PARTY A (Seller)
ConocoPhillips Company and ConocoPhillips Alaska, Inc |
PARTY NAME |
PARTY B (Buyer)
Chugach Electric Association, Inc. |
||||||
700 G. St.
Anchorage, AK 99510 |
ADDRESS |
5601 Electron Drive
Anchorage, AK 99519 |
||||||
BUSINESS WEBSITE |
||||||||
CEA 2009-01 |
CONTRACT NUMBER |
_______ |
||||||
00-136-8265 |
D-U-N-S® NUMBER |
_______ |
||||||
x US FEDERAL: 73-0400345 (COP)
x US FEDERAL: 94-2700433 (CPAI) |
TAX ID NUMBERS |
x US FEDERAL: _______
o OTHER: |
||||||
JURISDICTION OF ORGANIZATION |
||||||||
x Corporation
o Limited Partnership
o LLP |
o LLC
o Partnership
o Other: __________ |
COMPANY TYPE |
x Corporation
o Limited Partnership
o LLP |
o LLC
o Partnership
o Other __________ |
||||
GUARANTOR
(IF APPLICABLE) |
||||||||
CONTACT INFORMATION |
||||||||
ATTN: Cook Inlet Gas Marketing |
ATTN: Suzanne Gibson,
Director, Energy Resources |
|||||||
TEL#: (907) 265-1605 |
FAX#: (918) 662-6889 |
§ COMMERCIAL |
TEL#: (907) 762-4577 |
FAX# (907) 762-4688 | ||||
EMAIL: Von.L.Huthins@ConocoPhillips.com |
EMAIL: Suzanne_Gibson@chugachelectric.com |
|||||||
ATTN: Cook Inlet Gas Control |
ATTN: Burke Wick, Director, System Control |
|||||||
TEL#: (907) 263-4704 |
FAX#: (918) 662-6895 |
§ SCHEDULING |
TEL#: (907) 762-4779 |
|||||
EMAIL: Brandy.Ostrinski@ConocoPhillips.com |
EMAIL: Burke_Wick@chugachelectric.com |
|||||||
ATTN: ____________ |
§ CONTRACT |
ATTN: General Counsel |
||||||
TEL#: ____________ |
FAX#: ____________ |
AND LEGAL |
TEL#: ___________ |
FAX#: ___________ | ||||
EMAIL: |
NOTICES |
EMAIL: |
||||||
ATTN: ____________ |
ATTN: ___________ |
|||||||
TEL#: ____________ |
FAX#: ____________ |
§ CREDIT |
TEL#: ___________ |
FAX#: ___________ |
||||
EMAIL: |
EMAIL: |
|||||||
ATTN: Cook Inlet Gas Control |
§ TRANSACTION |
ATTN: Suzanne Gibson,
Director, Energy Resources |
||||||
TEL#: (907) 263-4704 |
FAX#: (918) 662-6895 |
CONFIRMATIONS |
TEL#: (907) 762-4577 |
|||||
EMAIL: Brandy.Ostrinski@ConocoPhillips.com |
EMAIL: Suzanne_Gibson@chugachelectric.com |
|||||||
ACCOUNTING INFORMATION |
||||||||
ATTN: Revenue Alaska |
§ INVOICES |
ATTN: Chugach Electric Association, Inc. |
||||||
TEL#: 918-661-1649 |
FAX#: 918-6625453 |
§ PAYMENTS |
TEL#: 907-762-4369 |
|||||
EMAIL: Toni.M.Glass@conocophillips.com |
§ SETTLEMENTS |
EMAIL: Marina_Mccoy-Casey@chugachelectric.com |
||||||
BANK: Bank One |
WIRE TRANSFER |
BANK: FNB of A |
||||||
ABA: 071000013 |
ACCT: 643625114 |
NUMBERS |
ABA: 125200060 |
ACCT: 1104751 | ||||
OTHER DETAILS: |
(IF APPLICABLE) |
OTHER DETAILS: |
||||||
BANK: Bank One |
BANK: FNB of A |
|||||||
ABA: 071000013 |
ACCT: 643625114 |
ACH NUMBERS |
ABA: 125200060 |
ACCT: 1104751 | ||||
OTHER DETAILS: |
(IF APPLICABLE) |
OTHER DETAILS: |
||||||
ATTN: __________________
ADDRESS: ______________ |
CHECKS
(IF APPLICABLE) |
ATTN: Marina McCoy-Casey
ADDRESS: 5601 Electron Drive Anchorage, AK 99519 |
Copyright © 2006 North American Energy Standards Board, Inc. |
NAESB Standard 6.3.1 |
All Rights Reserved |
September 5, 2006 |
Section 1.2
Transaction Procedure |
o Oral (default)
OR
x Written |
Section 10.2
Additional
Events of |
x No Additional Events of Default (default)
o Indebtedness Cross Default | |
Section 2.7
Confirm Deadline |
o 2 Business Days after receipt (default)
OR
x 10 Business Days after receipt |
Default |
o Party A: __________________
o Party B: __________________
o Transactional Cross Default
Specified Transactions:
| |
Section 2.8
Confirming Party |
x Seller (default)
OR
o Buyer
OR
o |
|||
Section 3.2
Performance Obligation |
o Cover Standard (default)
OR
o Spot Price Standard
OR
x Special Provisions Section 16.2
|
Section 10.3.1
Early Termination Damages |
x Early Termination Damages Apply (default)
OR
o Early Termination Damages Do Not Apply | |
Note: The following Spot Price Publication applies to both of the immediately preceding. |
Section 10.3.2 |
o Other Agreement Setoffs Apply (default) | ||
Section 2.31
Spot Price
Publication |
x Gas Daily Midpoint (default)
OR
o |
Other
Agreement
Setoffs |
o Bilateral (default)
o Triangular | |
Section 6
Taxes |
o Buyer Pays At and After Delivery Point (default)
OR
x Seller Pays Before and At Delivery Point |
OR
x Other Agreement Setoffs Do Not Apply | ||
Section 7.2
Payment Date
|
x 25th Day of Month following Month of
delivery (default)
OR
o Day of Month following Month of delivery |
Section 15.5
Choice Of Law |
Alaska | |
Section 7.2
Method of Payment |
x Wire transfer (default)
o Automated Clearinghouse Credit (ACH)
o Check |
Section 15.10
Confidentiality |
o Confidentiality applies (default)
OR
x Confidentiality does not apply | |
Section 7.7
Netting |
x Netting applies (default)
OR
o Netting does not apply |
x Special Provisions Number of sheets attached: 10 pages
o Addendum(s): |
ConocoPhillips Company |
PARTY NAME |
Chugach Electric Association, Inc. | ||
By |
/s/ J.L. Bowles |
SIGNATURE |
By |
/s/ Bradley Evans |
J. L. Bowles |
PRINTED NAME |
Bradley Evans | ||
Vice President |
TITLE |
CEO | ||
ConocoPhillips Alaska Inc. |
PARTY NAME |
|||
By: |
/s/ J. L. Bowles |
SIGNATURE |
||
J. L. Bowles |
PRINTED NAME |
|||
President |
TITLE |
Copyright © 2006 North American Energy Standards Board, Inc. |
NAESB Standard 6.3.1 |
All Rights Reserved |
September 5, 2006 |
Copyright © 2006 North American Energy Standards Board, Inc. |
NAESB Standard 6.3.1 |
All Rights Reserved |
September 5, 2006 |
Copyright © 2006 North American Energy Standards Board, Inc. |
NAESB Standard 6.3.1 |
All Rights Reserved |
September 5, 2006 |
Copyright © 2006 North American Energy Standards Board, Inc. |
NAESB Standard 6.3.1 |
All Rights Reserved |
September 5, 2006 |
Copyright © 2006 North American Energy Standards Board, Inc. |
NAESB Standard 6.3.1 |
All Rights Reserved |
September 5, 2006 |
Copyright © 2006 North American Energy Standards Board, Inc. |
NAESB Standard 6.3.1 |
All Rights Reserved |
September 5, 2006 |
Copyright © 2006 North American Energy Standards Board, Inc. |
NAESB Standard 6.3.1 |
All Rights Reserved |
September 5, 2006 |
Copyright © 2006 North American Energy Standards Board, Inc. |
NAESB Standard 6.3.1 |
All Rights Reserved |
September 5, 2006 |
Copyright © 2006 North American Energy Standards Board, Inc. |
NAESB Standard 6.3.1 |
All Rights Reserved |
September 5, 2006 |
Copyright © 2006 North American Energy Standards Board, Inc. |
NAESB Standard 6.3.1 |
All Rights Reserved |
September 5, 2006 |
DISCLAIMER: The purposes of this Contract are to facilitate trade, avoid misunderstandings and make more definite the terms of contracts of purchase and sale of natural gas. Further, NAESB does not mandate the use of this Contract by any party. NAESB DISCLAIMS AND EXCLUDES, AND ANY USER OF THIS CONTRACT ACKNOWLEDGES AND AGREES TO NAESB'S DISCLAIMER OF, ANY AND ALL WARRANTIES, CONDITIONS OR REPRESENTATIONS, EXPRESS OR IMPLIED, ORAL OR WRITTEN, WITH RESPECT TO THIS CONTRACT OR ANY PART THEREOF, INCLUDING ANY AND ALL IMPLIED WARRANTIES OR CONDITIONS OF TITLE, NON-INFRINGEMENT, MERCHANTABILITY, OR FITNESS OR SUITABILITY FOR ANY PARTICULAR PURPOSE (WHETHER OR NOT NAESB KNOWS, HAS REASON TO KNOW, HAS BEEN ADVISED, OR IS OTHERWISE IN FACT AWARE OF ANY SUCH PURPOSE), WHETHER ALLEGED TO ARISE BY LAW, BY REASON OF CUSTOM OR USAGE IN THE TRADE, OR BY COURSE OF DEALING. EACH USER OF THIS CONTRACT ALSO AGREES THAT UNDER NO CIRCUMSTANCES WILL NAESB BE LIABLE FOR ANY DIRECT, SPECIAL, INCIDENTAL, EXEMPLARY, PUNITIVE OR CONSEQUENTIAL DAMAGES ARISING OUT OF ANY USE OF THIS CONTRACT. |
Copyright © 2006 North American Energy Standards Board, Inc. |
NAESB Standard 6.3.1 |
All Rights Reserved |
September 5, 2006 |
TRANSACTION CONFIRMATION |
EXHIBIT A | |
FOR IMMEDIATE DELIVERY |
Letterhead/Logo
|
Date: ____________, ____
Transaction Confirmation #: _________
| ||
This Transaction Confirmation is subject to the Base Contract between Seller and Buyer dated May 12, 2009. The terms of this Transaction Confirmation are binding unless disputed in writing within 2 Business Days of receipt unless otherwise specified in the Base Contract. | |||
SELLER:
ConocoPhillips Company/ ConocoPhillips Alaska, Inc.
______________________________________________
______________________________________________
Attn: Von Hutchins
Phone: (907) 265-1605
Fax: (918) 662-6889
Base Contract No. CEA 2009-01
Transporter: ____________________________________
Transporter Contract Number: _______________________ |
BUYER:
Chugach Electric Association, Inc.
_______________________________________________
_______________________________________________
Attn: _ Suzanne Gibson,
Director, Energy Resources_______
Phone: _(907) 762-4577
Fax: _(907) 762-4816
Base Contract No. ________________________________
Transporter: _____________________________________
Transporter Contract Number: _______________________
| ||
Contract Price: $ /Mcf or | |||
Delivery Period: Begin: , End: ,
|
Performance Obligation and Contract Quantity: (Select One)
| ||
Firm (Fixed Quantity):
MMcf/day
o EFP
|
Firm (Variable Quantity):
0 MMcf/day Minimum
MMcf/day Maximum
subject to Section 4.2. at election of
o Buyer or o Seller |
Interruptible:
Up to MMcf/day
|
Delivery Point(s): See Section 16 of Base Agreement for conditions regarding delivery
(If a pooling point is used, list a specific geographic and pipeline location): | |||
Special Conditions:
| |||
Seller: __________________________________________
By: ____________________________________________
Title: ___________________________________________
Date: __________________________________________
|
Buyer: __________________________________________
By: ____________________________________________
Title: ___________________________________________
Date: __________________________________________ |
Copyright © 2006 North American Energy Standards Board, Inc. |
NAESB Standard 6.3.1 |
All Rights Reserved |
September 5, 2006 |
|
· |
2.36. “Firm Gas Supply Tranche” shall mean the total volume of Gas equal to 100% of the Gas volumes utilized at the Bernice Lake Power Plant, the Nikiski Power Plant and the International Power Plant, 40% of the Gas volumes utilized at the Beluga Power Plant, and 40% of the Buyer’s share of the Southcentral Power Plant excluding any Gas utilized to generate economy energy sales at any or
all of those facilities, up to a limit of 50 MMcf/day measured on an hourly basis at the Delivery Points which Buyer uses to serve Buyer’s retail customers and contracts with Matanuska Electric Association, Homer Electric Association and City of Seward. |
|
· |
2.37. “Delivery Start Date” shall mean, at Buyer's election, either January 1, 2010, or the date that Marathon’s current volumetric obligation to Buyer is exhausted, which is currently expected to occur sometime during the 2nd or 3rd quarter of
2010. |
|
· |
2.38 “Firm Fixed Quantity” shall mean the base portion of the Firm Gas Supply Tranche, measured on an hourly basis, that is demarcated based on the annually derived methodology described in Attachment 1. |
|
· |
2.39 “Firm Variable Quantity” shall mean the secondary portion of the Firm Gas Supply Tranche after subtracting the Firm Fixed Quantity at any point in time. There is no minimum take requirement for the Firm Variable Quantity, but Buyer shall not purchase any portion of the Firm Variable Quantity from another supplier absent a reduction in the Firm Variable Quantity in accordance with the procedure
described in this section or Seller's failure to deliver such Gas volumes. During periods in which Seller is still authorized to export LNG and the Nikiski LNG Plant is actively exporting LNG, Buyer may, with 120 days' advance Notice (or on shorter notice if the Parties so agree), reduce the Firm Variable Quantity to as low as zero, or subsequently reinstate any portion of such reduced quantity. If Seller ceases to be authorized to export LNG or the Nikiski LNG Plant is no longer actively
exporting LNG, as described in Section 16.3(g), during the term of the Base Contract, then Buyer must, within 30 days' Notice from Seller, make a one-time election on a fixed maximum level for Firm Fixed Quantity plus Firm Variable Quantity (not to exceed 50 MMcf/day), which maximum will remain in effect until December 31, 2013. |
|
· |
2.40 “Interruptible Gas Supply” shall have the meaning set forth in Section 16.3(f). |
|
· |
Section 1.4 is deleted. |
|
· |
Section 2.31 is deleted. |
|
· |
Section 2.34 is deleted. |
|
· |
Section 3.2 is deleted and replaced as follows: |
|
· |
Section 11.3 items (iv) and (v) are to be moved, in their entirety, into Section 11.2, and added into the first sentence as items (vi) and (vii), but, in each case, with the deletion of the phrase “except, in either case, as provided in Section 11.2”. |
|
· |
A new item (viii) is inserted into the first sentence in Section 11.2, as follows: “(viii) volcanic eruptions, which necessitate the preventative shutdown of equipment or machinery.” |
|
· |
Section 12, first phrase, is deleted and replaced as follows: “This Contract will terminate on December 31, 2016.” |
|
· |
The following new paragraph shall be added as Section 15.13: |
Copyright © 2006 North American Energy Standards Board, Inc. |
NAESB Standard 6.3.1 |
All Rights Reserved |
September 5, 2006 |
16.3. |
Subject to the terms and conditions of this Contract, Seller shall deliver and sell, and Buyer shall receive and pay for the Contract Quantity composed of the Firm Gas Supply Tranche and Interruptible Gas Supply, as described and limited below. |
|
a) |
Transaction Confirmations for Firm Fixed Quantities, Firm Variable Quantities, and Interruptible Gas Supply will be established and updated as necessary, but not less than on a quarterly basis, starting at the Delivery Start Date and continuing until December 31, 2016, according to the principles specified within this Special Provisions Addendum, unless mutually agreed otherwise. |
|
b) |
New Transaction Confirmations will be agreed per the procedures outlined in Section 1.2 at such times that delivery circumstances necessitate such action. At a minimum, changes in price will require new Transaction Confirmations on a quarterly basis. Additional changes that are currently contemplated include but are not limited to annual changes to the Firm Fixed Quantity and the maximum
Firm Variable Quantity. If Buyer exercises the right described in Section 16.1 above to increase or decrease the maximum Firm Variable Quantity, then a new Transaction Confirmation will also be required. |
|
c) |
The derivation of the annual determination of the maximum Firm Fixed Quantity is set forth in Attachment 1. |
|
d) |
The methodologies to be used to determine prices for Firm Fixed Quantities and Firm Variable Quantities in the Transaction Confirmations are outlined in Attachment 2. |
|
e) |
The details governing Delivery Points and daily nomination procedures are outlined in Sections 16.4 and 16.5. |
|
f) |
“Interruptible Gas Supply” shall mean that quantity of Gas required by Buyer, and provided by Seller, in excess of the Firm Gas Supply Tranche pursuant to an interruptible Transaction Confirmation under the following conditions. To the extent Buyer has gas supply needs that are in excess of the then applicable Firm Variable Quantity, Seller shall use commercially reasonable efforts to make such
interruptible volumes available to Buyer from Seller’s field production. Seller agrees that such commercially reasonable efforts will include curtailing the delivery of Gas to the Nikiski LNG Plant to the extent necessary to meet these unmet needs of Buyer provided, however, that Seller will not be obligated to curtail deliveries to the Nikiski LNG Plant if the curtailment will result in any material operational difficulties or technical harm to the Nikiski LNG Plant. During periods
in which Seller is still authorized to export LNG and is actively exporting LNG, the price for these interruptible volumes of Gas shall be the Firm Variable Price set forth in Attachment 2; at all other times the price will be negotiated at the time the Interruptible Transaction Confirmation is made and shall not exceed two hundred percent (200%) of the Firm Fixed Price set forth in Attachment 2. |
|
g) |
For purposes of this Section 16.3 and the definition of Firm Variable Quantity, “Nikiski LNG Plant is actively exporting LNG” shall mean that Seller has not provided Buyer with 90 days written Notice that the Nikiski LNG Plant is being shutdown for the remainder of the term of this Contract and that the US Department of Energy has been informed
of such shutdown. |
16.4. |
Buyer will nominate to Seller in writing via electronic means at least 12 hours in advance of the next calendar day the hourly volumes of Gas by power plant location that Buyer desires for that entire calendar day. Subject to Section 16.5, Seller retains the right to select the Delivery Point(s), but Seller shall use commercially reasonable efforts to deliver Gas to Buyer at the Delivery Points in the order
of preference listed in Attachment 3 to meet the Buyer’s nomination request. Seller's nomination confirmation or alternative response shall be sent to Buyer in writing via electronic means at least 9 hours in advance of the relevant calendar day. Should the timing of the nominations in this Section 16.4 no longer meet the timing requirements of Transporter(s), then Buyer and Seller will work together to adjust the nomination timing. |
16.5. |
It is Buyer’s responsibility to secure the necessary transportation for the Gas downstream of the Delivery Point(s). The costs associated with transporting nominated Gas downstream of the Delivery Point(s) into regulated pipelines shall be borne by the Buyer. In order to minimize Buyer’s transportation costs, Buyer and Seller commit to do the following: |
|
a) |
Buyer and Seller will meet periodically to forecast Firm Gas Supply Tranche requirements by facility and jointly formulate plans for transporting the required volumes of Gas in a cost effective manner. |
|
b) |
Buyer and Seller shall within 90 days following the execution of this Contract work cooperatively, reasonably, and in good faith to: (1) determine if: (a) a direct connection from the Nikiski LNG Plant to the Nikiski power plant can be established, and (b) a capacity expansion from the Beluga River Unit (BRU) to the Beluga Power Plant is warranted, and (2) work to secure gas exchange opportunities that will
reduce the cost of transportation to be borne by the Buyer. Seller shall have no obligation to expend funds in connection with these items. |
|
c) |
Seller shall make available to Buyer for delivery from BRU to the Beluga Power Plant the quantity of BRU Gas determined by the following equation: BRU gas takes by BRU owners other than Seller times 50%, less any reduction in Seller's BRU gas take rights resulting from Seller's overlift position and less quantities delivered to Buyer under the agreement listed as (2) in Attachment 4, up to 40% of the Gas requirements
at the Beluga Power Plant, excluding any Gas utilized to generate economy energy sales. Seller shall have the option of transporting Gas for delivery at Seller’s expense to the Beluga Power Plant to satisfy its obligations in the preceding sentence unless such option adversely affects Buyer’s transportation options or operation of the Beluga Power Plant in Buyer’s sole discretion. In addition, any Gas production from the BRU to be sold by Seller during the term of this
Contract will first be made available to Buyer under this Contract. For purposes of interpretation of this Section 16.5 (c), if Seller’s working interest in BRU changes, then the percentage in the equation in the first sentence shall be modified to maintain Buyer’s quantity of BRU Gas from the Seller’s working interest share of BRU field production. |
Copyright © 2006 North American Energy Standards Board, Inc. |
NAESB Standard 6.3.1 |
All Rights Reserved |
September 5, 2006 |
|
d) |
Seller shall give Buyer first priority for all Gas delivered through the Nikiski LNG Plant Connection (ENSTAR/APC Metering Station K277). |
16.6. |
To verify Seller's compliance with its obligations under 16.5(c), an independent third party, selected by Buyer and reasonably acceptable to Seller, may perform an audit in accordance with Section 7.6, subject to reasonable confidentiality terms, and report the audit findings to Buyer and Seller. To verify the Gas requirements at the Beluga Power Plant, excluding any Gas utilized to generate economy energy
sales, for purposes of Section 16.5(c), and to verify the Gas quantities utilized at the power plants to be served by the Firm Gas Supply Tranche, excluding any Gas utilized to generate economy energy sales, an independent third party, selected by Seller and reasonably acceptable to Buyer, may perform an audit in accordance with Section 7.6, subject to reasonable confidentiality terms, and report the audit findings to Buyer and Seller. |
16.7 |
Seller will be responsible for the payment of all royalties, and any fees, penalties and assessments attributable to the royalties, on Gas delivered under this Contract provided that the Alaska Department of Natural Resources agrees that the price paid under this Contract is the value of the State of Alaska's royalty share of production under AS 38.05.180 (aa) (with the exception of production covered by a royalty settlement
agreement). The parties will work together to obtain acceptance by the Alaska Department of Natural Resources of the price paid under this Contract as the value of the State of Alaska's royalty share of production under AS 38.05.180(aa) (with the exception of production covered by a royalty settlement agreement) within 90 days of the effective date of this Contract. If the parties are not successful in obtaining such acceptance, Buyer will reimburse Seller for any royalty payments which
exceed the royalty payments that would be payable, for Gas not covered by a royalty settlement agreement, if the price paid under this Contract was equal to the value of the State of Alaska's royalty share of such production as determined by the Alaska Department of Natural Resources. |
16.9 |
Reserves Certification |
Copyright © 2006 North American Energy Standards Board, Inc. |
NAESB Standard 6.3.1 |
All Rights Reserved |
September 5, 2006 |
16.10 |
Additional Firm Fixed Quantities |
|
a) |
Calendar year: 2014 - 25 MMscf/day, 2015 – 17 MMscf/day, 2016 – 8 MMscf/day. |
|
b) |
All volumes delivered under these Transaction Confirmations shall be deemed to be the first volumes received by Buyer. |
|
c) |
Pricing shall be in accordance with Attachment 2. |
|
d) |
All other provisions of this Contract apply. |
16.11 |
New Taxes |
16.12 |
Arbitration |
|
16.13 |
Court |
Copyright © 2006 North American Energy Standards Board, Inc. |
NAESB Standard 6.3.1 |
All Rights Reserved |
September 5, 2006 |
2008 Gas Volumes |
|||||||||||
Total Daily Volumes Sorted Lowest to Highest |
Average of lowest 30 days: |
31,755 |
|||||||||
Actual
Day |
Total
Volumes |
Beluga |
Nikiski |
Bernice
Lake |
IGT |
40% of
Beluga |
100% of
Nikiski |
100% of
Bernice |
100% of
IGT |
Total COP
Tranche |
Days |
181 |
53,201 |
50,949 |
0 |
2,251 |
0 |
20,380 |
0 |
2,251 |
0 |
22,631 |
1 |
118 |
58,402 |
46,640 |
11,601 |
161 |
0 |
18,656 |
11,601 |
161 |
0 |
30,418 |
2 |
96 |
59,417 |
48,078 |
11,339 |
0 |
0 |
19,231 |
11,339 |
0 |
0 |
30,570 |
3 |
104 |
59,428 |
47,558 |
11,871 |
0 |
0 |
19,023 |
11,871 |
0 |
0 |
30,894 |
4 |
103 |
59,736 |
47,551 |
12,045 |
140 |
0 |
19,020 |
12,045 |
140 |
0 |
31,205 |
5 |
180 |
59,746 |
53,575 |
2,316 |
3,856 |
0 |
21,430 |
2,316 |
3,856 |
0 |
27,601 |
6 |
168 |
59,837 |
43,556 |
11,223 |
5,058 |
0 |
17,422 |
11,223 |
5,058 |
0 |
33,703 |
7 |
105 |
60,198 |
48,040 |
11,987 |
172 |
0 |
19,216 |
11,987 |
172 |
0 |
31,374 |
8 |
97 |
60,573 |
49,352 |
10,813 |
408 |
0 |
19,741 |
10,813 |
408 |
0 |
30,962 |
9 |
131 |
60,620 |
46,997 |
11,424 |
2,199 |
0 |
18,799 |
11,424 |
2,199 |
0 |
32,422 |
10 |
169 |
60,857 |
41,737 |
11,214 |
6,939 |
967 |
16,695 |
11,214 |
6,939 |
967 |
35,815 |
11 |
186 |
60,909 |
53,101 |
2,272 |
5,536 |
0 |
21,241 |
2,272 |
5,536 |
0 |
29,049 |
12 |
106 |
61,038 |
48,969 |
12,069 |
0 |
0 |
19,588 |
12,069 |
0 |
0 |
31,656 |
13 |
119 |
61,071 |
49,459 |
11,613 |
0 |
0 |
19,783 |
11,613 |
0 |
0 |
31,396 |
14 |
132 |
61,198 |
46,841 |
11,424 |
2,932 |
0 |
18,736 |
11,424 |
2,932 |
0 |
33,093 |
15 |
102 |
61,252 |
49,207 |
12,045 |
0 |
0 |
19,683 |
12,045 |
0 |
0 |
31,728 |
16 |
159 |
61,704 |
48,870 |
11,223 |
1,610 |
0 |
19,548 |
11,223 |
1,610 |
0 |
32,382 |
17 |
90 |
61,843 |
49,887 |
11,957 |
0 |
0 |
19,955 |
11,957 |
0 |
0 |
31,911 |
18 |
117 |
61,863 |
50,479 |
11,385 |
0 |
0 |
20,191 |
11,385 |
0 |
0 |
31,576 |
19 |
120 |
61,895 |
50,282 |
11,613 |
0 |
0 |
20,113 |
11,613 |
0 |
0 |
31,725 |
20 |
110 |
61,973 |
50,556 |
11,418 |
0 |
0 |
20,222 |
11,418 |
0 |
0 |
31,640 |
21 |
166 |
63,001 |
50,396 |
11,223 |
1,383 |
0 |
20,158 |
11,223 |
1,383 |
0 |
32,764 |
22 |
174 |
63,177 |
50,350 |
10,935 |
1,891 |
0 |
20,140 |
10,935 |
1,891 |
0 |
32,967 |
23 |
141 |
63,266 |
47,210 |
11,333 |
4,723 |
0 |
18,884 |
11,333 |
4,723 |
0 |
34,940 |
24 |
171 |
63,272 |
49,354 |
10,920 |
2,999 |
0 |
19,741 |
10,920 |
2,999 |
0 |
33,660 |
25 |
111 |
63,308 |
51,500 |
11,371 |
438 |
0 |
20,600 |
11,371 |
438 |
0 |
32,409 |
26 |
107 |
63,475 |
49,851 |
12,049 |
1,576 |
0 |
19,940 |
12,049 |
1,576 |
0 |
33,565 |
27 |
101 |
63,578 |
51,189 |
12,045 |
344 |
0 |
20,476 |
12,045 |
344 |
0 |
32,865 |
28 |
114 |
63,578 |
52,200 |
11,379 |
0 |
0 |
20,880 |
11,379 |
0 |
0 |
32,258 |
29 |
162 |
63,743 |
50,454 |
11,223 |
2,066 |
0 |
20,182 |
11,223 |
2,066 |
0 |
33,471 |
30 |
Copyright © 2006 North American Energy Standards Board, Inc. |
NAESB Standard 6.3.1 |
All Rights Reserved |
September 5, 2006 |
El Paso, Permian Basin |
$ | 3.500 | ||
Waha |
$ | 3.585 | ||
ANR, Okla. |
$ | 3.485 | ||
Columbia Gulf, La. |
$ | 4.760 | ||
Agua Dulce Hub |
$ | 4.245 | ||
Total |
$ | 19.575 | ||
divide by 5 |
5 | |||
Daily Average |
$ | 3.915 |
April |
$ | 6.559 | ||
May |
$ | 6.542 | ||
June |
$ | 5.999 | ||
Total |
$ | 19.100 | ||
divide by 3 |
3 | |||
Monthly Average |
$ | 6.367 | ||
Multiply by 95% |
0.95 | |||
Firm Variable Price for 3rd Quarter |
$ | 6.048 |
Platt’s National Average Price |
$ | 4.570 | ||
multiply by 120% |
1.20 | |||
Daily Price |
$ | 5.484 |
Copyright © 2006 North American Energy Standards Board, Inc. |
NAESB Standard 6.3.1 |
All Rights Reserved |
September 5, 2006 |
Copyright © 2006 North American Energy Standards Board, Inc. |
NAESB Standard 6.3.1 |
All Rights Reserved |
September 5, 2006 |
|
1. |
The inlet to Buyer’s facilities connected to the Beluga Unit Area Connection (to CEA off of the Beluga River field) – At the downstream flange of Beluga River Unit’s meter at or near the outlet of the Beluga River Unit’s gas filter building located within the West ½ of the Southwest ¼ of Section 26, Township 13 North, Range 10 West, Kenai Peninsula Borough, Seward Meridian, State of
Alaska. |
|
2. |
Nikiski LNG Plant Connection (ENSTAR/APC Metering Station K277) – At the downstream flange of the connection between Seller's affiliate's piping at the Nikiski LNG Plant and ENSTAR's lateral from ENSTAR's Royalty Pipeline, located in the North ½ of the Southwest ¼ of the Southwest ¼ of Section 22, Township 7 North, Range 12 West, Kenai Peninsula Borough,
Seward Meridian, State of Alaska. |
|
3. |
The Kenai-Anchorage Pipeline – Kenai Unit Area Connection (ENSTAR/APC Station K670, Meters 500 & 505). At the upstream flange of the Alaska Pipeline Company's master meter located at or near the inlet of the Alaska Pipeline Company's Kenai-Anchorage pipeline in Section 30, Township 5 North, Range 11 West, Kenai Peninsula Borough, Seward Meridian, State of Alaska. |
|
4. |
The Kenai Kachemak Pipeline – KKPL-APC Interconnection Point (MSN 601). At the downstream weld of the 8-inch electronic isolation fitting, located just outside of KKPL's meter building, between the northern terminus of the KKPL and the APL's lateral to the inlet of the APC’s Kenai-Anchorage pipeline in Southeast ¼ of Section 30, Township 5 North, Range 11 West, Kenai Peninsula Borough, Seward
Meridian, State of Alaska. |
5. |
Nikiski LNG Plant Connection (KNPL Metering Station 410) – At the upstream flange of the eight (8) inch lateral valve immediately upstream of the KNPL 403 meter connection that is downstream of Seller's affiliate's piping off of the KNPL 410 meter at the Nikiski LNG Plant, located in the North ½ of the Southwest ¼ of the Southwest ¼ of Section 22, Township 7 North, Range 12 West, Kenai Peninsula
Borough, Seward Meridian, State of Alaska. |
|
1. |
A direct connection to the Nikiski LNG facility, as contemplated in Section 16.5(b). |
|
2. |
Nikiski LNG Plant Connection (KNPL Metering Station 410) – At the upstream flange of the eight (8) inch lateral valve immediately upstream of the KNPL 403 meter connection that is downstream of Seller's affiliate's piping off of the KNPL 410 meter at the Nikiski LNG Plant, located in the North ½ of the Southwest ¼ of the Southwest ¼ of Section 22, Township 7 North, Range 12 West, Kenai Peninsula
Borough, Seward Meridian, State of Alaska. |
|
3. |
Nikiski LNG Plant Connection (ENSTAR/APC Metering Station K277) – At the downstream flange of the connection between Seller's affiliate's piping at the Nikiski LNG Plant and ENSTAR's lateral from ENSTAR's Royalty Pipeline, located in the North ½ of the Southwest ¼ of the Southwest ¼ of Section 22, Township 7 North, Range 12 West, Kenai Peninsula Borough,
Seward Meridian, State of Alaska. |
|
4. |
The Kenai-Anchorage Pipeline – Kenai Unit Area Connection (ENSTAR/APC Station K670, Meters 500 & 505). At the upstream flange of the Alaska Pipeline Company's master meter located at or near the inlet of the Alaska Pipeline Company's Kenai-Anchorage pipeline in Section 30, Township 5 North, Range 11 West, Kenai Peninsula Borough, Seward Meridian, State of Alaska. |
|
5. |
The Kenai Kachemak Pipeline – KKPL-APC Interconnection Point (MSN 601). At the downstream weld of the 8-inch electronic isolation fitting, located just outside of KKPL's meter building, between the northern terminus of the KKPL and the APL's lateral to the inlet of the APC’s Kenai-Anchorage pipeline in Southeast ¼ of Section 30, Township 5 North, Range 11 West, Kenai Peninsula Borough, Seward
Meridian, State of Alaska. |
Copyright © 2006 North American Energy Standards Board, Inc. |
NAESB Standard 6.3.1 |
All Rights Reserved |
September 5, 2006 |
|
6. |
Beluga Unit Area Connection (ENSTAR/APC Station 8601. Meters 170 A & B) – At the upstream flange of Alaska Pipeline Company's meter at or near the inlet of Alaska Pipeline Company's Beluga-Anchorage pipeline located within the West ½ of the Southwest ¼ of Section 26, Township 13 North, Range 10 West, Kenai Peninsula Borough, Seward Meridian, State of Alaska. |
Copyright © 2006 North American Energy Standards Board, Inc. |
NAESB Standard 6.3.1 |
All Rights Reserved |
September 5, 2006 |
|
· |
Letter Agreement dated May 24, 1983 amending Agreement between Shell Oil Company and Alaska Pipeline Company dated December 20, 1982. |
|
· |
Agreement between Shell Western E & P, Inc. and Alaska Pipeline Company dated January 26, 1988 amending Agreement between Shell Oil Company and Alaska Pipeline Company dated December 20, 1982. |
|
· |
Partial assignment of Agreement between Shell Oil Company and Alaska Pipeline Company dated December 20, 1982, as amended, from Shell Western E & P, Inc. to ARCO Alaska, Inc. effective October 1, 1989. |
|
· |
Agreement between ARCO Alaska, Inc. and Alaska Pipeline Company dated November 15, 1991, to amend an assigned interest in the Agreement between Shell Oil Company and Alaska Pipeline Company, dated December 20, 1982, as amended. |
Copyright © 2006 North American Energy Standards Board, Inc. |
NAESB Standard 6.3.1 |
All Rights Reserved |
September 5, 2006 |