EXHIBIT 10.13(g)
FIRM NO-NOTICE TRANSPORTATION AGREEMENT
between
TEXAS GAS TRANSMISSION CORPORATION
and
MISSISSIPPI VALLEY GAS COMPANY
Dated
NOVEMBER 1, 1997
FIRM NO-NOTICE TRANSPORTATION AGREEMENT
Rate Schedule NNS
THIS AGREEMENT, made and entered into this 1st day of November, 1997,
by and between Texas Gas Transmission Corporation, a Delaware corporation,
hereinafter referred to as "Texas Gas," and Mississippi Valley Gas Company, a
Mississippi corporation, hereinafter referred to as "Customer,"
WITNESSETH:
WHEREAS, Customer was receiving a firm, bundled city gate sales service
from Texas Gas on May 18, 1992, under provisions of a sales service agreement
dated November 1, 1997; and
WHEREAS, Customer desires to continue receiving the equivalent
transportation service formerly embedded in its bundled sales service, or
portion thereof, as no-notice service; and
WHEREAS, Texas Gas desires to provide and Customer desires to receive
such no-notice service under its NNS Rate Schedule on the terms and conditions
set forth herein;
NOW THEREFORE, in consideration of the premises and of the mutual
covenants herein contained, the parties hereto covenant and agree as follows:
ARTICLE I. DEFINITIONS
1.1 The definitions in Section 3 of Rate Schedule NNS, as well as Section 1 of
the General Terms and Conditions of Texas Gas's FERC Gas Tariff, are hereby
incorporated by reference and made a part of this Agreement.
ARTICLE II. QUANTITY
2.1 Pursuant to Texas Gas's Rate Schedule NNS and subject to the terms and
provisions of this Agreement, Customer agrees to deliver or cause to be
delivered to Texas Gas at the Point(s) of Receipt in Exhibit "A" hereunder, gas
for transportation and Texas Gas agrees to receive, transport, and redeliver to
Customer at the Point(s) of Delivery in Exhibit "B" hereunder, the daily and
seasonal quantities of gas set forth herein. The parties agree that the
transportation service provided hereunder shall be a firm service provided by
combining pipeline capacity (the "Nominated" portion of the service) and storage
capacity (the "Unnominated" portion of the service) into a single transportation
service.
2.2 The maximum daily quantity of gas which Texas Gas shall be obligated to
transport and redeliver to Customer, and which Customer shall be obligated to
receive, is Customer's applicable Contract Demand expressed on a seasonal basis
as set forth below:
Daily
Contract Demand MMBtu/D
--------------- -------
Winter 50,429
Summer 5,000
2.3 The above Contact Demands consist of a Nominated Daily Quantity, for which
Customer is responsible for scheduling the delivery of gas supplies into Texas
Gas's system, and an Unnominated Daily Quantity, which is
2
automatically delivered from storage by Texas Gas to meet Customer's
requirements. Those quantities, expressed on a seasonal basis, are set forth
below:
Nominated Daily Quantity MMBtu/D
------------------------ -------
Winter 5,000
Summer 5,000
Unnominated Daily Quantity MMBtu/D
-------------------------- -------
Winter 45,429
2.4 Customer's Excess Unnominated Daily Quantity shall be 5,043 MMBtu per day,
which is ten percent (10%) of its Winter Contract Demand.
2.5 The maximum seasonal quantities of gas which Texas Gas shall be obligated to
transport and deliver to Customer, and which Customer shall be obligated to
receive, are Customer's Seasonal Quantity Entitlements as set forth below:
Seasonal
Quantity Entitlement MMBtu
-------------------- ---------
Winter 1,785,797
Summer 1,070,000
2.6 A portion of Customer's Winter Quantity Entitlement consists of unnominated
quantities of gas delivered by Texas Gas from storage. The maximum net quantity
of gas Texas Gas is obligated to deliver to Customer from storage during any
Winter Season is Customer's Unnominated Seasonal Quantity, which is 1,030,797
MMBtu. In addition to scheduling the receipt of Customer's Summer Quantity
Entitlement, Customer is also responsible for the redelivery each summer of that
portion of Customer's Unnominated Seasonal Quantity actually used the prior
winter, as more fully set forth herein.
2.7 Customer shall reimburse Texas Gas for the Quantity of Gas required for
fuel, company use, and unaccounted for associated with the transportation
service hereunder in accordance with Section 16 of the General Terms and
Conditions of Texas Gas's FERC Gas Tariff. Texas Gas may adjust the fuel
retention percentage as operating circumstances warrant; however, such change
shall not be retroactive. Texas Gas agrees to give Customer thirty (30) days
written notice before changing such percentage.
2.8 Texas Gas, at its sole option, may, if tendered by Customer, transport
daily quantities in excess of Customer's Contract Demand.
2.9 In order to protect its system, the delivery of gas to its customers and/or
the safety of its operations, Texas Gas shall have the right to vent excess
natural gas delivered to Texas Gas by Customer or Customer's supplier(s) in that
part of its system utilized to transport gas received hereunder. Prior to
venting excess gas, Texas Gas will use its best efforts to contact Customer or
Customer's supplier in an attempt to correct such excess deliveries to Texas
Gas. Texas Gas may vent such excess gas solely within its reasonable judgment
and discretion without liability to Customer, and a pro rata share of any gas so
vented shall be allocated to Customer. Customer's pro rata share shall be
determined by a fraction, the numerator of which shall be the quantity of gas
delivered to Texas Gas at the Point of Receipt by Customer or Customer's
suppliers in excess of Customer's confirmed nomination and the denominator of
which shall be the total quantity of gas in excess of total confirmed
nominations flowing in that part of Texas Gas's system utilized to transport
gas, multiplied by the total quantity of gas vented or lost hereunder.
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ARTICLE III. SCHEDULING OF
CUSTOMER'S NOMINATED DAILY QUANTITY
3.1 This Article III only applies to the scheduling of the Nominated Daily
Quantity portion of Customer's Contract Demand and not to the Unnominated Daily
Quantity of Unnominated Seasonal Quantity delivered from storage.
3.2 Customer shall be obligated four (4) working days prior to the end of each
month to furnish Texas Gas with a schedule of the estimated daily quantity(ies)
of gas it desires to be received, transported, and redelivered for the following
month. Such schedules will show the quantity(ies) of gas Texas Gas will receive
from Customer at the Point(s) of Receipt, along with the identity of the
supplier(s) that is delivering or causing to be delivered to Texas Gas
quantities for Customer's account at each Point of Receipt for which a
nomination has been made.
3.3 Customer shall give Texas Gas, after the first of the month, twenty-four
(24) hours notice prior to the commencement of any day in which Customer desires
to change the quantity(ies) of gas it has scheduled to be delivered to Texas Gas
at the Point(s) of Receipt. If Customer's nomination change does not require
Texas Gas to interrupt service to another customer, Texas Gas will agree to
waive this 24-hour prior notice and implement nomination changes requested by
customer to commence in such lesser time frame subject to Texas Gas's being able
to confirm and verify such nomination change at both receipt and delivery
points, and receive PDA's reflecting this nomination change at both receipt and
delivery points. Texas Gas will use its best efforts to make the nomination
change effective at the time requested by customer; however, if Texas Gas is
unable to do so, the nomination change will be implemented as soon as
confirmation is received.
ARTICLE IV. POINTS OF RECEIPT AND DELIVERY
AND SUPPLY LATERAL ALLOCATION
4.1 Customer shall deliver or cause to be delivered natural gas to Texas Gas at
the Point(s) of Receipt specified in Exhibit "A" attached hereto and Texas Gas
shall redeliver gas to Customer or for the account of Customer at the Point(s)
of Delivery specified in Exhibit "B" attached hereto, in accordance with
Sections 7 and 15 of the General Terms and Conditions of Texas Gas's FERC Gas
Tariff.
4.2 Customer's preferential capacity rights on each of Texas Gas's supply
laterals shall be as set forth in Exhibit "C" attached hereto, in accordance
with Section 34 of the General Terms and Conditions of Texas Gas's FERC Gas
Tariff.
ARTICLE V. TERM OF AGREEMENT
5.1 This Agreement shall become effective November 1, 1997, and shall remain in
full force and effect for a primary term of five (5) years ending October 31,
2002. At the end of such primary term, or any subsequent rollover term, this
Agreement shall automatically be extended for an additional rollover term of
five (5) years, unless Customer terminates this Agreement at the end of such
primary or rollover term by giving Texas Gas at least 365 days advance written
notice prior to the expiration of the primary term or any subsequent rollover
term.
ARTICLE VI. POINT OF MEASUREMENT
6.1 The gas shall be measured or caused to be measured by Customer and/or Texas
Gas at the Point(s) of Measurement which shall be as specified in Exhibits A,
A-I, and B herein. In the event of a line loss or leak between the Point of
Measurement and the Point of Receipt, the loss shall be determined in accordance
with the methods described in Section 3, "Measuring and Measuring Equipment,"
contained in the General Terms and Conditions of First Revised Volume No. 1 of
Texas Gas's FERC Gas Tariff.
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ARTICLE VII. FACILITIES
7.1 Texas Gas and Customer agree that any facilities required at the Point(s) of
Receipt, Point(s) of Delivery, and Point(s) of Measurement, shall be installed,
owned, and operated as specified in Exhibits A, A-I, and B herein. Customer may
be required to pay or cause Texas Gas to be paid for the installed cost of any
new facilities required as contained in Sections 1.3, 1.4 and 1.5 of Texas Gas's
FT Rate Schedule. Customer shall only be responsible for the installed cost of
any new facilities described in this Section if agreed to in writing between
Texas Gas and Customer.
ARTICLE VIII. RATES AND CHARGES
8.1 Unless otherwise agreed to in writing by Texas Gas and Customer, Customer
shall pay to Texas Gas each month a Reservation Charge which shall consist of
the applicable Contract Demand as specified in this Agreement multiplied by the
applicable demand rate per MMBtu. The Reservation Charge shall be billed as of
the effective date of this Agreement. Unless otherwise agreed to in writing by
Texas Gas and Customer, Customer shall also pay Texas Gas the Maximum Commodity
Rate per MMBtu of gas delivered by Texas Gas for no-notice transportation
services rendered to Customer up to Customer's applicable Contract Demand. For
all gas quantities delivered in excess of Customer's applicable Contract Demand
on any day, Customer shall pay the NNS Overrun Rate per MMBtu, as described
in the NNS Rate Schedule. In addition, Customer shall pay any and all currently
effective demand or commodity surcharges, including but not limited to, the GRI
Funding Unit, the FERC ACA Unit Charge, Texas Gas's Take-or-Pay surcharge, and
Order 636 Transition Costs surcharge.
If Texas Gas declares force majeure which renders it unable to perform
service for Customer under this Agreement either in whole or part, then Customer
shall be relieved of its obligation to pay NNS demand charges for that part of
its NNS contract demand affected by such force majeure event until the force
majeure event is remedied.
Unless otherwise agreed to in writing by Texas Gas and Customer, Texas
Gas may, from time to time, and at any time selectively after negotiation,
adjust the rate(s) applicable to any individual Customer; provided, however,
that such adjusted rate(s) shall not exceed the applicable Maximum Rate(s) nor
shall they be less than the Minimum Rate(s) set forth in the currently effective
Sheet No. 10 of Texas Gas's FERC Gas Tariff. If Texas Gas so adjusts any rates
to any Customer, Texas Gas shall file with the Commission any and all required
reports respecting such adjusted rate.
8.2 In the event Customer utilizes a Secondary Point(s) of Delivery for
transportation service herein, Customer will continue to pay the monthly
reservation charges as described in Section 8.1 above. In addition, Customer
will pay the maximum commodity charge applicable to the zone in which gas is
delivered up to Customer's applicable Contract Demand and the maximum overrun
commodity charge for any quantities delivered by Texas Gas in excess of
Customer's Seasonal Quantity Entitlement. Customer also agrees to pay the ACA,
Take-or-Pay Surcharge, GRI charges, fuel retention charge, and any other
effective surcharges, if applicable, as described in Section 8.1 above.
8.3 It is further agreed that Texas Gas may seek authorization from the
Commission and/or other appropriate body for such changes to any rate(s) and
terms set forth herein or in Texas Gas's tariff, as may be found necessary to
assure Texas Gas just and reasonable rates. Nothing herein contained shall be
construed to deny Customer any rights it may have under the Natural Gas Act, as
amended, including the right to participate fully in rate proceedings by
intervention or otherwise to contest increased rates in whole or in part.
8.4 Customer agrees to fully reimburse Texas Gas for all fees, if any,
associated with the service contemplated herein which Texas Gas is required to
pay to the Commission or any agency having or assuming jurisdiction of the
transactions contemplated herein.
8.5 Customer agrees to execute or cause its supplier or processor to execute a
separate agreement with Texas Gas providing for the transportation of any
liquids and/or liquefiables, and agrees to pay or reimburse Texas Gas, or cause
Texas Gas to be paid or reimbursed, for any applicable rates or charges
associated with the transportation of such liquids and/or liquefiables, as
specified in Section 24 of the General Terms and Conditions of Texas Gas's FERC
Gas Tariff.
5
ARTICLE IX. WINTER SERVICE
9.1 Customer will only be required to nominate into Texas Gas's system a
quantity of gas up to the Nominated Daily Quantity.
9.2 In addition to the Nominated Daily Quantity actually scheduled by Customer,
Texas Gas will adjust deliveries from storage up to Customer's Unnominated Daily
Quantity to meet Customer's city gate requirements up to Customer's Winter
Contract Demand.
9.3 In addition, Customer may exceed its Unnominated Daily Quantity by a
quantity equal to its Excess Unnominated Daily Quantity (i.e. 10% of its Winter
Contract Demand) for up to two consecutive gas days without a penalty; however,
total deliveries to the Customer may not exceed the Customer's Winter Contract
Demand. Texas Gas will notify the Customer within four (4) hours of the end of
the gas day in which Customer has exceeded its Unnominated Daily Quantity. If
the Customer does not cease taking such Excess Unnominated Daily Quantity from
Texas Gas's storage after two consecutive gas days, then pipeline may assess a
penalty of $15 per MMBtu of such excess gas taken and may issue an operational
flow order requiring Customer to immediately inject additional gas supply and/or
reduce city gate deliveries so that the customer is no longer exceeding his
Unnominated Daily Quantity.
9.4 Monthly Maximum Withdrawal: No more than 50% of Customer's Unnominated
Seasonal Quantity shall be withdrawn in any consecutive thirty (30) day period.
9.5 Seasonal Minimum and Maximum Withdrawal: No more than 105% of Customer's
Unnominated Seasonal Quantity shall be withdrawn by March 1; provided further,
that no less than 68% and no more than 100% of Customer's Unnominated Seasonal
Quantity shall be withdrawn by April 1 (the end of the Winter Season).
9.6 Adjusted Unnominated Daily Quantity: As Customer's Unnominated Seasonal
Quantity (USQ) is withdrawn, that portion of Customer's Unnominated Daily
Quantity (UDQ) available to Customer shall be adjusted. Customer's Adjusted
Unnominated Daily Quantity (UDQ) shall be equal to the greater of its average
winter daily unnominated quantity (i.e., Customer's USQ divided by the total
number of Winter days the UDQ is available) or the applicable percentage of its
Unnominated Daily Quantity (UDQ) as set forth in the following table:
% USQ Withdrawn % UDQ Available
--------------- ---------------
75% 90%
80% 85%
85% 80%
90% 75%
9.7 During the Winter Season, Texas Gas will also inject gas into storage on a
best efforts basis as part of NNS service. Although such injections will be
done on a best efforts basis, Texas Gas will be presumed, unless it gives notice
to the contrary, to be able to inject into storage such quantities of gas as to
take into account routine variations in no-notice deliveries. If Texas Gas is
unable to make such best efforts injections, it will advise Customer by posting
on its electronic bulletin board. However, no presumption will exist for
nonroutine situations (e.g. injections in excess of 15% of Customer's Winter
Contract Demand or sustained injections of more than five days) and Customer
must give 24 hours advance written notice to Texas Gas of quantities it desires
to inject into storage, so that Texas Gas can determine the extent to which it
can make such injections and adjust its operations accordingly.
ARTICLE X. SUMMER SERVICE
10.1 Texas Gas shall deliver to Customer at the city gate during each Summer
Season up to the Customer's Summer Contract Demand and Summer Quantity
Entitlement as nominated by Customer.
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10.2 Pursuant to the provisions set forth below, Customer shall deliver in kind
to Texas Gas during each Summer Season a quantity of gas equal to that portion
of Customer's Unnominated Seasonal Quantity actually utilized by Customer
(including any infield transfers pursuant to Section 25.8(c) of the General
Terms and Conditions of this tariff) during the prior Winter Season. Customer
shall reserve and utilize such portion of its Summer Contract Demand as
necessary to redeliver such volumes into storage.
10.3 Maximum Daily Injection Quantity: To protect the storage formations and
allow uniform filling of the storage reservoirs, Customer will be required to
adhere to certain injection limits (calculated as a percentage of the
Unnominated Seasonal Quantity), throughout the summer injection period. During
the Summer Season Customer may, on a daily basis, inject according to the
following table:
% of Unnominated Maximum Available
Seasonal Quantity Injection Rate
Injected (% of USQ)
---------------- -----------------
0%- 65% 1.3%
65%-90% 1.1%
>90% 0.6%
10.4 Inventory verification tests will be conducted on a semiannual basis. These
tests require the temporary suspension of individual storage field activities
(injections and withdrawals) for a period of approximately two weeks. If
conditions will not permit the full maximum daily injection or withdrawal
quantity, Texas Gas may temporarily adjust the limit and allow makeup quantities
on succeeding days. Texas Gas will provide at least 45 days prior notice in
regard to the scheduling of these shut-in periods.
10.5 During the Summer Season, Texas Gas will also withdraw gas from storage on
a best efforts basis as part of the NNS service. Although such withdrawals will
be done on a best efforts basis, Texas Gas will be presumed, unless it gives
notice to the contrary, to be able to withdraw from storage such quantities of
gas as to take into account routine variations in no-notice services. If Texas
Gas is unable to make such best efforts withdrawals, it will advise Customer by
posting on its electronic bulletin board. However, no presumption will exist for
nonroutine situations (e.g. withdrawals in excess of 10% of Customer's Winter
Contact Demand or sustained withdrawals of more than five days) and Customer
must give 24 hours advance written notice to Texas Gas of quantities it desires
to withdraw from storage, so that Texas Gas can determine the extent to which it
can make such withdrawals and adjust its operations accordingly.
10.6 To assist Texas Gas's operational and maintenance scheduling through the
Summer Season, Customer will notify Texas Gas by March 15 of each year, with
updates monthly, of the quantities it intends to inject monthly during the
immediately upcoming Summer Season; such injection schedule provided by Customer
is a best efforts estimate and may be revised as necessary. Texas Gas will use
its reasonable efforts to coordinate its test, maintenance, alteration and
repair activities during such Summer Season to accommodate Customer's request.
ARTICLE XI. MISCELLANEOUS
11. 1 Texas Gas's Transportation Service hereunder shall be subject to receipt
of all requisite regulatory authorizations from the Commission, or any successor
regulatory authority, and any other necessary governmental authorizations, in a
manner and form acceptable to Texas Gas. The parties agree to furnish each other
with any and all information necessary to comply with any laws, orders, rules,
or regulations.
11.2 Except as may be otherwise provided, any notice, request, demand,
statement, or ▇▇▇▇ provided for in this Agreement or any notice which a party
may desire to give the other shall be in writing and mailed by regular mail, or
by postpaid registered mail, effective as of the postmark date, to the post
office address of the party intended to receive the same, as the case may be, or
by facsimile transmission, as follows:
7
Texas Gas
Texas Gas Transmission Corporation
▇▇▇▇ ▇▇▇▇▇▇▇▇▇ ▇▇▇▇▇▇
Post Office Box 20008
▇▇▇▇▇▇▇▇▇, ▇▇▇▇▇▇▇▇ ▇▇▇▇▇
Attention: Gas Revenue Accounting (▇▇▇▇▇▇▇▇ and Statements)
Marketing Administration (Other Matters)
Gas Transportation and Capacity Allocation (Nominations)
Fax (▇▇▇) ▇▇▇-▇▇▇▇
Customer
Mississippi Valley Gas Company
▇▇▇ ▇▇▇▇ ▇▇▇▇▇▇▇ ▇▇▇▇▇▇
▇▇▇▇▇▇▇, ▇▇▇▇▇▇▇▇▇▇▇ ▇▇▇▇▇
Attention: ▇▇. ▇▇▇▇▇ ▇. ▇▇▇▇
The address of either party may, from time to time, be changed by a
party mailing, by certified or registered mail, appropriate notice thereof to
the other party. Furthermore, if applicable, certain notices shall be considered
duly delivered when posted to Texas Gas's Electronic Bulletin Board, as
specified in Texas Gas's Tariff.
11.3 Customer shall have fifteen (15) days from the date of receipt of this
Agreement in which to execute such Agreement or Customer's request may be deemed
null and void.
11.4 This Agreement shall be governed by the laws of the State of
Kentucky.
11.5 Each party agrees to file timely all statements, notices, and petitions
required under the Commission's Regulations or any other applicable rules or
regulations of any governmental authority having jurisdiction hereunder and to
exercise due diligence to obtain all necessary governmental approvals required
for the implementation of this Transportation Agreement.
11.6 All terms and conditions of Rate Schedule NNS and the attached Exhibits
A, A-I, B, and C are hereby incorporated to and made a part of this Agreement.
11.7 This contract shall be binding upon and inure to the benefit of the
successors, assigns, and legal representatives of the parties hereto.
11.8 Neither party hereto shall assign this Agreement or any of its rights or
obligations hereunder without the consent in writing of the other party and
subject to the requirements of Section 25.7 of the General Terms and Conditions
of Texas Gas's tariff. Notwithstanding the foregoing, either party may assign
its right, title and interest in, to and by virtue of this Agreement including
any and all extensions, renewals, amendments, and supplements thereto, to a
trustee or trustees, individual or corporate, as security for bonds or other
obligations or securities, without such trustee or trustees assuming or becoming
in any respect obligated to perform any of the obligations of the assignor and,
if any such trustee be a corporation, without its being required by the parties
hereto to qualify to do business in the state in which the performance of this
Agreement may occur, nothing contained herein shall require consent to transfer
this Agreement by virtue of merger or consolidation of a party hereto or a sale
of all or substantially all of the assets of a party hereto, or any other
corporate reorganization of a party hereto.
11.9 This Agreement insofar as it is affected thereby, is subject to all valid
rules, regulations, and orders of all governmental authorities having
jurisdiction.
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11.10 No waiver by either party of any one or more defaults by the other in the
performance of any provisions hereunder shall operate or be construed as a
waiver of any future default or defaults whether of a like or a different
character.
IN WITNESS WHEREOF, the parties hereto have caused this Agreement to be
signed by their respective representatives thereunto duly authorized, on the day
and year first above written.
ATTEST: TEXAS GAS TRANSMISSION CORPORATION
/s/ ▇▇▇▇▇▇ ▇. ▇▇▇▇ By /s/ (ILLEGIBLE)
---------------------------- -----------------------------------------
Asst. Secretary Vice President
WITNESSES: MISSISSIPPI VALLEY GAS COMPANY
By /s/ (ILLEGIBLE)
---------------------------- -----------------------------------------
Attest /s/ (ILLEGIBLE)
---------------------------- -------------------------------------
_____ Secretary
Date of Execution by Customer:
30 Oct 97
----------------------------
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CONTRACT NO. N000120
EXHIBIT A
FIRM POINT(S) OF RECEIPT
MISSISSIPPI VALLEY GAS COMPANY
FIRM NO-NOTICE TRANSPORTATION
AGREEMENT
DAILY FIRM
METER CAPACITY (MMBtu)
LATERAL SEGMENT ZONE NO. NAME WINTER SUMMER
------- ------- ---- ----- ---- ------ ------
BEGIN LIST OF FIRM RECEIPT POINTS
NORTH LOUISIANA LEG
Carthage - ▇▇▇▇▇▇▇▇
▇ ▇▇▇▇ ▇▇▇▇▇▇▇▇ 0 2,500
▇▇▇▇▇▇ - East
1 8760N Lonewa (NLA) 0 0
EAST LEG
▇▇▇▇▇ - ▇▇▇▇▇▇
SL 2740 Superior-Pure 0 0
SOUTHEAST LEG
B1k. 8 - ▇▇▇▇▇▇ City
SL 2460 Peltex Deep Saline #1 0 0
SL 2463 ▇▇▇▇ Oil 0 0
SL ▇▇▇▇ ▇▇▇▇ ▇▇▇▇▇ 0 0
SL 2755 Texaco-Bay Junop 0 0
Henry - Lafayette
SL 2790 ▇▇▇▇▇ Hub 6,782 4,282
▇▇▇▇▇▇ City - Lafayette
SL 2454 FMP/Bayou Postillion 0 0
SL 9173 ANR-Calumet (Rec.) 0 0
SOUTH LEG
▇▇▇▇ - ▇▇▇▇▇▇
SL 9003 ▇▇▇▇ 0 0
SOUTHWEST LEG
▇▇▇▇▇ - ▇▇▇▇▇▇
SL 2437 ENOGEX/NGPL Tap Washita 0 0
SL 9170 Transok/NGPL Inter #2 ▇▇▇▇▇▇ 0 0
SL 9843 Mobil - ▇▇▇▇▇ 0 0
WEST LEG
Mallard Bay - Woodlawn
SL 2207 ▇▇▇▇▇▇ Petroleum-▇▇▇▇▇▇▇▇ 0 0
MAINLINE
Bastrop - North
1 1631 MVG Allocation Point 5,000 5,000
EFFECTIVE DATE: July 1, ▇▇▇▇
▇▇▇▇▇▇▇▇ ▇▇. ▇▇▇▇▇▇▇
EXHIBIT A
FIRM POINT(S) OF RECEIPT
MISSISSIPPI VALLEY GAS COMPANY
FIRM NO-NOTICE TRANSPORTATION
AGREEMENT
DAILY FIRM
METER CAPACITY (MMBtu)
LATERAL SEGMENT ZONE NO. NAME WINTER SUMMER
------- ------- ---- ----- ---- ------ ------
WC-294 (at ANR-▇▇▇▇▇▇)
Included under Mainline
HIOS (at ANR-▇▇▇▇▇▇)
Included under Mainline
End List of Firm Receipt Points.
Note: 199 MMBtu/D at ▇▇▇▇▇ (Meter No. 2790) available to Duck Hill (N015853),
until 10/30/2002.
EFFECTIVE DATE: July 1, 2000
EXHIBIT "A-I"
SECONDARY POINT(S) OF RECEIPT
TGT
METER
LATERAL SEGMENT ZONE NO. DRN SUPPLY POINT
------- ------- ---- ----- --- ------------
NORTH LOUISIANA
Carthage-Haughton 1 2102 152451 ▇▇▇▇▇▇▇▇
▇ ▇▇▇▇ ▇▇▇▇▇ ▇▇▇▇▇
1 9051 7148 ▇▇▇▇▇▇▇
1 8116 42473 Texas Eastern-Sligo
1 9884 49099 Valero-Carthage
▇▇▇▇▇▇▇▇-▇▇▇▇▇▇ 1 8003 43390 ▇▇▇▇▇▇▇▇▇
1 2455 38387 Beacon
1 9866 44088 Cornerstone-Ada
1 2340 7787 ▇.▇. ▇▇▇▇▇▇▇▇▇-▇▇▇▇▇▇
1 2186 7790 LGI#1
1 2456 7046 ▇▇▇▇▇▇▇▇▇
1 2457 7788 ▇▇▇▇▇▇-▇▇▇▇
1 2459 11259 Minden Pan-Am #1
1 9819 43554 ▇▇▇▇▇▇-▇▇▇▇▇▇
1 9461 43555 ▇▇▇▇-▇▇▇▇▇▇▇▇▇▇
1 2760 38250 Sligo Plant
1 9834 49082 Texaco-Athens
▇▇▇▇▇▇ 1 2145 38281 Claiborne
1 9439 185980 Energy Management-Antioch
1 2010 7795 Fina Oil-HICO
1 9818 7739 PGC-Bodcaw
1 2757 7792 Texas Eastern-▇▇▇▇▇▇
▇▇▇▇▇▇-East 1 9418 171295 Associated-▇▇▇▇▇▇▇
1 2631 38310 ▇▇▇▇▇▇▇ Plant
1 2632 38300 Dubach
1 2202 144066 Ergon-Monroe
1 8760 9334 Lonewa
1 8020 9217 MRT-Bastrop
1 9302 9335 ▇▇▇▇▇
1 9812 43556 Par Minerals/Downsville
1 9823 43559 Reliance-▇▇▇▇▇▇▇
1 2612 10799 Reliance-West Monroe
1 2634 9339 Southwest-▇▇▇▇▇▇▇
EAST
▇▇▇▇▇-▇▇▇▇▇▇ SL 2015 6512 Amerada ▇▇▇▇
▇▇ 2016 6513 Amerada ▇▇▇▇-South Lewisburg
SL 2385 6517 ▇.▇. ▇▇▇▇▇▇▇▇▇ #1
SL 2288 6508 Great Southern-Mowata #2
SL 9804 6545 Great Southern-Mowata #3
SL 8142 6549 ▇▇▇▇▇▇▇
▇▇ 2740 6499 Superior-Pure
A-I-1
TGT
METER
LATERAL SEGMENT ZONE NO. DRN SUPPLY POINT
------- ------- ---- ----- --- ------------
SOUTHEAST
Blk. 8-▇▇▇▇▇▇ City SL 2198 10590 Bois D'Arc
SL 9142 140570 Bois ▇'▇▇▇-▇▇▇▇▇▇▇ ▇▇▇▇
▇▇ ▇▇▇▇ ▇▇▇▇▇ ▇▇▇▇▇▇▇-▇▇▇▇▇ 8
SL 2638 31567 ▇▇▇▇ Point
SL 2845 10533 Lake ▇▇▇▇▇
▇▇ 2460 43557 Peltex Deep Saline #1
SL 2480 31554 S.S. 41
SL 9471 43569 Sohio
SL 2755 10587 Texaco-Bay ▇▇▇▇▇
▇▇ 9836 10595 Texaco-Dog Lake
SL 2463 43572 ▇▇▇▇ Oil
SL 9883 10591 Zeit-Lake ▇▇▇▇▇
▇▇▇▇▇-▇▇▇▇▇▇▇▇▇ ▇▇ 3190 10902 ▇▇▇▇▇▇▇▇-▇▇▇▇▇
SL 2790 42612 ▇▇▇▇▇ Hub
▇▇▇▇▇▇▇▇▇-▇▇▇▇▇▇ SL 2125 8741 California Co.-North ▇▇▇▇▇
▇▇ 2138 6500 California Co.-South Bosco #2
SL 2339 8737 ▇▇▇▇▇
▇▇ 9837 43488 Excel-▇▇▇▇▇▇
▇▇ 2601 8732 Fina Oil-Anslem Coulee
SL 8040 6525 Florida
SL 2290 6544 Gulf Transport-Church Pt.
SL 9906 38741 ▇▇▇▇▇▇▇▇-South ▇▇▇▇▇
▇▇ 9005 6538 Rayne-Columbia Gulf
SL 3067 8736 South ▇▇▇▇▇
▇▇ 2810 8738 Tidewater-North ▇▇▇▇▇
▇▇ 8051 8727 Youngsville
▇▇▇▇▇▇▇-Freshwater SL 9501 204880 Araxas-Abbeville
SL 2147 10898 CNG-Hell Hole Bayou
SL 2203 10890 Deck Oil-Perry/Hope
SL 9160 140571 LLOG-Abbeville
SL 2394 10906 LRC-▇▇▇▇▇▇
▇▇ 9800 43550 May Petroleum
SL 2748 127418 Parc ▇▇▇▇▇▇
▇▇ 2749 10896 ▇▇▇▇ ▇▇▇▇▇▇ ▇
▇▇ ▇▇▇▇ ▇▇▇▇▇ ▇&▇ ▇▇▇-▇▇▇▇▇▇▇▇▇
SL 9434 171296 Southwestern-▇▇▇▇▇
▇▇ 2706 40933 Sun ▇▇▇
▇▇ 9422 160243 UNOCAL-Freshwater Bayou
SL 2840 10900 UNOCAL-N. Freshwater Bayou
▇▇▇▇▇▇ City-▇▇▇▇▇▇▇▇▇ ▇▇ 2064 43425 Amoco-Charenton
SL 9173 10277 ANR-Calumet (Rec.)
SL 9803 38341 Atlantic
SL 9809 43733 B.H. Petroleum-S.E. ▇▇▇▇▇
▇▇ 9881 80583 Bridgeline-▇▇▇▇▇▇▇
▇▇ 2085 10270 British American-▇▇▇▇▇
▇▇ 9412 185979 Equitable-Lake ▇▇▇▇▇▇▇▇
▇▇ 9047 8223 Florida Gas-▇.▇. ▇▇▇▇▇▇
SL 2454 8215 FMP/Bayou Postillion
A-I-2
TGT
METER
LATERAL SEGMENT ZONE NO. DRN SUPPLY POINT
------- ------- ---- ----- --- ------------
SOUTHEAST (CONT.) SL 8059 10279 ▇▇▇▇▇▇▇▇
▇▇ 9437 171297 ▇▇▇▇ Oil-▇▇▇▇▇▇ Point
SL 9502 211243 ▇▇▇▇ Oil-East ▇▇▇▇▇▇ Point
SL 9854 43546 ▇▇▇▇▇▇ Oil-Bayou Penchant
SL 9853 60164 ▇▇▇▇▇▇ Oil-Garden City
SL 2189 43561 ▇▇▇▇▇▇▇▇ ▇▇▇▇
▇▇ 2636 8240 Shell-Bayou Pigeon
SL 8149 8235 SONAT-East Bayou Pigeon
SL 2035 10264 Southwest-Jeanerette
SL 9895 59632 Texaco-Bayou Sale
SL 8205 10272 Transco-▇▇▇▇▇▇ Point
SL 9829 10263 Trunkline-Centerville
▇▇▇▇▇▇▇▇▇-▇▇▇▇▇▇ City
SL 2250 33435 A. Glassell-Chacahoula
SL 2335 186009 Amoco-North ▇▇▇▇▇▇▇▇
▇▇ 2835 6912 Lake Palourde
SL 9873 8875 ▇▇▇▇▇▇ Oil-Chacahoula
SL 9175 124990 LLOG-Chacahoula
SL 9847 43636 LRC-Choctaw
SL 2440 8877 Magna-Chacahoula #1
SL 2445 8878 Magna-St. ▇▇▇▇ #2
SL 2470 60191 ▇▇▇▇▇▇▇▇▇-Chacahoula
SL 2135 10145 Simon Pass
SL 9431 144064 Transco-Thibodaux
SOUTH
▇▇▇▇-▇▇▇▇▇▇ SL 9003 38233 ▇▇▇▇
▇▇ 9415 171298 Tejas Power-▇▇▇▇
SOUTHWEST
East ▇▇▇▇▇▇▇-▇▇▇▇▇ ▇▇ 2581 30074 E.C. 14
SL 2033 43548 Little Cheniere-Arco
SL 2034 43549 Little Cheniere-▇▇▇▇▇▇
▇▇ 2392 7561 LRC-Grand Cheniere
▇▇▇▇▇-▇▇▇▇▇▇ SL 9843 156905 Mobil-▇▇▇▇▇
▇▇ 9446 7530 NGPL-▇▇▇▇▇
▇▇ 2437 149325 ENOGEX/NGPL Tap Washita
SL 9169 149326 TEX SW/NGPL Washita
SL 9171 149313 Transok/NGPL Inter #2 ▇▇▇▇▇▇▇
▇▇ 9170 149321 Transok/NGPL Inter #2 ▇▇▇▇▇▇
▇▇ 9172 149329 Transok/NGPL Waggs ▇▇▇▇▇▇▇
WEST
Iowa-Eunice SL 9507 21777 Camex-China
SL 8170 8613 Iowa
SL 9445 ▇▇▇▇ ▇▇▇▇▇▇ ▇▇▇▇▇▇▇-▇▇▇▇▇▇▇▇
▇▇▇▇▇▇▇ ▇▇▇-▇▇▇▇▇▇▇▇ SL 2140 8610 California Co.-South ▇▇▇▇▇▇▇▇▇
▇▇ 2615 7585 ▇▇▇▇▇▇▇▇ ▇▇▇▇ Sands-S. ▇▇▇▇▇▇▇▇▇
▇▇ 2207 60169 ▇▇▇▇▇▇ Petroleum-▇▇▇▇▇▇▇▇
▇▇ 9028 43506 Gas Energy Development-▇▇▇▇▇
▇▇ 2355 81054 Humble-▇▇▇▇▇▇▇▇
▇▇ 2383 7567 IMC Wintershall-▇▇▇▇▇▇▇▇
▇-▇-3
TGT
Meter
Lateral Segment Zone No. DRN Supply Point
------- ------- ---- ----- --- ------------
WEST (CONT.) SL 8071 7571 LRC-Mallard Bay
SL 9828 8585 Riverside-Lake ▇▇▇▇▇▇
▇▇ 2635 107453 Shell-▇▇▇▇▇▇▇▇
▇▇ 2822 7586 Superior-S. ▇▇▇▇▇▇▇▇▇
▇▇ 2885 8603 Union Texas-▇▇▇▇▇
▇.▇. 294
Entering at ANR- SL 9026 29497 W.C. 167/132
Eunice SL 9136 55151 W.C. 167/Near Shore
SL 9440 186036 W.C. 293/306A
SL 9396 60204 W.C. 293/H.I. 120/H.I. 120-128
SL 9383 43734 W.C. 293/H.I. 167/H.I. 167-166
SL 2838 29693 W.C. 294
HIOS
Offshore Points ▇.▇. ▇▇▇
▇▇▇▇▇▇▇▇ ▇▇ ▇▇▇-▇▇▇▇▇▇ ▇▇ ▇▇▇▇ ▇▇▇▇▇ ▇.▇. A-247/A-244A/A-231
SL 9176 154807 H.I. A-247/A-245
SL 9135 41343 W.C. 167/HIOS Mainline
▇.▇. ▇▇▇
▇▇ ▇▇▇▇ ▇▇▇▇▇ ▇.▇. A-283/A-283A
SL 9487 197839 H.I. A-283/A-443
SL 2855 33296 H.I. A-285/A-282
H.I. 303
SL 2858 43524 H.I. A-302A/A-303
H.I. 323
SL 9468 21334 H.I. A-323
H.I. 343
SL 9467 21339 H.I. ▇-▇▇▇/▇-▇▇▇
▇.▇. ▇-▇▇▇
▇▇ ▇▇▇▇ ▇▇▇▇▇ ▇.▇. A-334A/A-335
SL 9327 43529 H.I. A-345/A-325A
H.I. A-498
SL 2529 197837 H.I. A-498/A-451
SL 2536 197838 H.I. A-498/A-462/Various
SL 2534 60171 ▇.▇. ▇-▇▇▇/▇-▇▇▇
▇▇ ▇▇▇▇ ▇▇▇▇▇ ▇.▇. A-498/A-489/A-474
SL 2535 60174 ▇.▇. ▇-▇▇▇/▇-▇▇▇/▇-▇▇▇
▇▇ ▇▇▇▇ ▇▇▇▇▇ ▇.▇. A-498/A-490
SL 2856 43723 H.I. ▇-▇▇▇/▇-▇▇▇
▇.▇. ▇-▇▇▇
▇▇ ▇▇▇▇ ▇▇▇▇▇ ▇.▇. A-539/A-480
SL 9365 60178 H.I. A-539/A-511
SL 9508 216653 ▇.▇. ▇-▇▇▇/▇-▇▇▇
▇▇ ▇▇▇▇ ▇▇▇▇▇ ▇.▇. A-539/A-532
SL 9328 60179 H.I. ▇-▇▇▇/▇-▇▇▇
▇-▇-▇
TGT
Meter
Lateral Segment Zone No. DRN Supply Point
------- ------- ---- ----- --- ------------
HIOS (CONT.) SL 9901 81051 H.I. A-539/A-552/A-551
SL 9889 49104 ▇.▇. ▇-▇▇▇/▇-▇▇▇/▇-▇▇▇
▇▇ ▇▇▇▇ ▇▇▇▇▇ ▇.▇. A-539/A-567
SL 9380 60182 H.I. A-539/A-568
H.I. 546
SL 9466 21336 H.I. ▇-▇▇▇/▇-▇▇▇/▇-▇▇▇
▇.▇. ▇-▇▇▇
▇▇ ▇▇▇▇ ▇▇▇▇▇ ▇.▇. A-531A
SL 2861 43122 H.I. A-536C
SL 2862 43123 H.I. A-537B
SL 9127 54854 H.I. A-537B/A-537D/A-556
SL 9308 60183 ▇.▇. ▇-▇▇▇
▇▇ ▇▇▇▇ ▇▇▇▇▇ ▇.▇. A-555/A-537D/A-556
SL 9887 49105 H.I. A-555/A-557A/A-556
▇.▇. ▇-▇▇▇
▇▇ ▇▇▇▇ ▇▇▇▇▇ ▇.▇. A-573/A-384/G B 224
SL 2859 43531 ▇.▇. ▇-▇▇▇▇ ▇▇▇▇▇▇▇
▇▇ ▇▇▇▇ ▇▇▇▇▇ ▇.▇. A-595CF Complex
▇.▇. ▇-▇▇▇
▇▇ ▇▇▇▇ ▇▇▇▇▇▇ ▇.▇. A-582/A-561A
SL 9469 221329 H.I. A-582/A-563/A-564
SL 9470 221328 ▇.▇. ▇-▇▇▇/▇-▇▇▇▇
▇▇ ▇▇▇▇ ▇▇▇▇▇ ▇.▇. A-582/E.B. 110
SL 9377 49107 H.I. A-582/E.B. 160/Various
SL 9134 81052 H.I. A-582/E.B. 165
MAINLLNE
Bastrop-North 3 8082 6463 ANR-Slaughters
3 2061 4308 Bee-Hunter
3 2072 6385 ▇▇▇▇▇
4 1229 108797 Cincinnati Gas and Electric Co.
3 1367 132995 Citizens Gas & Coke Utility
2 8124 41187 Dyersburg
1 9871 132993 Entergy-Helena
3 9459 186011 ▇▇▇▇▇-▇▇▇▇▇▇▇▇▇
3 9432 186010 Har-▇▇▇/▇▇▇▇▇▇ ▇▇▇▇▇▇▇▇ #1
3 9530 6461 Har-▇▇▇/▇▇▇▇▇▇
1 9303 1484 Helena #2
3 1440 108798 Indiana Gas Company, Inc.
4 1433 140534 Indiana Utilities Corporation
4 9522 223429 Indiana Utilities-New Albany Shale
4 1489 132837 Lawrenceburg Gas Company
4 1715 16281 Lebanon-Columbia
4 1247 ▇▇▇▇▇ ▇▇▇▇▇▇▇-▇▇▇▇▇▇
4 1859 16284 ▇▇▇▇▇▇▇-▇▇▇▇▇ ▇▇▇▇▇▇▇
▇ ▇▇▇▇ ▇▇▇▇▇ ▇▇▇▇▇▇▇-▇▇▇▇▇ ▇▇▇▇
1 1600 132977 Memphis Light, Gas and Water Division
3 8073 6134 Midwestern-Whitesville
1 3801 134577 Pooling Receipt-Zone 1
A-I-5
TGT
Meter
Lateral Segment Zone No. DRN Supply Point
------- ------- ---- ----- --- ------------
MAINLINE (CONT.) 3 9525 6447 Pride Energy ▇▇. ▇
▇ ▇▇▇▇ ▇▇▇▇▇▇ ▇▇▇▇▇▇▇▇-▇▇▇▇▇ ▇▇▇▇▇
3 5800 128355 Slaughters-Storage Complex (Withdraw)
3 1810 132845 Southern Indiana Gas and Electric Co.
4 1872 125662 Union Light, Heat and ▇▇▇▇▇ ▇▇.
▇ ▇▇▇▇ ▇▇▇▇▇ ▇▇▇▇▇▇ ▇▇▇▇▇▇-▇▇▇▇▇▇▇▇
2 1885 132856 Western Kentucky Gas Company
3 1906 108800 Western Kentucky Gas Company
3 1912 21773 Western Kentucky Gas Company
4 1981 132852 Western Kentucky Gas Company
▇▇▇▇▇▇-Zone SL/1 Line SL 9035 6519 ANR-Eunice
SL 9084 105453 Bayou ▇▇▇▇▇▇
▇▇ 8107 8120 ▇▇▇▇▇▇▇▇▇▇
SL 9536 225010 Louisiana Chalk-Eunice
SL 8046 8121 ▇▇▇▇▇
▇▇ 3800 124803 Pooling Receipt-Zone SL
SL 3900 154805 SL Lateral Terminus
Zone SL/1 Line-Bastrop 1 2020 44085 Arkla-Perryville
1 9870 44087 Channel Explo.-Chicksaw Creek
1 9826 9332 Delhi-▇▇▇▇▇
1 9882 60205 ▇▇▇▇▇▇▇-▇▇▇▇▇▇ ▇▇▇▇▇
▇ ▇▇▇▇ ▇▇▇▇▇ ▇▇▇▇▇▇▇-▇▇▇▇▇ Plant
1 2361 9321 ▇▇▇▇▇▇-Millhaven
1 9814 43538 ▇▇▇▇▇-▇▇▇▇▇ Lake
1 8063 9670 Pineville (LIG)
1 2648 9214 Spears
1 9832 43414 Wintershall-Clarks
▇-▇-▇
▇▇▇▇▇▇▇▇ ▇▇. ▇▇▇▇▇
Winter Contract Demand - 50,429 MMBtu/D
Summer Contract Demand - 5,000 MMBtu/D
EXHIBIT "B"
POINT(S) OF DELIVERY
ZONE I
Meter MAOP MDP*
No. DRN Name and Description Facilities (psig) (psig)
----- ----- -------------------- ---------- ------ ------
1631 60206 Mississippi Valley Gas Company
BENOIT - ▇▇▇, ▇▇▇▇, ▇▇▇, ▇▇▇▇▇▇▇ ▇▇▇▇▇▇, ▇▇ (1) 600 ▇▇▇
▇▇▇▇▇▇▇ ▇▇▇▇▇▇▇▇ - ▇▇, ▇▇▇▇, ▇▇▇, ▇▇▇▇▇▇▇
▇▇▇▇▇▇, ▇▇ (1) 810 ▇▇▇
▇▇▇▇▇▇▇▇▇▇ - ▇▇▇, ▇▇▇▇, ▇▇▇, ▇▇▇▇▇▇▇
▇▇▇▇▇▇, ▇▇ (1) 560 ▇▇▇
▇▇▇▇▇▇▇▇▇▇ ▇▇▇ ▇▇▇▇ - ▇▇▇, ▇▇▇▇, ▇▇▇,
▇▇▇▇▇▇▇ ▇▇▇▇▇▇, ▇▇ (1) ▇▇▇ ▇▇▇
▇▇▇▇▇▇▇▇▇ - ▇▇▇ ▇▇▇▇, ▇▇▇, ▇▇▇▇▇▇▇ ▇▇▇▇▇▇, ▇▇ (1) 640 ▇▇▇
▇▇▇▇▇▇ ▇▇▇▇▇▇▇▇ - ▇▇▇, ▇▇▇, ▇▇▇, ▇▇▇▇▇▇
▇▇▇▇▇▇, ▇▇ (1) 674 ▇▇▇
▇▇▇▇▇▇ - ▇▇▇, ▇▇▇▇, ▇▇▇, ▇▇▇▇▇▇▇ ▇▇▇▇▇▇, ▇▇ (1) 840 ▇▇▇
▇▇▇▇▇▇▇ ▇▇▇▇▇▇▇▇ - ▇▇, ▇▇▇, ▇▇▇▇, ▇▇▇▇▇▇
▇▇▇▇▇▇, ▇▇ (1) 486 ▇▇▇
▇▇▇ ▇▇▇▇ - ▇▇▇, ▇▇▇, ▇▇▇, ▇▇▇▇▇▇ ▇▇▇▇▇▇, ▇▇ (1) 840 ▇▇▇
▇▇▇▇▇▇▇▇▇▇ - ▇▇▇, ▇▇▇, ▇▇▇, ▇▇▇▇▇▇ ▇▇▇▇▇▇, ▇▇ (1) 674 ▇▇▇
▇▇▇▇▇▇▇▇▇ - ▇▇, ▇▇▇▇, ▇▇▇, ▇▇▇▇▇▇▇ ▇▇▇▇▇▇, ▇▇ (1) 560 ▇▇▇
▇▇▇▇ ▇▇▇▇▇▇▇▇▇ - ▇▇▇, ▇▇▇, ▇▇▇▇, ▇▇▇▇▇▇
▇▇▇▇▇▇, ▇▇ (1) 500 ▇▇▇
▇▇▇▇ ▇▇▇▇▇▇▇▇▇ #▇ - ▇▇▇, ▇▇▇, ▇▇▇, ▇▇▇▇▇▇
▇▇▇▇▇▇, ▇▇ (1) ▇▇▇ ▇▇▇
▇▇▇▇ - ▇▇▇, ▇▇▇▇, ▇▇▇, ▇▇▇▇▇▇▇ ▇▇▇▇▇▇, ▇▇ (1) 500 ▇▇▇
▇▇▇▇▇▇▇▇▇ - ▇▇▇, ▇▇▇, ▇▇▇, ▇▇▇▇▇▇ ▇▇▇▇▇▇. ▇▇ (1) ▇▇▇ ▇▇▇
▇▇▇▇ - ▇▇▇, ▇▇▇▇, ▇▇▇, ▇▇▇▇▇▇▇ ▇▇▇▇▇▇, ▇▇ (1) 640 ▇▇▇
▇▇▇▇▇▇▇▇ ▇▇. ▇ - ▇▇, ▇▇▇▇, ▇▇▇, ▇▇▇▇▇▇▇
▇▇▇▇▇▇, ▇▇ (1) 640 ▇▇▇
▇▇▇▇▇▇▇▇ ▇▇. ▇ - ▇▇, ▇▇▇▇, ▇▇▇, ▇▇▇▇▇▇▇
▇▇▇▇▇▇, ▇▇ (1) 640 250
MVG-GREENVILLE AIR BASE - S22, T19N, R8W
Washington County, MS (1) 600 ▇▇▇
▇▇▇-▇▇▇▇▇▇▇▇▇▇ #▇ - ▇▇▇, ▇▇▇▇, ▇▇▇,
▇▇▇▇▇▇▇▇▇▇ ▇▇▇▇▇▇, ▇▇ (1) 640 ▇▇▇
▇▇▇-▇▇▇▇▇▇▇▇▇▇ #▇ - ▇▇▇, ▇▇▇▇, ▇▇▇,
▇▇▇▇▇▇▇▇▇▇ ▇▇▇▇▇▇, ▇▇ (1) 840 ▇▇▇
▇▇▇-▇▇▇▇▇▇▇▇▇▇ #▇ - ▇▇▇, ▇▇▇▇, ▇▇▇,
▇▇▇▇▇▇▇▇▇▇ ▇▇▇▇▇▇, ▇▇ (1) 672 250
MVG-HARDY SPRINGS - Grenada County, MS (1)
NATIONAL PACKING - S14, T17N, R9W, (1) 672 150
B-1
NOTE: SEE ATTACHED STANDARD FACILITIES KEY FOR EXPLANATION OF FACILITIES.
*MINIMUM DELIVERY PRESSURE
Meter MAOP MDP*
No. DRN Name and Description Facilities (psig) (psig)
----- ----- -------------------- ---------- ------ ------
Washington County, MS
▇▇▇▇▇ ▇▇▇▇▇▇ - ▇▇▇, ▇▇▇, ▇▇▇▇, ▇▇▇▇▇▇
▇▇▇▇▇▇, ▇▇ (1) ▇▇▇
▇▇▇▇▇▇ ▇▇▇▇▇▇▇▇ - ▇▇▇, ▇▇▇▇, ▇▇▇, ▇▇▇▇▇▇▇▇▇▇
▇▇▇▇▇▇, ▇▇ (1) ▇▇▇ ▇▇▇
▇▇▇▇▇▇▇▇▇▇▇▇▇ - ▇▇▇, ▇▇▇, ▇▇▇▇, ▇▇▇▇▇▇
▇▇▇▇▇▇, ▇▇ (1) 486 325
RURAL-MS-MVG ▇▇
▇▇▇▇▇ - ▇▇▇, ▇▇▇▇, ▇▇▇, ▇▇▇▇▇▇▇ ▇▇▇▇▇▇, ▇▇ (1) ▇▇▇ ▇▇▇
▇▇▇▇▇▇ - ▇▇, ▇▇▇▇, ▇▇▇, ▇▇▇▇▇▇▇ ▇▇▇▇▇▇, ▇▇ (1) ▇▇▇ ▇▇▇
▇▇▇▇▇▇ - ▇▇, ▇▇▇, ▇▇▇▇, ▇▇▇▇▇▇ ▇▇▇▇▇▇, ▇▇ (1) 500 ▇▇▇
▇▇▇▇▇ ▇▇▇▇▇ ▇▇▇▇ - ▇▇▇, ▇▇▇▇, ▇▇▇,
▇▇▇▇▇▇▇ ▇▇▇▇▇▇, ▇▇
▇▇▇▇▇ - S33, T1S, R9W, DeSoto County, MS (1) 417 150
B-2
NOTE: SEE ATTACHED STANDARD FACILITIES KEY FOR EXPLANATION OF FACILITIES.
*MINIMUM DELIVERY PRESSURE
-----------------------------
CONTRACT NO. N000120
-----------------------------
FIRM NO-NOTICE TRANSPORTATION
AGREEMENT
EXHIBIT C
SUPPLY LATERAL CAPACITY
MISSISSIPPI VALLEY GAS COMPANY
PREFERENTIAL RIGHTS
MMBTU/D
SUPPLY LATERAL WINTER SUMMER
------ ------
Zone 1 Supply Lateral(s)
North Louisiana Leg: 0 2,500
------ ------
Total Zone 1: 0 2,500
Zone SL Supply Lateral(s)
East Leg: 0 0
Southeast Leg: 6,782 4,282
South Leg: 0 0
Southwest Leg: 0 0
West Leg: 0 0
WC-294 (at ANR-▇▇▇▇▇▇): 0 0
HIOS (at ANR-▇▇▇▇▇▇): 0 0
------ ------
Total Zone SL: 6,782 4,282
------ ------
Grand Total: 6,782 6,782
====== ======
NOTE: QUANTITIES SHOWN INCLUDE 199 MMBTU/D ON THE SOUTHEAST LATERAL RELEASED TO
DUCK HILL (N15853) UNTIL 10/30/2002.
EFFECTIVE DATE: July 1, 2000
STANDARD FACILITIES KEY
(1) Measurement facilities are owned, operated, and maintained by Texas Gas
Transmission Corporation.
(2) Measurement facilities are owned, operated, and maintained by ANR
Pipeline Company.
(3) Measurement facilities are owned, operated, and maintained by Arkansas
Louisiana Gas Company.
(4) Measurement facilities are owned by Texas Gas Transmission Corporation
and operated and maintained by ▇▇▇▇-▇▇▇▇▇ Corporation.
(5) Measurement facilities are owned, operated, and maintained by ▇▇▇▇
Gateway Pipeline Company.
(6) Measurement facilities are owned by Texas Gas Transmission Corporation
and operated and maintained by Delhi Gas Pipeline Corporation.
(7) Measurement facilities are owned, operated, and maintained by
▇▇▇▇-▇▇▇▇▇ Corporation.
(8) Measurement facilities are owned, operated, and maintained by Louisiana
Intrastate Gas Corporation.
(9) Measurement facilities are owned, operated, and maintained by Trunkline
Gas Company.
(10) Measurement facilities are owned, operated, and maintained by Columbia
Gulf Transmission Company.
(11) Measurement facilities are owned by Texas Gas Transmission Corporation
and operated and maintained by Columbia Gulf Transmission Company.
(12) Measurement facilities are owned, operated, and maintained by Florida
Gas Transmission Company.
(13) Measurement facilities are owned by Texas Gas Transmission Corporation
and operated and maintained by ANR Pipeline Company.
(14) Measurement facilities are owned by ▇▇▇▇▇▇▇▇ Petroleum Company and
operated and maintained by ANR Pipeline Company.
(15) Measurement facilities are owned by Transcontinental Gas Pipe Line
Corporation and operated and maintained by ANR Pipeline Company.
(16) Measurement facilities are jointly owned by others and operated and
maintained by ANR Pipeline Company.
(17) Measurement facilities are owned by ▇▇▇▇ Gateway Pipeline Company and
operated and maintained by ANR Pipeline Company.
(18) Measurement facilities are owned by Texas Gas Transmission Corporation
and operated and maintained by Texas Eastern Transmission Corporation.
(19) Measurement facilities are owned by Texas Gas Transmission Corporation
and operated and maintained by Natural Gas Pipeline Company of America.
(20) Measurement facilities are owned by Louisiana Intrastate Gas
Corporation and operated and maintained by Texas Gas Transmission
Corporation.
(21) Measurement facilities are owned, operated, and maintained by Texas
Eastern Transmission Corporation.
(22) Measurement facilities are owned by ▇▇▇▇-▇▇▇▇▇ Corporation and operated
and maintained by ANR Pipeline Company.
(23) Measurement facilities are operated and maintained by ANR Pipeline
Company.
(24) Measurement facilities are owned, operated, and maintained by
Transcontinental Gas Pipe Line Corporation.
(25) Measurement facilities are owned by Texas Gas Transmission Corporation
and operated and maintained by Tennessee Gas Pipeline Company.
(26) Measurement facilities are owned, operated, and maintained by Northern
Natural Gas Company.
(27) Measurement facilities are owned and maintained by ▇▇▇▇▇▇▇▇ Pipeline
Company and operated by Texas Gas Transmission Corporation.
(28) Measurement facilities are owned by Samedan and operated and maintained
by ANR Pipeline Company.
(29) Measurement facilities are owned by Texas Gas Transmission Corporation
and operated and maintained by CNG Producing.
(30) Measurement facilities are owned, operated, and maintained by Devon
Energy Corporation.
(31) Measurement facilities are owned by Total Minatome Corporation and
operated and maintained by Texas Gas Transmission Corporation.
(32) Measurement facilities are owned by Texas Gas Transmission Corporation
and operated and maintained by Trunkline Gas Company.
(33) Measurement facilities are owned by ▇▇▇▇▇▇ Oil Company and operated and
maintained by Texas Gas Transmission Corporation.
(34) Measurement facilities are owned, operated, and maintained by
Mississippi River Transmission Corporation.
(35) Measurement facilities are owned, operated, and maintained by Texaco
Inc.
(36) Measurement facilities are owned by Texas Gas Transmission Corporation
and operated and maintained by Louisiana Resources Company.
(37) Measurement facilities are owned, operated, and maintained by Louisiana
Resources Company.
(38) Measurement facilities are owned by Oklahoma Gas Pipeline Company and
operated and maintained by ANR Pipeline Company.
(39) Measurement and interconnecting pipeline facilities are owned and
maintained by Louisiana Resources Company. The measurement facilities
are operated and flow controlled by Texas Gas Transmission Corporation.
(40) Measurement facilities are owned by ▇▇▇▇-▇▇▇▇▇▇▇ and operated and
maintained by ANR Pipeline Company.
(41) Measurement facilities are owned, operated, and maintained as specified
in Exhibit "B".
(42) Measurement facilities are owned by Enron Corporation and operated and
maintained by Texas Gas Transmission Corporation.
(43) Measurement facilities are owned by United Cities Gas Company and
operated and maintained by TXG Engineering, Inc.
(44) Measurement facilities are owned, operated, and maintained by NorAm Gas
Transmission Company.
(45) Measurement facilities are owned by Falcon Seaboard Gas Company and
operated and maintained by Texas Gas Transmission Corporation.
(46) Measurement facilities are owned by ANR Pipeline Company and operated
and maintained by High Island Offshore System.
(47) Measurement facilities are owned by Forest Oil Corporation, et al., and
operated and maintained by Tenneco Gas Transportation Company.
(48) Measurement facilities are owned by PSI, Inc., and operated and
maintained by ANR Pipeline Company.
(49) Measurement facilities are owned, operated, and maintained by Tennessee
Gas Pipeline Company.
(50) Measurement facilities are owned, operated, and maintained by Colorado
Interstate Gas Company.
(51) Measurement facilities are owned by Producer's Gas Company and operated
and maintained by Natural Gas Pipeline Company of America.
(52) Measurement facilities are owned by ▇▇▇▇▇▇ Exploration and operated and
maintained by ANR Pipeline Company.
(53) Measurement facilities are jointly owned by Amoco, Mobil, and Union;
operated and maintained by ANR Pipeline Company.
(54) Measurement facilities are owned, operated, and maintained by VHC Gas
Systems, L.P.
(55) Measurement facilities are owned by ▇▇▇▇▇▇ Oil and Gas and operated and
maintained by Columbia Gulf Transmission Company.
(56) Measurement facilities are operated and maintained by Natural Gas
Pipeline Company of America.
(57) Measurement facilities are operated and maintained by Texas Gas
Transmission Corporation.
(58) Measurement facilities are operated and maintained by Tennessee Gas
Pipeline Company.
(59) Measurement facilities are operated and maintained by Columbia Gulf
Transmission Company.
(60) Measurement facilities are owned, operated, and maintained by
Midwestern Gas Transmission Company.
(61) Measurement facilities are owned, operated, and maintained by Western
Kentucky Gas Company.
(62) Measurement facilities are owned by ▇▇▇▇ Hub Partners, L. P., and
operated and maintained by Texas Gas Transmission Corporation.
(63) Measurement facilities are owned and maintained by Louisiana Chalk
Gathering System and operated by Texas Gas Transmission Corporation.