer;
provided that fuel and system losses allocable to Gatherer under this Section 6.1(a) may not exceed
[CONFIDENTIAL]% of the gas quantity measured in MMBtu at the Points of Receipt (the “Standard
Fuel/Loss Reimbursement”). All Fees and system fuel and loss calculations shall be assessed based
on the quantities of gas measured at the Points of Receipt.

          (b) Subject to the limitations set forth in Sections 6.1(c) and (d) below, Gatherer agrees
that it will diligently connect to Gatherer’s Ada Field gathering system (the “Ada System”) any new
well operated by Producer and located within the lands, leases, areas or sources described in
Exhibit “A, that Producer has deemed commercially productive (a “New Commercial Well”). Gatherer
shall pay for the cost to construct a single line, tap and meter for

13

 

each New Commercial Well (at Gatherer’s initial cost), and Gatherer will own and operate the
metering facility and pipeline required to connect each New Commercial Well (“Gatherer’s Connection
Cost”). Producer shall reimburse Gatherer at a rate of [CONFIDENTIAL] to connect each New
Commercial Well to the Ada System (“Producer’s Connection Cost Obligation”). If Producer requests
an additional line, interconnect, or meter to the facilities described above, then Producer shall
pay the actual costs of such additional facilities. Gatherer will seek Producer’s consent prior to
making expenditures that exceed the initial estimate by 10%.

          (c) Should Producer desire Gatherer to connect any well before such well is proven to be a New
Commercial Well, Producer shall notify Gatherer to such effect in writing and thereupon become
obligated to fully reimburse Gatherer for Gather’s Connection Cost, rather than paying Producer’s
Connection Cost Obligation if such well is not proven commercially productive with in ninety (90)
days of it’s connection to the Ada System.

          (d) If Gatherer is able to acquire rights of way and associated real estate rights) at or
below market prices predominating in the region (collectively, “Land Rights”), Gatherer shall cause
any New Commercial Well located within 1,000 feet of the Ada System, to be connected and in-service
within thirty (30) days after receiving Producer’s written notice instructing Gatherer to connect a
New Commercial Well (a “Well Connect”). Any notice received after 4:00 p.m. CCT or any weekend or
holiday, shall be deemed to be received the next business day. For New Commercial Wells located
greater than 1,000 feet from the Ada System, Gatherer shall be afforded an additional ten (10) days
(for each additional 1,000 feet or any portion thereof) to complete the connection of the New
Commercial Well. In addition to the foregoing, when Gatherer is unable to acquire Land Rights at
or near the market price predominating in the region in order to undertake a Well Connect, Gatherer
shall inform Producer of such issue in wilting, providing particulars on efforts made to (i)
acquire such Land Rights and/or (ii) implement alternative routes. If Producer is unwilling to
bear the incremental costs of acquiring the Land Rights that exceed market value then Gatherer’s
obligation set forth in (b) and (c) above shall be deemed to have been satisfied. If Gatherer and
Producer are unable to agree on cost sharing within 30 days then Gatherer shall release such well
from the Agreement.

     6.2 Incremental Compression Service: The parties agree to the following terms relating to the
provision of and payment for Incremental Compression (hereafter defined):

          (a) Gatherer shall install and operate compression facilities at mutually agreeable locations
on the Ada System to provide Producer with low pressure compression service that meets or is lower
than the QALP, as defined in Section 15.1, (collectively, “Incremental Compression”). Gatherer
shall install and operate each Incremental Compressor Facility (as defined in Section 15.1) within
the normal operating range of pressures, volumes, and compression ratios for such facilities based
on the quantities of Producer’s gas available at each location where the same is installed.
Gatherer’s obligation to operate an Incremental Compressor Facility (hereafter defined) shall be
limited to Gatherer’s ability to do so within the normal operating conditions of the Ada System and
the specifications of such Incremental Compressor Facility. Gatherer shall begin acquiring right
of way, real estate and compression

14

 

along with filing all regulatory permits within 30 days of execution of this Agreement.
Construction and installation of a Location, as defined in Article XV, will be completed within
ninety (90) days of receiving all regulatory permits applicable thereto. Actual operation of
equipment will begin within ten (10) days of completion of construction and installation of a
Location. Notice will be provided to Producer as to the status of the air permitting process.

          (b) In addition to all other amounts payable under this Agreement (including all amounts
payable pursuant to Section 6.1 above), Producer agrees to pay Gatherer an Incremental Compression
Fee described below and reimburse Gatherer for incremental metered fuel utilized to provide
Incremental Compression, as such fuel is allocated by Gatherer pursuant to the last paragraph of
this Section 6.2(b).

The “Incremental Compression Fee” shall be per tier for the respective Average Monthly Quantity
which is calculated by taking the average monthly quantity of Producer’s gas measured in MMBtu at
the Points of Receipt times the rate shown below for the tier.

	 	 	 
	Average Monthly Quantity (MMbtu/d)	 	Incremental Compression Fee
	[CONFIDENTIAL]

	 	[CONFIDENTIAL]

“Average Monthly Quantity” means the total quantity of Producer’s gas, measured in MMbtu at all
Points of Receipt during the flow month, divided by the number of days in such month. During a
month in which a Force Majuere condition occurs the Incremental Compression Fee shall equal the
previous months Tiered Rate and not be adjusted by the Average Monthly Quantity.

Wherever a third party produces natural gas from a Producer operated well which utilizes
Incremental Compression and is dedicated to Gatherer under a separate agreement (a “Third Party
Producer”), Gatherer will undertake reasonable efforts to enter into a contract with the Third
Party Producer obligating it to pay Gatherer an Incremental Compression Fee and fuel.
Nevertheless, Producer must pay Gatherer for Incremental Compression attributable to all quantities
of gas produced from Producer operated wells plus any fuel to the extent that Gatherer is not able
to collect such amounts from a Third Party Producer, even if this causes Producer to bear more than
its prorate share thereof. The incremental fuel cost that Producer is obligated to

15

 

pay under this Section 6.2 shall never exceed 3.3% of the quantity of Producer’s and Third Party
Producer’s natural gas measured in MMBtu at the Points or Receipt; this cost shall be in addition
to Standard Fuel/Loss Reimbursement.

     6.3 Consumer Price Index (“CPI”). On August 1, 2005 and each anniversary thereof, the Fees as
described in Sections 6.1 and 6.2, shall be adjusted by multiplying such Fees by a fraction, the
numerator of which shall be the “Current Year’s CPI” (“CYI”) and the denominator of which shall be
the Previous Year’s CPI (“PYI”) as defined below in this paragraph. The CYI and PYI shall be based
upon the CPI index referred to as the “Consumer Prices — All Urban Consumers” index as published
monthly by the United States Department of Labor, using the All Items (Not seasonally adjusted)
column, or a mutually agreeable successor or substitute measure of inflation. The average monthly
CPI for the twelve (12) consecutive months occurring during calendar year 2003 shall be the PYI for
the 1st price adjustment. The PYI shall be the average monthly CPI for the twelve (12) consecutive
months prior to the CYI after the 1st price adjustment. The CYI will be the average monthly CPI
for the twelve (12) consecutive months occurring in the calendar year prior to the year in which
the CPI calculation is made. Notwithstanding anything to the contrary set forth in this Agreement,
Compressor fuel, incremental compressor fuel, system loss, fee for gathering services in Section
6.1(a), and Producer’s Connection Cost Obligation, are not subject to the CPI adjustment.”

3. ARTICLE IX, TERM, Section 9.1 shall be deleted in its entirety and replaced with the
following new Section 9.1:

     “9.1
The primary term of this Agreement shall end on July 31, 2011, whereupon this Agreement
shall continue in effect year to year thereafter until either Party terminates the

16

 

Agreement at the end of the primary term or any successive one (1) year term by giving written
notice of same at least sixty (60) days prior to the last day thereof.”

4. ARTICLE X, NOTICE. Section 10.1 shall be deleted in its entirety and replaced with the
following new Section 10.1:

     “10.1 All notices required by this Agreement shall be in writing, and may be delivered either
personally to the designated representative of the party being notified, by courier or overnight
delivery service, by facsimile (with confirmation of receipt) or sent by first class mail to the
following:

	 	 	 	 	 
	PRODUCER

	 	 	 	GATHERER
	ConocoPhillips Company

	 	 	 	Duke Energy Field Services, LP
	Physical

	 	 	 	5718 Westheimer, Suite 2000
	600 N. Dairy Ashford (77079)

	 	 	 	Houston, Texas 77057
	U.S. Mail

	 	 	 	ATTN: Contract Administration
	P O Box 2197
	 	 	 	 
	Houston, Texas 75252-2 197
	 	 	 	 
	ATTN: Gas and Power Marketing Contract Administration
	 
	 	 	 	 
	Telephone: (281) 293-5359

	 	 	 	Telephone: (713) 627-6200
	Facsimile: (281) 293-3525

	 	 	 	Facsimile: (713) 627-6270

The telephone numbers above are solely for information and may not be used for Agreement notices.”

5. ARTICLE XII, FORCE MAJEURE, is hereby deleted in its entirety and replaced with the
following:

     “12.1 Force Majeure. In the event of any party hereto being rendered unable, wholly or in
part, by reason of force majeure, to carry out its obligations under this Agreement, other than the
obligation to make payment of amounts due hereunder, it is agreed that such party shall give notice
and reasonably full particulars of such force majeure, in writing, to the other party within a
reasonable time after the occurrence of the cause relied on, and the obligations of the party

17

 

giving such notice, so far as they are affected by such force majeure, shall be suspended
during the continuance of any inability so caused, but for no longer period, and such cause shall,
so far as possible, be remedied with all reasonable dispatch. The term “force majeure” as used in
this Agreement shall mean any delay or default in performance due to any cause beyond the
reasonable control of the party claiming force majeure and without such party’s fault or
negligence, including but not restricted to acts of God or the public, civil disturbances, arrests
and restraints by rulers and people; acts of the public enemy, wars, riots, insurrections,
sabotage; acts, requests or interruptions of the federal, state or local government or any agency
thereof; court orders, present and future valid orders of any governmental authority, or any
officer, agency or any instrumentality thereof; floods, fires, storms, epidemics, landslides,
lightning, earthquakes, washouts, explosions, quarantine; strikes, lockouts, or industrial
disturbances; interruption of residue gas transportation downstream of Gatherer’s processing
facilities, freight embargoes or delays in delivery of equipment or service necessary to the
performance of any provision of this Agreement; inability or delay in securing right of way, labor
shortages, breakage or accident to machinery or lines of pipe, or any other cause, whether of the
kind herein enumerated or otherwise, not reasonably within the control of the party claiming force
majeure. It is understood and agreed that the settlement of strikes or lockouts shall be entirely
within the discretion of the party having the difficulty, and that the above requirement that any
force majeure shall be remedied with all reasonable dispatch shall not require the settlement of
strikes or lockouts by acceding to the demands of the opposing party when such course is
inadvisable in the discretion of the party having the difficulty.”

6. A new article entitled, ARTICLE XV, PERFORMANCE GUARANTEE shall be added to the
Agreement providing as follows:

18

 

ARTICLE XV

PERFORMANCE GUARANTEE

     “15.1
Pipeline Pressure Obligation. (a) Gatherer will design a
[CONFIDENTIAL] psig system that will
have pipe and compression sized for a compressor suction pressure of [CONFIDENTIAL] psig. The design, when
modeled prior to installation of the compressor facilities and pipelines, results in a predicted
meter pressure within [CONFIDENTIAL] percent ([CONFIDENTIAL]%) at four (4) identified pipeline locations (individually a
“Location”, collectively the “Locations”). These Locations are described as [CONFIDENTIAL].
Each of these Locations are associated with one of four (4) facilities used to provide Incremental
Compression (each an “Incremental Compressor Facility”). The Incremental Compressor Facilities are
identified as and will be deemed to have the following maximum
capacities (i) the [CONFIDENTIAL] Station ([CONFIDENTIAL] mmcfd), (ii) the [CONFIDENTIAL] Station ([CONFIDENTIAL] mmcfd), (iii) the [CONFIDENTIAL] Station ([CONFIDENTIAL] mmcfd)
and (iv) the [CONFIDENTIAL] Station ([CONFIDENTIAL] mmcfd) when each operates at a pressure of [CONFIDENTIAL] psig (hereafter the
“Station Capacity”). Gatherer agrees to maintain an average Location pressure each calendar
quarter as follows: The QALP consists of the following values: (i) the daily average location
pressure at each individual Location divided by (ii) the number of days in the subject calendar
quarter, with the final result equaling the QALP for such calendar quarter for that Location
(hereinafter, the “QALP”) of not greater than [CONFIDENTIAL]% of the design Location pressure of [CONFIDENTIAL] psig at
each “Location”, based on the Producer’s and Third Party Producer’s combined maximum capacity at
each individual Incremental Compression Facility set forth above. Gatherer’s agreement to maintain
the QALP will commence following the completion of installation and final testing of the last
Incremental Compressor Facility (the “Commencement Date”). The QALP shall commence to be
calculated on the Commencement Date and thirty (30) days after the commencement date Gatherer and
Producer shall confirm the actual pressures and the model pressures are within [CONFIDENTIAL]% of model
expectation. If pressures are within [CONFIDENTIAL]%, Gatherer shall thereafter be obligated by the location
pressure obligation set forth in this Section. If pressures are not
within [CONFIDENTIAL]%, then Gatherer
shall have [CONFIDENTIAL] ([CONFIDENTIAL]) days to remedy the pressure situation or Producer shall receive
[CONFIDENTIAL] as noted below in paragraph “c” until such time as the actual pressures achieved are
within [CONFIDENTIAL]% of such pressure obligations.

     (b) The average daily location pressure and number of days for a Location whose operation on a
given day is affected by a force majeure condition, scheduled overhaul and/or preventive
maintenance shall not be used in calculating the QALP. Preventive maintenance shall not exceed [CONFIDENTIAL]%
of the time in any calendar quarter.

     (c) If the QALP of a Location is greater
than [CONFIDENTIAL] psig, then Gatherer shall during the [CONFIDENTIAL] day
period following its being notified of such QALP value by Producer, take steps it deems appropriate
to reduce the Location pressure. If Gatherer fails to reduce the Location pressure to the required
level with such [CONFIDENTIAL] day period, Producer shall have the right (as its sole and exclusive remedy
under this Agreement for Gatherer’s failure to meet the pipeline pressure obligation of this
Section) to receive a [CONFIDENTIAL] of the [CONFIDENTIAL] payable during the next calendar
quarter. The Incremental Compression Fee shall be computed and applied as follows as to any
affected Location (the “Affected Location”):

(i) When the QALP indicates a pressure greater
than [CONFIDENTIAL] psig, the portion of the Average
Monthly Quantity that is attributable to the Affected Location only, shall bear an
Incremental Compressor Fee that is $[CONFIDENTIAL] less per MMBtu than is charged to the Average
Monthly Quantity that is not attributable to the Affected Location; and

(ii) To determine the portion of the Average
Monthly Quantity that is attributable to the
Affected Location, the Average Monthly Quantity for the next calendar quarter shall be
multiplied by a fraction, the numerator of which shall be the capacity of the Affected
Location (as shown in this Section above) and the denominator of which shall be [CONFIDENTIAL] mmcfd.
However, if the Affected Location is [CONFIDENTIAL] (which has [CONFIDENTIAL] meter pressures) then only
[CONFIDENTIAL]% of the [CONFIDENTIAL] volume will be used in the numerator. Likewise, if two locations
associated with [CONFIDENTIAL] are greater than [CONFIDENTIAL] psig, then [CONFIDENTIAL]% of the [CONFIDENTIAL] volume will
be used in the numerator, and if all three locations are [CONFIDENTIAL] than [CONFIDENTIAL] psig, then the
[CONFIDENTIAL] volume of [CONFIDENTIAL] shall be used in the numerator.

     (d) Notwithstanding any other provision of this Section, any calendar quarter that the volume
of natural gas compressed at an Incremental Compressor Facility exceeds such facility’s maximum
capacity times the number of days in such calendar quarter (taking into account reductions allowed
for force majeure condition, schedule overhaul and/or preventative maintenance) the QALP for such
calendar shall be deemed to be less than [CONFIDENTIAL] psig, regardless of what the computation of QALP
outlined in this Section 15.1(b) above indicates. In no event shall Gatherer be obligated to
monitor or otherwise track the QALP, and unless proven otherwise by Producer, a QALP of [CONFIDENTIAL] psig
will be assumed to exist at all times. Additionally, if Producer’s operations result in production
of non-conforming gas as defined in Section 5.1, Quality of Gas, then based upon notice as set
forth in Section 5.2 and confirmation that Producer’s well contaminated the Ada System, then the
location pressure guarantee set forth in this Section is suspended for the relevant calendar
quarter for that Location and Producer shall reimburse Gatherer the reasonable cost to remove and
dispose of such contaminants from the system. Gatherer shall own all hydrocarbon liquids that are
collected and removed from the pipeline.

     (e) Should the Locations cease to be applicable, Gatherer and Producer shall mutually agree
upon substitute locations.

     (f) Gatherer shall operate the Incremental Compression within normal operating range of
pressures, volumes, and compression ratios for such Incremental Compression Facilities based on the
volume of gas available at each respective Incremental Compressor Facility. Gatherer’s obligation
to operate the Incremental Compression Facilities shall be limited to Gatherer’s ability to do such
within normal operating limitations, as determined by Gatherer, of such compressors and the daily
operating conditions of the Ada System.

     (g) Should there be unused Station Capacity [CONFIDENTIAL] after the Commencement Date during the
term of this Agreement, Gatherer shall have the option to remove, use, or modify such unused
Station Capacity. Prior to utilization or removal, Gatherer shall notify Producer of Gatherer’s
intent to reduce the Station Capacity. Producer may elect to utilize or release the unused Station
Capacity at no cost within [CONFIDENTIAL] days of notification. Should Producer not utilize the Station
Capacity in [CONFIDENTIAL] days but wish to retain it Producer may elect to reserve the unused Station
Capacity. Producer shall pay a reserve compression fee of $[CONFIDENTIAL]/bhp per month calculated on the bhp
being reserved. Such charge shall cease when Producer utilizes the bhp or cancels the reserve
compression. If Producer fails to notify Gatherer of its election set forth in this Section
(g), Producer will be deemed to have released the unused Station Capacity.”

7. A new article entitled, ARTICLE XVI, COMPRESSOR AND PIPELINE PURCHASE shall be added to
the Agreement providing as follows:

ARTICLE XVI

COMPRESSOR AND PIPELINE PURCHASE

     “16.1 Property Purchased: In consideration of the payment of $50.00, the receipt of
which Producer hereby acknowledges from Gatherer, Producer grants Gatherer an irrevocable option to
acquire, the compressions, buildings in which they are located, and to the extent transferable,
surface sites and rights of ways, and all appurtenances related thereto that are located at
Producer’s [CONFIDENTIAL] and [CONFIDENTIAL] locations and as are further described in the Exhibit “A”, attached
and made a part of this Agreement (the “Compressor Facilities”) together with those certain
pipelines as further described in the Exhibit “B”, attached and made a part of this Agreement (the
“Pipelines”, with the Compressor Facilities and Pipelines hereafter referred to collectively as the
“Assets”). Producer agrees to afford Gatherer complete and unrestricted access to the sites and
locations of the Assets such as will enable Gatherer to conduct environmental, structural integrity
and valuation due diligence efforts. The option hereby granted by Producer shall remain in effect
through October 15, 2004 for compressors and November 1, 2004 for the pipelines (the “Option
Expiration Date”). Gatherer may exercise said option at any time before the Option Expiration Date
by delivering notice of such election to Producer. Upon receipt of such notice, the parties shall
finalize negotiations relative to the purchase price and the Assignment and Bill of Sale for use in
transferring the Assets (the initial form of which is attached hereto as Exhibit C). If Gatherer
does elect the option, Producer shall execute and deliver such additional documents as Gatherer may
reasonably require to affect the transfer of good and marketable title in the Assets to Gatherer.

     16.2 Purchase Price: If Gatherer exercises its option to purchase the Assets, it agrees to
pay Producer an amount of $[CONFIDENTIAL].

     16.3 Inspection and Acceptance: From the date of this Agreement, until the date of Gatherer’s
exercise of the option and purchase of the Compressor Facilities and Pipelines, Gatherer shall have
the right to inspect and confirm that the Compressors and Pipelines are in good condition and
suitable for Gatherer’s intended purposes and to assess the environmental impact that the Assets
have had, if any.”

8. No Further Changes. Unless otherwise specified by this Amendment, the terms used herein
shall have the same meaning as provided in the Agreement. Except, as herein amended, all other
terms and provisions of the Agreement shall remain in full force and effect.

19

 

     IN WITNESS HEREOF, the parties have executed this Amendment to be effective as of the date
first written above.

	 	 	 	 	 	 	 	 	 	 	 
	GATHERER	 	 	 	PRODUCER	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	Duke Energy Field Services, LP	 	 	 	ConocoPhillips Company	 	 
	 
	 	 	 	 	 	 	 	 	 	 
	By:

	 	/s/ David F. Garrett
	 	 	 	By:
	 	/s/ Mary Ann Pearce	 	 
	 

	 	 
	 	 	 	 	 	 	 	 
	Name:

	 	David F. Garrett
	 	 	 	Name:
	 	Mary Ann Pearce	 	 
	Title:

	 	Vice President — Commercial
	 	 	 	Title:
	 	Commercial Manager	 	 

This signature is an integral part of the Tenth Amendment

to Natural Gas Gathering Agreement ADA1019GAT

20

 

EXHIBIT “A”

PRODUCER’S COMPRESSOR LOCATIONS

	 	 	 
	LOCATION	 	DESCRIPTION
	[CONFIDENTIAL]
	 	 

A-1

 

EXHIBIT “B”

DESCRIPTION OF PURCHASED PIPELINES

	 	 	 	 	 
	LOCATION	 	PARISH	 	APPROX. LENGTH and DESCRIPTION
	[CONFIDENTIAL]
	 	 	 	 

B-1

Source: [{"source": "alea-institute/alea-institute/kl3m-data-edgar-agreements/train-00093-of-00352.parquet"}, [{"source": "alea-institute/alea-institute/kl3m-data-edgar-agreements/train-00093-of-00352.parquet"}]]