EXHIBIT 10.30
AGREEMENT BETWEEN ALASKA PIPELINE COMPANY
AND SHELL WESTERN E&P INC.
TO AMEND A RETAINED INTEREST IN THE GAS PURCHASE
CONTRACT BETWEEN SHELL OIL COMPANY
AND ALASKA PIPELINE COMPANY
DATED DECEMBER 20, 1982
This is an Agreement dated November 15, 1991 to amend an interest in
the Gas Purchase Contract dated December 20, 1982, between Shell Oil Company
("Shell") and Alaska Pipeline Company ("Buyer"). That contract is referred to in
this Agreement as the Beluga Contract. Effective January 1, 1984, Shell assigned
its interest in the Beluga Contract to Shell Western E&P Inc. ("SWEPI").
Effective Xxxxx 0, 0000, XXXXX assigned to ARCO Alaska, Inc. ("ARCO") a
one-third undivided interest in the Beluga Contract and ARCO assumed a one-third
undivided interest in Seller's benefits and obligations under the Beluga
Contract. The assignment and cover letter establishing the effective date are
attached as Exhibit B. The parties to this Agreement are Alaska Pipeline Company
and SWEPI.
This Agreement amends only SWEPI's Retained Interest in the Beluga
Contract. There is a similar, consistent, but not identical agreement with ARCO
which amends ARCO's one-third interest in the Beluga Contract and a separate
settlement agreement
1
dated November 15, 1991, which resolves litigation pertinent to and affecting
this Agreement.
The parties wish to amend SWEPI's Retained Interest. Except as
expressly modified by this Agreement, the Beluga Contract terms remain in effect
and the terms used in this Agreement shall have the same meaning as in the
Beluga Contract. In the event that the terms of this Agreement are inconsistent
with those in the Beluga Contract, this Agreement shall govern the
interpretation of the Beluga Contract as amended by this Agreement.
The definition of "swing rate" defined in paragraph 1.16 of the
Beluga Contract is deleted and replaced with the following definition:
1.16 The term "swing rate" means Seller's maximum daily obligation
to deliver gas expressed in millions of cubic feet.
The term "Seller" used in the Beluga Contract is redefined to mean
Shell and ARCO.
Article V (Quantity) of the Beluga Contract is deleted in its
entirety and replaced by a new Article V:
ARTICLE V: QUANTITY
5.1 Attached Schedule 1 shall be used to determine the quantity of
gas which Buyer shall purchase each year from Seller, subject to the other terms
of this Agreement. Schedule 1 states the Annual Contract Quantity ("ACQ") by
year as a function of Total Market-Out Volume (as defined below). In any year in
which the
2
Total Market-Out Volume is zero, the ACQ shall be determined from the zero line
of Schedule 1. For example, if the Total Market Out Volume is zero in 1997, the
ACQ shall be 15 BCF. SWEPI shall be responsible for supplying two-thirds of the
ACQ.
If the Total Market Out Volume falls between the quantities shown in
the Total Market Out Column of Schedules 1 through 3, the ACQ (Schedule 1) and
the quantities at each price (Schedules 2 and 3) shall be determined by
interpolation (see Exhibit C).
5.2 The ACQ shall be reduced if any person or entity (other than
Chugach Electric Association, Inc.) which was a customer of Buyer or Buyer's
affiliate, ENSTAR Natural Gas Company ("ENSTAR"), on September 30, 1991,
purchases some or all of its gas supply from any source(s) other than Buyer or
ENSTAR. The quantity of gas purchased from the source(s) other than Buyer or
ENSTAR each year is the Market-Out Volume for that year. The sum of all
Market-Out Volumes each year is the Total Market-Out Volume for that year.
The reduced ACQ shall be determined from Schedule 1. For example,
assume that two businesses which were customers of ENSTAR on September 30, 1991
purchase in 1994 a total of 8 Bcf of gas from sources other than ENSTAR or
Buyer. The Total Market-Out Volume is 8 Bcf and the ACQ (from Schedule 1) for
1994 is 8.64 Bcf. SWEPI shall be responsible for supplying two-thirds of the ACQ
(5.76 Bcf in this example).
3
5.3 Attached Schedule 2 shows the quantities of gas which shall be
priced in accordance with paragraph 7.2(d)(i). Attached Schedule 3 shows the
quantities of gas which will be priced in accordance with paragraph 7.2 (d)
(ii). The sum of the quantities in Schedules 2 and 3 (for each year and Total
Market Out Volume) equals the ACQ shown in Schedule 1 (for the same year and
Total Market Out Volume).
5.4 Through 1995, the swing rate shall be 110 (i.e., Seller is
obligated to deliver a maximum of 110 million cubic feet per day) unless reduced
as provided in paragraph 5.4(b).
Beginning January 1, 1996, the swing rate shall be a pro-rata share
of Buyer's projected maximum daily demand on all suppliers calculated as
follows:
(a) No later than October 1st of each year (beginning in 1994), Buyer
shall give Seller a projection of Buyer's maximum daily demand on
all suppliers and total purchases from all suppliers, including
Seller, for each of the next two years. Buyer's forecast will not
exceed Buyer's historical daily peaks reasonably adjusted for known
or estimated changes, including load growth or decline, and Buyer's
estimate of Total Market-Out Volume. Seller shall have the right to
review all data on which the forecast is based. The swing rate for
the second year of the forecast shall be calculated by:
(i) using Buyer's estimate of Total Market Out Volume, to
determine the estimated ACQ from Schedule 1;
4
(ii) dividing the estimated ACQ by Buyer's forecast of total
purchases from all suppliers; and
(iii) multiplying the result of (ii) by Buyer's forecast of maximum
daily demand on all suppliers, including Seller.
All calculations are based on projected data for the second year of
the forecast. The first year of the forecast is informational only and will be
updated as the forecast "rolls" forward the following year. Balancing gas (see
paragraph 5.8) shall not affect the swing rate for any year.
An example of the calculation of swing rate for 1998 follows. Assume
that on October 1, of 1996, Buyer makes the following forecasts:
1997 1998
---- ----
Maximum daily demand (MMcf) on all suppliers, including Seller 230.00 235.00
Total purchases (Bcf) from all suppliers, including Seller 32.00 33. 00
The ACQ (Schedule 1, estimated Total Market-Out Volume of 8.00 Bcf) 11.00 11.00
Swing rate for 1998 = 11/33 x 235 = N/A 78.33
(b) If a person or entity (other than Chugach Electric Association,
Inc.) which was a customer of Buyer or ENSTAR on September 30, 1991, purchases
gas directly from the Beluga River Unit (See Exhibit A) at any time during the
years 1992 through 1995, the swing rate shall remain 110 but shall be applied to
Buyer and the customer collectively. Stated another way, Seller shall be
5
required to deliver up to, but not more than, 110 MMcf per day to Buyer and the
customer combined. For example, if the customer actually purchases 30 MMcf from
the Beluga River Unit on a given day, Seller's swing rate to Buyer on that day
shall be 80 MMcf (110 MMcf minus 30 MMcf).
After 1995, the swing rate shall be determined as provided in
paragraph 5.4(a).
(c) SWEPI shall be responsible for delivering two-thirds of the
swing rate calculated pursuant to this paragraph 5.4.
5.5 If any lessor (see Exhibit A to the Beluga Contract) elects to
take its royalty gas in-kind, Seller shall have the option of reducing both the
ACQ and swing rate (while royalty gas is being taken in-kind) by the ratio of
the total royalty gas taken in kind to the total production from the Beluga
River Unit while royalty gas is taken in kind.
5.6 Buyer shall use its best efforts to keep Seller informed as to
any peak demand that may occur during a period other than a normal peak demand
period so that Seller can more expediently schedule any well or field work that
Seller believes is necessary.
5.7 Subject to the other provisions of this Agreement, Seller must
produce and deliver to Buyer and Buyer must receive and pay for the ACQ. Buyer
has the right, but not the obligation, to purchase the swing rate from Seller on
any day of the year, regardless of whether the ACQ for that year has already
been taken. Nothing in this Agreement shall be construed to require Seller to
6
produce and deliver or Buyer to purchase and receive from Seller or to pay
Seller for any quantities of gas in excess of that which may be produced under
the applicable rules, regulations, and orders of regulatory bodies having
jurisdiction.
Buyer shall have the option to purchase daily quantities of gas, if
any, in excess of the swing rate then in effect which, in Seller's sole
judgment, can be produced and delivered efficiently and in accordance with good
operating practices and without impairment of Seller's obligations under current
or future gas sales contracts.
5.8 Despite Buyer's reasonable efforts, the quantity of gas Buyer is
obligated to take (i.e., the ACQ) and the quantity of gas Buyer actually takes
will not be equal each year because Buyer will not know its total purchases from
all suppliers or the Total Market-Out Volume until shortly after year-end due to
forecasting limitations, changes in weather, and other operating factors. Any
difference between actual purchases and the ACQ ("balancing gas") shall be
balanced in January and February of the following year using the following
procedures:
(a) If in any year Buyer purchases less than the ACQ
(deducting from actual purchases any balancing gas taken during that year to
satisfy the ACQ of prior years) , the balancing gas shall be purchased the
following year in addition to the ACQ for that year. During January and February
of the following year, all gas purchased shall be deemed to be balancing gas
until Buyer has purchased all the balancing gas it is obligated to purchase. The
7
price for balancing gas shall be the price in effect for the prior year (i.e.,
the year in which the balancing gas should have been purchased) . If all of the
balancing gas is not taken during January and February, Buyer shall pay in March
(when the xxxx for February deliveries is paid) for the balancing gas not taken.
Buyer may take the balancing gas paid for but not taken at any time through
December 31, 2010, or any earlier termination of the Beluga Contract, but the
balancing gas shall not reduce the ACQ Buyer is obligated to take each year. The
balancing gas taken by Buyer shall not exceed the volumes that Seller can
produce and deliver efficiently and in accordance with prudent operating
practices and without impairment of Seller's obligations under other gas sales
contracts.
(b) If in any year Buyer purchases more than the ACQ
(deducting from actual purchases any balancing gas taken during that year to
satisfy the ACQ of prior years) , the balancing gas shall be deducted from the
ACQ for the following year. The price for the balancing gas shall be the price
in effect during the year following the year in which it was purchased (i.e.,
the year in which the balancing gas should have been purchased).
The base price in paragraph 7.1 is changed from $2.32 per Mcf to
$1.971 per Mcf.
Paragraph 7.2(a) of Article VII (Price) is deleted and replaced with
the following provision:
8
7.2 (a) Effective January 1 of each year (the "Adjustment
Date"), the base price ($1.971 per Mcf) shall be adjusted as follows:
(A) Each year multiply $1.971 by a fraction, the numerator
of which is the daily average price per barrel of Light
Sweet Crude Oil Futures ("LSCOF") for October and
November deliveries of the year prior to the year for
which the adjusted price is being calculated, and the
denominator of which is $22.36 per barrel.
(B) The average price of LSCOF shall be determined from
prices for "CRUDE OIL, Light Sweet" futures contracts
traded on the New York Mercantile Exchange or its
successor. The daily average price of LSCOF shall be the
sum of the "Settle" prices reported in the Wall Street
Journal or its successor for (i) October contracts for
each day that October contracts are reported as the
contracts for the Current Trading Month, plus (ii)
November contracts for each day that November contracts
are reported as the contracts for the Current Trading
Month divided by the total number of days that such
"Settle" prices are reported. "Current Trading Month"
means the final month in which a contract can be traded.
9
(C) If the information necessary to calculate the daily
average price of LSCOF is no longer publicly reported,
the parties shall negotiate and attempt to agree on
another oil price or prices to substitute for LSCOF and
to make any other changes necessary to create a
successor index.
A new paragraph 7.2(d) shall be added to Article VII (Price):
7.2(d) The total annual purchases from Seller shall be priced as
follows:
(i) The portion of the ACQ shown in Schedule 2 shall be priced
at the base price (Paragraph 7.1) as adjusted under amended Paragraph 7.2(a).
(ii) The portion of the ACQ shown in Schedule 3 shall be
priced as follows:
(A) Effective on the Adjustment Date each year, the price
shall be determined by multiplying $1.55 by a fraction,
the numerator of which is the daily average price per
barrel of Light Sweet Crude Oil Futures ("LSCOF") for
the quarter ending on September 30 of the year prior to
the year for which the adjusted price is being
calculated, and the denominator of which is $18.00 per
barrel.
10
(B) The average price of LSCOF shall be determined from
prices for "CRUDE OIL, Light Sweet" futures contracts
traded on the New York Mercantile Exchange or its
successor. The daily average price of LSCOF shall be the
sum of the "Settle" prices reported in the Wall Street
Journal or its successor for (i) July contracts for each
day that July contracts are reported as the contracts
for the Current Trading Month, plus (ii) August
contracts for each day that August contracts are
reported as the contracts for the Current Trading Month,
plus (iii) September contracts for each day that
September contracts are reported as the contracts for
the Current Trading Month, divided by the total number
of days that such "Settle" prices are reported. "Current
Trading Month" means the final month in which a contract
can be traded.
(C) If the information necessary to calculate the daily
average price of LSCOF is no longer publicly reported,
the parties shall negotiate and attempt to agree on
another oil price or prices to substitute for LSCOF and
to make any other changes necessary to create a
successor index.
11
(iii) During January 1999, any party may give notice that it
wishes to renegotiate the price or volumes of gas shown in Schedule 1 beginning
with the year 2001. If notice is given, the parties will within 30 days begin
exchanging information so that they may in good faith discuss and determine
whether changes in price or volumes are mutually beneficial. No party shall
incur any liability for failure to agree on a new price or volumes. If the
parties do not agree on a new price or volume, this Agreement shall continue
according to its terms.
Article XV (Term) and Article XVIII, Section 18.2 (Government
Regulation), are deleted and replaced with the following provision:
ARTICLE XV: TERM AND REGULATORY APPROVAL
This Agreement cannot be permanently implemented until it has been
approved by the Alaska Public Utilities Commission (APUC). The Agreement shall
be deemed approved when the APUC issues a final order, which is no longer
subject to appeal, finding that approval is in the public interest and that the
costs incurred under the Agreement are fully recoverable in the rates of ENSTAR.
The parties will ask the APUC to approve the Agreement on an interim basis so
that it may be implemented January 1, 1992.
If APUC interim approval is not obtained prior to January 1, 1992,
the parties shall maintain all records necessary to implement the Agreement
effective January 1, 1992 when interim
12
approval is obtained, or, if interim approval is not obtained, when final
approval is obtained.
If the APUC does not approve this Agreement by January 1, 1993,
either party may cancel the Agreement after 30 days written notice to the other
party and to the APUC. If the APUC approves this Agreement subject to material
changes in the terms and conditions which are unacceptable to either party,
either party may petition for reconsideration. The party finding the terms and
conditions unacceptable must, within 5 days of being served with the order,
notify the other party in writing of the terms and conditions which are
unacceptable and state whether it will petition for reconsideration. If a
petition for reconsideration is filed and if the unacceptable terms and
conditions are not cured, the party finding the terms and conditions
unacceptable may cancel the Agreement by giving notice within 30 days following
the last day on which the petition for reconsideration could be granted or
within 30 days following the APUC's order on reconsideration, whichever is
earlier. If a petition for reconsideration is not filed, either party may cancel
the Agreement by giving written notice within 30 days of the service of the
order containing the unacceptable terms and conditions.
This Agreement shall terminate December 31, 2009 (except that Buyer
shall have until December 31, 2010 to take any balancing gas previously paid for
but not taken), or when Buyer has purchased a total of 220 BCF under the Beluga
contract as amended by this Agreement, whichever occurs first.
13
The following provision is added to paragraph 20.5:
Any action to enforce or interpret this Agreement, or otherwise arising
under this Agreement, shall be litigated in the courts of the State of Alaska in
the Third Judicial District at Anchorage.
The following paragraph 20.7 is added:
20.7 This Agreement is the product of the joint effort of the parties and
shall not be construed against either party as drafter. This Agreement, and the
Settlement Agreement dated November 15, 1991, are the entire agreement of the
parties concerning the subject matter of the Agreement and all prior agreements,
understandings, and representations are superseded by this written Agreement. No
amendment to this Agreement is binding until reduced to writing and signed by
the parties.
A comprehensive example of the calculations required by this Agreement is
attached as Exhibit C. Exhibit C shows the rules for rounding.
SHELL WESTERN E&P INC. By:
/s/ L. L. Xxxxx Date: 11-18-91
----------------------------
I certify that on this 18th day of November, 1991 ,there appeared before
me L.L.Xxxxx and he swore to me that he was the Attorney-in-Fact of SHELL
WESTERN E&P INC. and that he is authorized to sign the foregoing instrument on
its behalf, and that he signed the same freely and voluntarily for the purposes
therein mentioned.
/s/ Xxxxxxx Xxxxxxxx
-------------------------------
NOTARY PUBLIC FOR TEXAS
My commission expires: 12-21-92
14
ALASKA PIPELINE COMPANY By:
/s/ Xxxxxxx X.Xxxxxx Date: November 22,1991
----------------------------
I certify that on this 22nd day of November, 1991, there appeared before me
Xxxxxxx X.Xxxxxx and he swore to me that he was the President of ALASKA PIPELINE
COMPANY and that he is authorized to sign the foregoing instrument on its
behalf, and that he signed the same freely and voluntarily for the purposes
therein mentioned.
/s/ Xxxxxx X. Xxxx
-----------------------------
NOTARY PUBLIC FOR ALASKA
My commission expires: June 13,1993
15
RECEIVED
Executive
[SHELL OIL COMPANY LOGO]
MAR 06 1990
One Xxxxx Xxxxx
X. X. Xxx 0000
Xxxxxxx. Xxxxx 00000
February 27, 1990
Certified Mail
Return Receipt Requested
Xx. Xxxxxxx X. Xxxxxx
President
Alaska Pipeline Company
0000 Xxxxxxx Xxxx
P. 0. Xxx 000000
Xxxxxxxxx, Xxxxxx 00000-0000
Dear Xx. Xxxxxx:
SUBJECT: PARTIAL ASSIGNMENT OF GAS PURCHASE CONTRACT
GAS PURCHASE CONTRACT BETWEEN
SHELL WESTERN E&P INC. AND
ALASKA PIPELINE COMPANY
DATED DECEMBER 20, 1982
This letter is written pursuant to a services agreement between Shell Western
E&P Inc. (SWEPI) and Shell Oil Company.
Please find enclosed one (1) copy of a Partial Assignment of the subject Gas
Purchase Contract from SWEPI to Arco Alaska, Inc. (ARCO). This document should
suffice as evidence of ARCO's assumption of an undivided one-third (1/3)
interest in and to all obligations and interests under the subject contract, as
amended.
This letter and enclosed copy of the assignment is being sent to fulfill the
notice requirements of Article XVI, paragraph 16.1 of the contract. Please
accept this notice as binding upon Alaska Pipeline Co. as of March 1, 1990
(although the assignment is dated October 1, 1989). ARCO is hereby notified by
copy of this letter of the effective date.
EXHIBIT B PAGE 1
2
If you have any questions or problems regarding this transaction, please feel
free to contact me at (000) 000-0000 or Xxx Xxxxxxxx at (000) 000-0000.
Yours very truly,
/s/ X. Xxxxxx
-------------------------------
X. Xxxxxx
Regional Manager
Natural Gas Marketing - West
DLC/bdt
Enclosure
cc: Arco Alaska, Inc.
Attn: Xx. Xxxxx Xxxxxxxxxx
Manager Marketing
P. O. Xxx 000000
Xxxxxxxxx, Xxxxxx 00000-0000
EXHIBIT B PAGE 2
PARTIAL ASSIGNMENT OF GAS PURCHASE CONTRACT
This partial assignment is made effective this 1st day of October, 1989,
by and between Shell Western E&P Inc., a Delaware corporation (hereinafter
referred to as "Assignor"), and ARCO Alaska, Inc., a Delaware corporation
(hereinafter referred to as "Assignee");
Recitals
WHEREAS, Shell Oil Company entered into a Gas Purchase Contract dated
December 20, 1982 to sell gas to Alaska Pipeline Company from the Beluga River
Gas Field area, Xxxx Inlet, Alaska (the "Enstar Contract"); and
WHEREAS, Assignor has succeeded to the interest of Shell Oil Company, as
Seller under the Enstar contract; and
WHEREAS, Enstar Corporation has succeeded to the interest of Alaska
Pipeline Company as Buyer under the Enstar Contract; and
WHEREAS, Shell Oil Company entered into a Gas Purchase Agreement ("the
1984 Agreement"), with Atlantic Richfield Company dated July 1, 1984; and
WHEREAS, Assignee has succeeded to the interest of its parent Atlantic
Richfield Company under the 1984 Agreement; and
WHEREAS, under the 1984 Agreement, Assignor purchased from Assignee
portions of the gas sold by Assignor under the Enstar Contract; and
WHEREAS, Assignor and Assignee mutually desire to terminate the 1984
Agreement, and in place of the 1984 Agreement enter into a partial assignment of
Assignor's rights, obligations and interests under the Enstar Contract as
amended, to Assignee;
EXHIBIT B PAGE 3
NOW, THEREFORE, in consideration of Ten Dollars ($10.00) and other good
and valuable consideration, the receipt and sufficiency of which is hereby
acknowledged, Assignor hereby assigns to Assignee an undivided one-third (1/3)
interest in and to Assignor's rights, obligations and interests under the Enstar
Contract as amended, a copy of which Contract and all amendments thereto are
attached hereto and made a part hereof, and Assignee hereby assumes an undivided
one-third (1/3) interest in and to Assignor's rights, obligations and interests
under the Enstar Contract as amended. Assignor and Assignee further agree that
the 1984 Agreement shall be cancelled as of the effective date of this
Assignment; provided, however, that if this Assignment or any part thereof is
void or becomes invalid, the 1984 Agreement, as amended, will be reinstated
according to its terms as of the date of execution of this Assignment.
For the purpose of Article 17 of the Enstar Contract, Assignee's address
shall be:
ARCO Alaska, Inc.
X.X. Xxx 000000
Xxxxxxxxx, Xxxxxx 00000-0000
Attn: Manager Marketing
SHELL WESTERN E&P INC. ARCO ALASKA, INC.
By /s/ L. L. Xxxxx By /s/ H. P. Xxxxxx, Jr.
----------------------- ------------------------
H. P. Xxxxxx, Jr.
Its Attorney-in-Fact Its Senior Vice President
EXHIBIT B PAGE 4
STATE OF TEXAS )
ss.
XXXXXX COUNTRY )
The foregoing instrument was acknowledged before me this 22 day of
September, 1989, by L. L. Xxxxx of SHELL WESTERN E&P INC., a Delaware
corporation, on behalf of the corporation.
/s/ Xxxxxxx Xxxxxxxx
------------------------------
Notary Public in and for Texas
My Commission Expires: 00-00-00
XXXXX XX XXXXXX )
ss.
THIRD JUDICIAL DIST. )
The foregoing instrument was acknowledged before me this 8th day of
February, 1990, by H. P. Xxxxxx, Jr. of ARCO ALASKA, INC., a Delaware
corporation, on behalf of the corporation.
/s/ Xxxxxxx X. Xxxx
------------------------------
Notary Public in and for Alaska
My Commission Expires: 8-24-93
EXHIBIT B PAGE 5
EXHIBIT C
This Exhibit contains examples of the basic calculations necessary to
implement the Agreement. The sample year is 1998. The three basic calculations
illustrated are (1) swing rate, (2) price and (3) the ACQ.
1. Swing Rate - The calculation of swing rate is illustrated in
paragraph 5.4(a). The projections of maximum daily demand on all suppliers
(MMcf), total purchases from all suppliers (Bcf), and Total Market Out Volume
(Bcf) will be made to two decimal places. The calculation of swing rate will be
made as shown and truncated at three decimal places. The result will be rounded
to two decimal places.
To illustrate using the projections in paragraph 5.4(a):
Swing rate 1988 = 11/33 x 235 = 78.33333...
Truncate to 3 decimal places = 78.333
Round to 2 decimal places = 78.33
The projections in paragraph 5.4(a) use an estimated Total Market
Out Volume of 8.00 Bcf, a whole number shown in Schedule 1, to determine ACQ. If
estimated Total Market Out Volume were not a whole number, the ACQ would be
determined by interpolation. Interpolation is illustrated in paragraph 3, ACQ,
below. The calculation of ACQ when Total Market Out Volume is not a whole number
will be truncated at three decimal places and then rounded to two decimal
places.
2. Price - Price calculations will be truncated at 5 decimal places
and rounded to four decimal places. Intermediate calculations (e.g., calculation
of an average price) will be truncated at five decimal places and carried
through the calculation.
To illustrate the calculation of the price for Schedule 3 volumes,
assume that the sum of the prices for LSCOF each day in the calendar quarter
ending September 30, 1997, is $1,266.61 per barrel and that values were reported
for 66 days. The average daily price per barrel for LSCOF is:
$1266.61/66 = 19.1910606...
Truncated to 5 decimal places = 19.19106
EXHIBIT C PAGE 1
The price, effective January 1, 1998, for Schedule 3 volumes is:
$1.55 x (19.19106 / 18) = price for 1998
$1.55 x (1.06617) = price for 1998
Truncated to 5 decimal places = 1.65256
Rounded to 4 decimal places 1.6526 = price 1998
3. ACQ - Shortly after the end of 1998, the Total Market Out Volume
for 1998 will be known and the ACQ for 1998 can be calculated. To calculate the
ACQ for 1998, first state the Total Market Out Volume in Bcf truncated at three
decimal places, then round to two decimal places.
For example, if the Total Market Out Volume ("TMOV") for 1998 is
8,669,836,000 cf:
Stated in Bcf: 8.669,836,000
Truncated to 3 decimal places: 8.669 Bcf
Rounded to 2 decimal places: 8.67 Bcf
The ACQ is calculated by interpolation as follows:
Step 1 (Calculate difference between actual TMOV and next higher TOMV from
Schedule 1):
Next higher TMOV from Sch. 1 = 9.00 Bcf
Less: TMOV 1998 8.67 Bcf
Difference 0.33 Bcf
Step 2:
[(Step 1 calculation) x (ACQ(1998)@TMOV=8 - ACQ(1998)@ TMOV =9)]+
[ACQ(1998)@ TMOV = 9] =ACQ(1998)
Step 2 (substituting values from Schedule 1 and the Step 1 calculation:
[(.33 Bcf) x (11 - 10.5)] + [10.5] = ACQ(1998)
[.165] + [10.5] = 10.6650
2
EXHIBIT C PAGE 2
Step 3:
truncate to 3 decimal places = 10.665
round to 2 decimal places = 10.66 Bcf
ACQ(1998) = 10.66 Bcf
4. Rounding - The first step in rounding is to truncate to one decimal place
greater than the desired number of decimal places. For example, if four decimal
places are desired (as in the price calculation) and the "raw" number is
$19.1910606..., the "raw" number is first reduced to five decimal places by
dropping all digits after the fifth decimal place. The truncated "raw" number is
$19.19106.
The second step in rounding requires inspection of the last digit.
If the last digit is: To round, drop the last digit and:
6, 7, 8, or 9 add 1 to the next to last digit
0, 1, 2, 3, or 4 do nothing to the next to last digit
5 do nothing to the next to last digit if it is even.
If the next to last digit is odd, increase the next
to last digit by 1
Examples:
(a) 25.62047 rounds to 25.6205
(b) 19.13214 rounds to 19.1321
(c) 12.47620 rounds to 12.4762
(d) 11.31965 rounds to 11.3196
(e) 11.31955 rounds to 11.3196
3
SCHEDULE 1
ANNUAL CONTRACT QUANTITY (BCF)*
Total
Market-Out
Volume (BCF) 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009
------------ ----- ----- ----- ----- ----- ----- ----- ----- ----- ----- ----- ----- ----- ----- ----- ----- ----- -----
0 15.44 15.44 15.44 14.44 14.00 15.00 15.00 15.00 15.00 14.00 13.00 13.00 12.00 12.00 12.00 12.00 12.00 12.00
1 14.44 14.44 14.59 13.69 13.50 14.50 14.50 14.50 14.50 13.50 12.50 12.50 11.50 11.50 11.50 11.50 11.50 11.50
2 13.44 13.44 13.74 12.94 13.00 14.00 14.00 14.00 14.00 13.00 12.00 12.00 11.00 11.00 11.00 11.00 11.00 11.00
3 12.44 12.44 12.89 12.19 12.50 13.50 13.50 13.50 13.50 12.50 11.50 11.50 10.50 10.50 10.50 10.50 10.50 10.50
4 11.44 11.44 12.04 11.44 12.00 13.00 13.00 13.00 13.00 12.00 11.00 11.00 10.00 10.00 10.00 10.00 10.00 10.00
5 10.44 10.44 11.19 10.69 11.50 12.50 12.50 12.50 12.50 11.50 10.50 10.50 9.50 9.50 9.50 9.50 9.50 9.50
6 9.44 9.44 10.34 9.94 11.00 12.00 12.00 12.00 12.00 11.00 10.00 10.00 9.00 9.00 9.00 9.00 9.00 9.00
7 8.44 8.44 9.49 9.19 10.50 11.50 11.50 11.50 11.50 10.50 9.50 9.50 8.50 8.50 8.50 8.50 8.50 8.50
8 7.44 7.44 8.64 8.44 10.00 11.00 11.00 11.00 11.00 10.00 9.00 9.00 8.00 8.00 8.00 8.00 8.00 8.00
9 6.44 6.44 7.79 7.69 9.50 10.50 10.50 10.50 10.50 9.50 8.50 8.50 7.50 7.50 7.50 7.50 7.50 7.50
10 5.44 5.44 6.94 6.94 9.00 10.00 10.00 10.00 10.00 9.00 8.00 8.00 7.00 7.00 7.00 7.00 7.00 7.00
11 4.44 4.44 6.09 6.19 8.50 9.50 9.50 9.50 9.50 8.50 7.50 7.50 6.50 6.50 6.50 6.50 6.50 6.50
12 3.44 3.44 5.24 5.44 8.00 9.00 9.00 9.00 9.00 8.00 7.00 7.00 6.00 6.00 6.00 6.00 6.00 6.00
13 2.44 2.44 4.39 4.69 7.50 8.50 8.50 8.50 8.50 7.50 6.50 6.50 5.50 5.50 5.50 5.50 5.50 5.50
14 1.44 1.44 3.54 3.94 7.00 8.00 8.00 8.00 8.00 7.00 6.00 6.00 5.00 5.00 5.00 5.00 5.00 5.00
15 1.00 1.00 2.69 3.19 6.50 7.50 7.50 7.50 7.50 6.50 5.50 5.50 4.50 4.50 4.50 4.50 4.50 4.50
16 1.00 1.00 1.84 2.44 6.00 7.00 7.00 7.00 7.00 6.00 5.00 5.00 4.00 4.00 4.00 4.00 4.00 4.00
17 1.00 1.00 1.00 1.69 5.50 6.50 6.50 6.50 6.50 5.50 4.50 4.50 3.50 3.50 3.50 3.50 3.50 3.50
18 1.00 1.00 1.00 1.00 5.00 6.00 6.00 6.00 6.00 5.00 4.00 4.00 3.00 3.00 3.00 3.00 3.00 3.00
19 1.00 1.00 1.00 1.00 4.50 5.50 5.50 5.50 5.50 4.50 3.50 3.50 2.50 2.50 2.50 2.50 2.50 2.50
20 1.00 1.00 1.00 1.00 4.00 5.00 5.00 5.00 5.00 4.00 3.00 3.00 2.00 2.00 2.00 2.00 2.00 2.00
-------
* The Annual Contract Quantities shown in this Schedule 1 are the total
quantities which Buyer must buy and which SWEPI and ARCO must deliver.
SWEPI shall supply two-thirds of the ACQ as provided in paragraph 5.1 of
this Agreement.
SCHEDULE 2
QUANTITIES OF GAS (BCF) PRICED UNDER PARAGRAPH 7.2 (d)(i)*
Total
Market-Out
Volume (BCF) 1992 1993 1994 1995 1996 1997 1998 1999 2000
------------ ----- ----- ----- ----- ---- ----- ----- ---- ----
0 15.44 15.44 15.44 14.44 9.44 10.44 10.44 5.44 5.44
1 14.44 14.44 14.44 13.44 8.44 9.44 9.44 4.44 4.44
2 13.44 13.44 13.44 12.44 7.44 8.44 8.44 3.44 3.44
3 12.44 12.44 12.44 11.44 6.44 7.44 7.44 2.44 2.44
4 11.44 11.44 11.44 10.44 5.44 6.44 6.44 1.44 1.44
5 10.44 10.44 10.44 9.44 4.44 5.44 5.44 0.44 0.44
6 9.44 9.44 9.44 8.44 3.44 4.44 4.44 0.00 0.00
7 8.44 8.44 8.44 7.44 2.44 3.44 3.44 0.00 0.00
8 7.44 7.44 7.44 6.44 1.44 2.44 2.44 0.00 0.00
9 6.44 6.44 6.44 5.44 0.44 1.44 1.44 0.00 0.00
10 5.44 5.44 5.44 4.44 0.00 0.44 0.44 0.00 0.00
11 4.44 4.44 4.44 3.44 0.00 0.00 0.00 0.00 0.00
12 3.44 3.44 3.44 2.44 0.00 0.00 0.00 0.00 0.00
13 2.44 2.44 2.44 1.44 0.00 0.00 0.00 0.00 0.00
14 1.44 1.44 1.44 0.44 0.00 0.00 0.00 0.00 0.00
15 0.44 0.44 0.44 0.00 0.00 0.00 0.00 0.00 0.00
16 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
17 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
18 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
19 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
20 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
Note:
For the years 2001 through 2009, all quantities are zero.
The zeros are omitted from the table for clarity.
------
* The quantities shown in this Schedule 2 are the total quantities priced
under paragraph 7.2 (d) (i). SWEPI shall supply two-thirds of the
quantities shown.
SCHEDULE 3
QUANTITIES OF GAS (BCF) PRICED UNDER PARAGRAPH 7.2 (d)(ii)*
Total
Market- Out
Volume (BCF) 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009
------------ ---- ---- ---- ---- ---- ---- ---- ----- ----- ----- ----- ----- ----- ----- ------ ----- ----- -----
0 0.00 0.00 0.00 0.00 4.56 4.56 4.56 9.56 9.56 14.00 13.00 13.00 12.00 12.00 12.00 12.00 12.00 12.00
1 0.00 0.00 0.15 0.25 5.06 5.06 5.06 10.06 10.06 13.50 12.50 12.50 11.50 11.50 11.50 11.50 11.50 11.50
2 0.00 0.00 0.30 0.50 5.56 5.56 5.56 10.56 10.56 13.00 12.00 12.00 11.00 11.00 11.00 11.00 11.00 11.00
3 0.00 0.00 0.45 0.75 6.06 6.06 6.06 11.06 11.06 12.50 11.50 11.50 10.50 10.50 10.50 10.50 10.50 10.50
4 0.00 0.00 0.60 1.00 6.56 6.56 6.56 11.56 11.56 12.00 11.00 11.00 10.00 10.00 10.00 10.00 10.00 10.00
5 0.00 0.00 0.75 1.25 7.06 7.06 7.06 12.06 12.06 11.50 10.50 10.50 9.50 9.50 9.50 9.50 9.50 9.50
6 0.00 0.00 0.90 1.50 7.56 7.56 7.56 12.00 12.00 11.00 10.00 10.00 9.00 9.00 9.00 9.00 9.00 9.00
7 0.00 0.00 1.05 1.75 8.06 8.06 8.06 11.50 11.50 10.50 9.50 9.50 8.50 8.50 8.50 8.50 8.50 8.50
8 0.00 0.00 1.20 2.00 8.56 8.56 8.56 11.00 11.00 10.00 9.00 9.00 8.00 8.00 8.00 8.00 8.00 8.00
9 0.00 0.00 1.35 2.25 9.06 9.06 9.06 10.50 10.50 9.50 8.50 8.50 7.50 7.50 7.50 7.50 7.50 7.50
10 0.00 0.00 1.50 2.50 9.00 9.56 9.56 10.00 10.00 9.00 8.00 8.00 7.00 7.00 7.00 7.00 7.00 7.00
11 0.00 0.00 1.65 2.75 8.50 9.50 9.50 9.50 9.50 8.50 7.50 7.50 6.50 6.50 6.50 6.50 6.50 6.50
12 0.00 0.00 1.80 3.00 8.00 9.00 9.00 9.00 9.00 8.00 7.00 7.00 6.00 6.00 6.00 6.00 6.00 6.00
13 0.00 0.00 1.95 3.25 7.50 8.50 8.50 8.50 8.50 7.50 6.50 6.50 5.50 5.50 5.50 5.50 5.50 5.50
14 0.00 0.00 2.10 3.50 7.00 7.50 8.00 8.00 8.00 7.00 6.00 6.00 5.00 5.00 5.00 5.00 5.00 5.00
15 0.56 0.56 2.25 3.19 6.50 7.50 7.50 7.50 7.50 6.50 5.50 5.50 4.50 4.50 4.50 4.50 4.50 4.50
16 1.00 1.00 1.84 2.44 6.00 7.00 7.00 7.00 7.00 6.00 5.00 5.00 4.00 4.00 4.00 4.00 4.00 4.00
17 1.00 1.00 1.00 1.69 5.50 6.50 6.50 6.50 6.50 5.50 4.50 4.5O 3.50 3.50 3.50 3.50 3.50 3.50
18 1.00 1.00 1.00 1.00 5.00 6.00 6.00 6.00 6.00 5.00 4.00 4.00 3.00 3.00 3.00 3.00 3.00 3.00
19 1.00 1.00 1.00 1.00 4.50 5.50 5.50 5.50 5.50 4.50 3.50 3.50 2.50 2.50 2.50 2.50 2.50 2.50
20 1.00 1.00 1.00 1.00 4.00 5.00 5.00 5.00 5.00 4.00 3.00 3.00 2.00 2.00 2.00 2.00 2.00 2.00
-----
* The quantities shown in this Schedule 3 are the total quantities priced
under paragraph 7.2(d)(ii). SWEPI shall supply two-thirds of the
quantities shown.
[SHELL OIL COMPANY LOGO]
November 15, 0000
Xxx Xxxxx Xxxxx
X.X. Xxx 0000
Xxxxxxx, Xxxxx 00000
Alaska Pipeline Company
ENSTAR Natural Gas Company
A Division of Seagull Energy Corporation
0000 Xxxxxxx Xxxx
X.X. Xxx 000000
Xxxxxxxxx, Xxxxxx 00000-0000
Attention: Xx. Xxxxxxx X. Xxxxxx
Gentlemen:
This letter is written pursuant to the Shell Oil Company (SOC)/Shell
Western E&P Inc. (SWEPI) Services Agreement.
This is to confirm our understanding that ENSTAR Natural Gas Company (ENSTAR)
and Alaska Pipeline Company (APC) are willing to transport gas for SWEPI under
the following conditions:
Subject to the other provisions of this letter agreement (in particular the
negotiation of a transportation agreement as set forth below), if by November
15, 1993, SWEPI contracts to sell natural gas to one or more customers on the
Kenai Peninsula, APC and ENSTAR agree to make such physical improvements to
their transmission and distribution systems as are necessary to enable them to
transport up to eighty million cubic feet of natural gas per day from any
existing receipt point or points on the northwest side of Xxxx Inlet to any
existing delivery point(s) on APC's transmission system on the Kenai Peninsula.
APC, ENSTAR and SWEPI acknowledge that SWEPI will seek to ship gas on a "forward
haul" basis from such receipt point(s) through Anchorage to such customers on
the Kenai Peninsula. APC, ENSTAR and SWEPI further recognize that such
transportation may at times be accomplished by backhaul, exchange, or forward
haul, or some combination thereof. APC and ENSTAR agree that the physical
improvements to be made to their respective systems will be capable of
transporting gas quantities (with exact quantities set forth as part of the
transportation agreement mentioned below) on a forward haul basis during those
times when APC and ENSTAR are unable or unwilling to use a backhaul or exchange
arrangement (in part or in whole).
At SWEPI's request, APC and ENSTAR will enter into a gas transportation
agreement with SWEPI, including rates, and will diligently seek all approvals
necessary to construct and operate the pipeline improvements. Upon obtaining all
necessary approvals, including the approval of the transportation agreement by
the Alaska Public Utilities Commission (APUC), APC and ENSTAR will promptly
construct the pipeline improvements and begin to transport gas for SWEPI. SWEPI
recognizes that the ability of APC and ENSTAR to transport gas for SWEPI is
subject to APC's and ENSTAR's primary obligation to provide service to their
utility customers, and that transportation service to SWEPI may, from time to
time, be reduced or curtailed so that APC and ENSTAR may meet their superior
obligations to other customers. SWEPI also recognizes that the transportation
agreement is at all times subject to the jurisdiction of the APUC.
If APC and ENSTAR are in agreement with the foregoing, please so indicate by
signing in the appropriate spaces provided below.
Very truly yours,
/s/ X. Xxxxxx
-------------------------------------------
X. Xxxxxx
Regional Marketing Manager
Natural Gas Marketing
AGREED AND ACCEPTED AGREED AND ACCEPTED
FOR ALASKA PIPELINE COMPANY FOR ENSTAR NATURAL GAS COMPANY
By: /s/ X.X.Xxxxxx By: /s/ X.X.Xxxxxx
------------------------------- ---------------------------------
Title: President Title: President
AGREED AND ACCEPTED
FOR SHELL WESTERN E&P INC
By: /s/ L. L. Xxxxx
--------------------------------
Title: ATTORNEY-IN-FACT
2
