20060710IPC to Staff 1, 18, 29, 32, 33, 51.pdf

IDAHO POWER COMPANY
PO. BOX 70
BOISE, IDAHO 83707
RECE\VED
1nn~ JUL
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BARTON L. KLINE
Senior Attorney
An IDACORP Company
July 7 2006
Jean D. Jewell , Secretary
Idaho Public Utilities Commission
472 West Washington Street
P. O. Box 83720
Boise , Idaho 83720-0074
Re:Case No. IPC-06-
Idaho Power Company s Response to the First Production
Request of Commission Staff
Dear Ms. Jewell:
Please find enclosed for filing an original and two (2) copies of Idaho Power
Company s Response to the First Production Request of Commission Staff regarding
the above-described case.
I would appreciate it if you would return a stamped copy of this transmittal letter
to me in the enclosed self-addressed stamped envelope.
Very truly yours
;1 4--f'
;J-A~ LX--
Barton L. Kline
BLK:sh
Enclosures
Telephone [phone] Fax [phone], E-mail BKlinerBIidahopower.com
BARTON L. KLINE ISB #1526
MONICA B. MOEN ISB #5734
Idaho Power Company
P. O. Box 70
Boise , Idaho 83707
Telephone: [phone]
FAX Telephone: [phone]
RECEIVED
2006 JUL - 7 PH~: 19
IDAHO PUBLIC
UTILITIES COMMISSION
Attorney for Idaho Power Company
Street Address for Express Mail
1221 West Idaho Street
Boise, Idaho 83702
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF THE APPLICATION
OF IDAHO POWER COMPANY FOR A
CERTIFICATE OF PUBLIC CONVENIENCE)
AND NECESSITY FOR THE RATE BASING
OF THE EV ANDER ANDREWS POWERPLANT.
CASE NO. IPC-06-
IDAHO POWER COMPANY'S FIRST
SUPPLEMENTAL RESPONSE TO
THE FIRST PRODUCTION REQUEST
OF COMMISSION STAFF
COMES NOW , Idaho Power Company ("Idaho Power" or "the Company
and in response to the First Production Request of the Commission Staff to Idaho Power
Company dated June 16, 2006, herewith submits the following information:
REQUEST NO.1: Please provide a copy of load-resource balance data
by month for each of the years 2006-2026 for the following conditions:
Energy analysis 50% water, 50% load
Energy analysis 70% water, 70% load
Energy analysis 90% water, 70% load
IDAHO POWER COMPANY'S FIRST SUPPLEMENTAL RESPONSE TO FIRST
PRODUCTION REQUEST OF COMMISSION STAFF Page
Peak hour analysis 50% water, 50% load
Peak hour analysis 70% water, 70% load
Peak hour analysis 90% water, 70% load
Please provide the data under two scenarios: without the addition of
Evander Andrews or any other new resources , and with the addition of Evander
Andrews. Please provide the data in an Excel format, both graphical and numerical.
RESPONSE TO REQUEST NO.1: The information requested is attached
hereto as "Response to Request No.
The response to this request was prepared by Karl Bokenkamp, GM
Power Supply Ops & Plan , Idaho Power Company, in consultation with Barton L. Kline
Senior Attorney, Idaho Power Company.
IDAHO POWER COMPANY'S FIRST SUPPLEMENTAL RESPONSE TO FIRST
PRODUCTION REQUEST OF COMMISSION STAFF Page 2
REQUEST NO. 18: Please perform the following computer simulation
runs for Idaho Power s system using the AURORA model. Before making any runs
however, review all assumptions for the transmission interconnections to Idaho Power
system , all assumptions for Idaho Power s existing generating plants , power purchase
and sales contracts , load shape and any other necessary input assumptions and make
any necessary adjustments so that the-model corresponds as closely as possible to
actual conditions. Insure that the load, and fuel price forecasts assumed in the modeling
runs are consistent with those of the 2006 IRP. It may be desirable to use the AURORA
Portfolio" feature to model Idaho Power for purposes of the following analyses.
Perform an hourly simulation beginning June 1 , 2007 and extending
through December 2032 (running five years beyond the conclusion of the
period of interest as recommended by EPIS) under an operating mode in
which no new capacity can be added within the Idaho Power system and
supply deficiencies are met through power imports from outside Idaho
Power s system. Based on the results of this run , identify the number and
timing of any hours in which transmission constraints limit the amount of
power that can be imported. In addition , identify those transmission
interconnections on which constraints occur. Identify the timing and
duration of any load curtailment predicted by the model. Report the
results in graphical format, including any narrative necessary to interpret
the results.
Perform a long-term optimization (capacity addition) study for the period
June 1 2007 through December 2032. Use hourly dispatch to fully capture
IDAHO POWER COMPANY'S FIRST SUPPLEMENTAL RESPONSE TO FIRST
PRODUCTION REQUEST OF COMMISSION STAFF Page 3
peak load hours. Confirm that the new resource choices available match
those identified in the Company s 2006 IRP and that the Evander Andrews
project is also available as a choice at the prices and terms assumed in
the RFP analysis. Assume also that market purchases are an available
option. Based on the results of this run , identify the type, timing and
location of new resources added along with the amount of capacity and
energy associated with each new resource. Confirm whether the Evander
Andrews project is chosen as an alternative to meet load. Summarize the
months and the hours within each month when the Evander Andrews plant
would be used to meet load. Identify any other resources selected by the
model.
Perform an hourly simulation beginning June 1 , 2007 and extending
through December 2032 assuming that capacity and energy is available in
accordance with the Evander Andrews project but at zero cost. Compare
the net power supply cost Over the duration of the simulation to the net
power supply cost for the model rim conducted in part "b" above. Compare
the difference in net power supply cost to the cost of the Evander Andrews
project.
RESPONSE TO REQUEST NO. 18: The information requested is
attached hereto as "Response to Request No. 18.
The response to this request was prepared by Karl Bokenkamp, GM
Power Supply Ops & Plan, Idaho Power Company, in consultation with Barton L. Kline
Senior Attorney, Idaho Power Company.
IDAHO POWER COMPANY'S FIRST SUPPLEMENTAL RESPONSE TO FIRST
PRODUCTION REQUEST OF COMMISSION STAFF Page 4
REQUEST NO. 29: Please provide a copy of any contracts/agreements
signed by Idaho Power to secure fuel storage and transportation rights (i.e.
transportation contracts) for the Evander Andrews project. What is the term of the
contract(s)? What are the provisions for extending or renewing the agreements? For
what period of time will fuel transportation and storage be guaranteed? Do the contracts
include fuel transportation and storage for either the Danskin or the Bennett Mountain
plants?
RESPONSE TO REQUEST NO. 29: The information requested is
attached hereto as "Response to Request No. 29.
The response to this request was prepared by Karl Bokenkamp, GM
Power Supply Ops & Plan , Idaho Power Company, in consultation with Barton L. Kline
Senior Attorney, Idaho Power Company.
IDAHO POWER COMPANY'S FIRST SUPPLEMENTAL RESPONSE TO FIRST
PRODUCTION REQUEST OF COMMISSION STAFF Page 5
REQUEST NO. 32: What is Idaho Power s forecast of expected fuel
prices for the Evander Andrews plant for the next twenty-year period? Please provide
forecasts in both a numerical and a graphical format.
RESPONSE TO REQUEST NO. 32: The information requested is
attached hereto as "Response to Request No. 32.
The response to this request was prepared by Karl Bokenkamp, GM
Power Supply Ops & Plan, Idaho Power Company, in consultation with Barton L. Kline
Senior Attorney, Idaho Power Company.
IDAHO POWER COMPANY'S FIRST SUPPLEMENTAL RESPONSE TO FIRST
PRODUCTION REQUEST OF COMMISSION STAFF Page 6
REQUEST NO. 33: Does Idaho Power have a risk management policy for
acquiring natural gas fuel for any of its existing or planned gas-fired plants? If so , please
provide a copy. If not, does the Company expect to develop a risk management policy?
RESPONSE TO REQUEST NO. 33: The information requested is
attached hereto as "Response to Request No. 33.
The response to this request was prepared by Karl Bokenkamp, GM
Power Supply Ops & Plan , Idaho Power Company, in consultation with Barton L. Kline
Senior Attorney, Idaho Power Company.
IDAHO POWER COMPANY'S FIRST SUPPLEMENTAL RESPONSE TO FIRST
PRODUCTION REQUEST OF COMMISSION STAFF Page 7
REQUEST NO. 51: What is Idaho Power s current forecast of expected
firm wholesale electric energy prices for the next -five and ten-year periods for heavy
and light load -hours? Please identify the source and date on which the forecasts were
made.
RESPONSE TO REQUEST NO. 51: The information requested is
attached hereto as "Response to Request No. 51.
The response to this request was prepared by Karl Bokenkamp, GM
Power Supply Ops & Plan , Idaho Power Company, in consultation with Barton L. Kline
Senior Attorney, Idaho Power Company.
DATED at Boise , Idaho, this 1-'day of July 2006.
GEfJ
BARTON L. KLINE
Attorney for Idaho Power Company
IDAHO POWER COMPANY'S FIRST SUPPLEMENTAL RESPONSE TO FIRST
PRODUCTION REQUEST OF COMMISSION STAFF Page 8
CERTIFICATE OF SERVICE
I HEREBY CERTIFY that on this day of July, 2006 , I served a true and
correct copy of the within and foregoing IDAHO POWER COMPANY'S RESPONSE TO
THE FIRST PRODUCTION REQUEST OF COMMISSION STAFF upon the following
named parties by the method indicated below, and addressed to the following:
Commission Staff Hand Delivered
Donovan Walker US. Mail
Deputy Attorney General Overnight Mail
Idaho Public Utilities Commission FAX
472 W. Washington (83702)
O. Box 83720
Boise, Idaho 83720-0074
Industrial Customers of Idaho Power Hand Delivered
Peter J. Richardson, Esq.US. Mail
Richardson & O'Leary Overnight Mail
515 N. 2ih Street FAX
O. Box 7218
Boise, Idaho 83702
Don Reading Hand Delivered
Ben Johnson Associates US. Mail
6070 Hill Road Overnight Mail
Boise, Idaho 83702 FAX
Mountain View Power, Inc.Hand Delivered
Ronald L. Williams ----X- US. Mail
Williams Bradbury, P.Overnight Mail
O. Box 2128 FAX
Boise, Idaho 83701
Robert D. Looper, President Hand Deli vered
Mountain View Power, Inc.-.:i.- US. Mail
1015 W. Hays Street Overnight Mail
Boise, Idaho 83702 FAX
(3Rt
Barton L. Kline
----
CERTIFICATE OF SERVICE, Page
IDAHO POWER COMPANY
CASE NO. IPC-O6-
FIRST PRODUCTION REQUEST
OF COMMISSION STAFF
RESPONSE TO
REQUEST NO.
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2
1
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(1
1
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(9
8
4
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5
4
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1
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1
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7
0
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Be
n
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t
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M
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t
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18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
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17
5
17
7
17
8
Da
n
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21
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7
26
8
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5
2
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(8
6
6
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8
3
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3
0
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9
6
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22
3
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0
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20
1
3
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
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Ju
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c
Pe
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H
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23
2
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2
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8
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2
2
7
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0
6
5
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8
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3
3
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Be
n
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t

M
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18
0
17
8
17
6
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8
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16
8
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5
17
7
17
8
Da
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17
9
13
0
23
2
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(9
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7
6
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1
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5
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20
2
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1
6
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6
3
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Ma
y
Ju
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De
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8
0
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7
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24
4
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0
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(8
6
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(3
7
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(2
1
3
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(1
9
8
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(1
1
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11
1
38
8
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7
4
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8
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8
5
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36
9
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6
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(1
3
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6
3
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(3
7
6
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(2
6
6
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(1
5
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33
7
(1
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(1
0
1
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(2
2
4
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4
4
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3
8
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(3
1
9
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(6
0
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31
1
(7
4
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(1
6
3
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(1
6
2
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(5
2
2
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(5
2
9
)
(4
0
9
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(1
3
7
)
28
4
(1
3
9
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(2
2
0
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1
9
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(6
9
0
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(7
0
1
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7
0
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9
2
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26
4
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7
7
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(2
7
8
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7
8
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7
8
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9
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24
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22
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5
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7
6
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1
1
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5
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20
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n
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P
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R
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20
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12
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M
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20
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6
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28
1
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12
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20
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7
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6
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21
7
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20
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11
2
16
9
27
8
21
5
20
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5
Ja
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Ma
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9
9
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6
9
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6
0
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10
2
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6
0
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5
7
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20
1
2
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7
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2
9
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Be
n
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M
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t
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16
8
16
5
16
8
17
0
17
5
17
7
17
8
20
1
3
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7
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Da
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16
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26
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31
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.
(
1
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36
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Ja
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b
Ma
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10
6
12
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7
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4
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5
0
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4
7
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3
8
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0
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n
n
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t

M
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t
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18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Da
n
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Su
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18
3
28
1
37
3
12
1
(6
8
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8
9
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9
9
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9
2
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8
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33
7
(1
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20
0
7
Ja
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b
Ma
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Ju
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25
1
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4
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(7
4
6
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(6
3
0
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(4
9
7
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(2
4
5
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6
7
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Be
n
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t

M
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t
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n
18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
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17
7
17
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Da
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15
0
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7
33
2
25
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4
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(5
8
5
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9
5
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7
5
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3
9
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29
9
(1
9
7
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20
0
8
Ja
n
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b
Ma
r
Ap
r
Ma
y
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Ju
l
Au
g
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c
Pe
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6
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21
5
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4
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3
8
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2
7
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9
1
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4
4
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(3
1
8
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(5
3
4
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Be
n
n
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t
t

M
o
u
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t
a
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n
18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Da
n
s
k
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Su
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11
2
16
9
27
8
21
5
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8
5
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(6
8
3
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7
6
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3
6
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(2
8
6
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26
6
(5
0
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(2
6
4
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20
0
9
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
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t
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Pe
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.
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2
3
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4
4
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5
9
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(5
8
8
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(1
0
0
7
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(9
1
5
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(7
9
3
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(6
4
3
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(4
0
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(3
8
3
)
(5
9
1
)
Be
n
n
e
t
t

M
o
u
n
t
a
i
n
18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Da
n
s
k
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Su
r
p
l
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D
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i
c
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y
12
6
10
8
(3
2
9
)
(7
5
2
)
(6
6
4
)
(5
3
8
)
(3
8
5
)
22
3
(1
1
5
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(3
2
1
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20
1
0
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
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t
Na
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Pe
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H
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j
D
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f
.
(2
8
3
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(2
3
8
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(1
7
2
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10
2
(6
3
2
)
(1
1
7
7
)
(1
0
8
9
)
(9
5
4
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(6
9
5
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(6
6
)
(4
2
2
)
(6
4
8
)
Be
n
n
e
t
t

M
o
u
n
t
a
i
n
18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Da
n
s
k
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n
Su
r
p
l
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/
D
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c
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n
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y
(1
0
)
10
2
(3
7
3
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(9
2
2
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(8
3
8
)
(6
9
9
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(4
3
7
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19
7
(1
5
4
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(3
7
8
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20
1
1
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
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Ju
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Au
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Na
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De
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Pe
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H
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S
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j
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.
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4
1
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(3
2
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2
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8
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2
7
1
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(1
1
8
3
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(1
0
3
8
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(7
4
3
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(9
9
)
(4
6
7
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(7
0
9
)
Be
n
n
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t
t

M
o
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n
t
a
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n
18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Da
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k
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Su
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8
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0
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2
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0
1
6
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(9
3
2
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(7
8
3
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(4
8
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16
4
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9
9
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(4
3
9
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20
1
2
Ja
n
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b
Ma
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Ju
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Au
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H
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j
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.
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8
9
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(3
4
7
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(2
6
7
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(1
2
9
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(7
5
9
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(1
3
6
9
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(1
2
7
7
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(1
1
1
2
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(7
8
9
)
(1
3
2
)
(4
8
8
)
(7
7
1
)
Be
n
n
e
t
t

M
o
u
n
t
a
i
n
18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Da
n
s
k
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Su
r
p
l
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/
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(1
1
6
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(7
7
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(0
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(1
2
9
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(5
0
0
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(1
1
1
4
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(1
0
2
6
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(8
5
7
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(5
3
1
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13
1
(2
2
0
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(5
0
1
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20
1
3
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
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p
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t
Na
v
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c
Pe
a
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H
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.
j
D
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f
.
(4
3
6
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(3
7
8
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(3
1
4
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(1
6
3
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(9
6
9
)
(1
4
6
4
)
(1
3
7
5
)
(1
1
9
2
)
(8
3
7
)
(1
6
3
)
(5
6
0
)
(8
3
4
)
Be
n
n
e
t
t

M
o
u
n
t
a
i
n
18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Da
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k
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Su
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0
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7
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6
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1
0
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2
0
9
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1
2
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3
7
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7
9
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10
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9
2
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6
4
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Ma
y
Ju
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De
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5
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8
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8
4
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6
1

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(2
5
3
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21
7
(4
5
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(1
7
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(1
4
8
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(4
4
4
)
(3
1
6
)
(2
1
4
)
(1
0
2
)
36
5
10
8
(8
7
)
(6
8
)
(4
8
9
)
(3
9
9
)
(2
9
2
)
(1
8
0
)
33
7
(1
3
1
)
(1
4
5
)
(5
8
5
)
(4
9
5
)
(3
7
5
)
(2
3
9
)
29
9
(1
9
7
)
(3
8
5
)
(6
8
3
)
(5
7
6
)
(4
3
6
)
(2
8
6
)
26
6
(5
0
)
(2
6
4
)
(3
2
9
)
(7
5
2
)
(6
6
4
)
(5
3
8
)
(3
8
5
)
22
3
(1
1
5
)
(3
2
1
)
(3
7
3
)
(9
2
2
)
(8
3
8
)
(6
9
9
)
(4
3
7
)
19
7
(1
5
4
)
(3
7
8
)
(4
2
1
)
(1
0
1
6
)
(9
3
2
)
(7
8
3
)
(4
8
5
)
16
4
(1
9
9
)
(4
3
9
)
(5
0
0
)
(1
1
1
4
)
(1
0
2
6
)
(8
5
7
)
(5
3
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)
13
1
(2
2
0
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0
1
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1
0
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(1
2
0
9
)
(1
1
2
4
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(9
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7
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10
0
(2
9
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Mo
n
t
h
l
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P
e
a
k
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L
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R
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B
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2
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C
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a
t

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A
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A
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1
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20
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50
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W
a
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5
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L
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(2
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4

I
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D
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20
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Ja
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12
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20
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35
8
30
5
38
6
69
9
Be
n
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M
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20
0
6
48
3
43
8
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3
48
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20
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7
43
6
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8
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9
62
2
Su
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D
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40
4
37
1
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8
71
9
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1
2
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(2
2
8
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6
4
)
21
5
20
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8
43
5
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5
43
4
63
4
20
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9
56
3
56
2
55
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9
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51
5
52
8
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9
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7
20
0
5
Ja
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b
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r
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H
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26
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29
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69
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6
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9
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7
)
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8
8
)
(8
4
)
(1
0
8
)
(1
2
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20
1
2
41
8
46
8
41
0
31
7
Be
n
n
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t
t

M
o
u
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t
a
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n
16
8
16
5
16
8
17
0
17
5
17
7
17
8
20
1
3
37
1
43
5
36
1
28
0
Da
n
s
k
i
n
Su
r
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l
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D
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f
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c
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n
c
y
35
8
30
5
38
6
69
9
(1
3
7
)
(1
5
6
)
(3
3
)
17
3
35
7
16
0
14
3
20
0
6
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
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e
Pe
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k

H
o
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21
0
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7
23
7
48
1
(1
1
9
)
(4
5
7
)
(4
9
0
)
(3
6
9
)
(1
6
0
)
(1
5
0
)
(1
6
2
)
Be
n
n
e
t
t

M
o
u
n
t
a
i
n
18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Da
n
s
k
i
n
Su
r
p
l
u
s
/
D
e
f
i
c
i
e
n
c
y
48
3
43
8
50
3
48
1
14
1
(2
0
2
)
(2
3
9
)
(1
1
4
)
33
9
11
8
10
8
20
0
7
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
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p
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t
Na
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Pe
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k

H
o
u
r

S
u
p
.
j
D
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f
.
16
3
13
7
19
3
62
2
(1
8
6
)
(5
4
3
)
(5
8
4
)
(4
5
4
)
(2
2
3
)
(1
9
3
)
(2
2
9
)
Be
n
n
e
t
t

M
o
u
n
t
a
i
n
18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Da
n
s
k
i
n
Su
r
p
l
u
s
/
D
e
f
i
c
i
e
n
c
y
43
6
40
8
45
9
62
2
(2
8
8
)
(3
3
3
)
(1
9
9
)
30
6
20
0
8
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
Se
p
Oc
t
Na
v
De
c
Pe
a
k

H
o
u
r

S
u
p
.
/D
e
f
.
16
2
15
4
16
8
63
4
(3
4
9
)
(6
1
8
)
(6
4
3
)
(5
0
4
)
(2
6
5
)
(2
4
4
)
(2
7
9
)
Ev
a
n
d
e
r

A
n
d
r
e
w
s

N
e
w

C
T
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Be
n
n
e
t
t

M
o
u
n
t
a
i
n
18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Da
n
s
k
i
n
Su
r
p
l
u
s
/
D
e
f
i
c
i
e
n
c
y
43
5
42
5
43
4
63
4
(1
9
5
)
(2
2
6
)
(8
1
)
16
2
46
6
20
1
16
9
20
0
9
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
Se
p
Oc
t
Na
v
De
c
Pe
a
k

H
o
u
r

S
u
p
.
j
D
e
f
.
11
1
11
3
11
5
42
9
(2
8
3
)
(7
0
0
)
(7
3
5
)
(5
9
1
)
(3
3
4
)
(3
0
7
)
(3
3
7
)
Ev
a
n
d
e
r

A
n
d
r
e
w
s

N
e
w

C
T
18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Be
n
n
e
t
t

M
o
u
n
t
a
i
n
18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Da
n
s
k
i
n
Su
r
p
l
u
s
/

D
e
f
i
c
i
e
n
c
y
56
3
56
2
55
7
42
9
14
9
(2
7
7
)
(3
1
8
)
(1
6
8
)
43
9
13
8
11
1
20
1
0
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
Se
p
Oc
t
Na
y
De
c
Pe
a
k

H
o
u
r

S
u
p
.
j
D
e
f
.
55
7
(3
5
0
)
(8
6
6
)
(9
0
5
)
(7
5
1
)
(3
9
1
)
(1
9
)
(3
4
7
)
(3
9
6
)
Ev
a
n
d
e
r

A
n
d
r
e
w
s

N
e
w

C
T
18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Be
n
n
e
t
t

M
o
u
n
t
a
i
n
18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Da
n
s
k
i
n
Su
r
p
l
u
s
/
D
e
f
i
c
i
e
n
c
y
51
5
52
8
50
9
55
7
(4
4
3
)
(4
8
8
)
(3
2
8
)
41
9
20
1
1
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
Se
p
Oc
t
Na
y
De
c
Pe
a
k

H
o
u
r

S
u
p
.
j
D
e
f
.
51
9
(4
1
6
)
(9
5
1
)
(9
9
5
)
(8
3
3
)
(4
4
4
)
(3
7
)
(3
9
3
)
(4
5
5
)
Ev
a
n
d
e
r

A
n
d
r
e
w
s

N
e
w

C
T
18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Be
n
n
e
t
t

M
o
u
n
t
a
i
n
18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Da
n
s
k
i
n
Su
r
p
l
u
s
/
D
e
f
i
c
i
e
n
c
y
46
6
49
6
45
8
51
9
(5
2
8
)
(5
7
8
)
(4
1
0
)
(1
7
)
40
1
(7
)
20
1
2
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
Se
p
Oc
t
Na
y
De
c
Pe
a
k

H
o
u
r

S
u
p
.
j
D
e
f
.
(3
4
)
(3
2
)
31
7
(4
8
1
)
(1
0
3
5
)
(1
0
8
5
)
(9
0
8
)
(4
9
7
)
(5
9
)
(4
1
6
)
(5
1
6
)
Ev
a
n
d
e
r

A
n
d
r
e
w
s

N
e
w

C
T
18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Be
n
n
e
t
t

M
o
u
n
t
a
i
n
18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Da
n
s
k
i
n
Su
r
p
l
u
s
/
D
e
f
i
c
i
e
n
c
y
41
8
46
8
41
0
31
7
(4
9
)
(6
1
2
)
(6
6
8
)
(4
8
5
)
(7
0
)
37
9
(6
8
)
20
1
3
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
Se
p
Oc
t
Na
y
De
c
Pe
a
k

H
o
u
r

S
u
p
.
j
D
e
f
.
(8
1
)
(1
4
)
(8
1
)
28
0
(6
7
8
)
(1
1
1
9
)
(1
1
7
7
)
(9
8
8
)
(5
5
1
)
(8
1
)
(4
8
6
)
(5
7
8
)
Ev
a
n
d
e
r

A
n
d
r
e
w
s

N
e
w

C
T
18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Be
n
n
e
t
t

M
o
u
n
t
a
i
n
18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Da
n
s
k
i
n
Su
r
p
l
u
s
/
D
e
f
i
c
i
e
n
c
y
37
1
43
5
36
1
28
0
(2
4
6
)
(6
9
6
)
(7
6
0
)
(5
6
5
)
(1
2
4
)
35
7
(4
1
)
(1
3
0
)
Ma
y
Ju
n
Ju
l
Au
g
Se
p
Oc
t
Na
y
De
e
(2
1
2
)
(2
2
8
)
(1
6
4
)
21
5
(1
3
7
)
(1
5
6
)
(3
3
)
17
3
35
7
16
0
14
3
14
1
(2
0
2
)
(2
3
9
)
(1
1
4
)
33
9
11
8
10
8
(2
8
8
)
(3
3
3
)
(1
9
9
)
30
6
(1
9
5
)
(2
2
6
)
(8
1
)
16
2
46
6
20
1
16
9
14
9
(2
7
7
)
(3
1
8
)
(1
6
8
)
43
9
13
8
11
1
(4
4
3
)
(4
8
8
)
(3
2
8
)
41
9
(5
2
8
)
(5
7
8
)
(4
1
0
)
(1
7
)
40
1
(7
)
(4
9
)
(6
1
2
)
(6
6
8
)
(4
8
5
)
(7
0
)
37
9
(6
8
)
(2
4
6
)
(6
9
6
)
(7
6
0
)
(5
6
5
)
(1
2
4
)
35
7
(4
1
)
(1
3
0
)
Mo
n
t
h
l
y

P
e
a
k
-
H
o
u
r

L
o
a
d

R
e
s
o
u
r
c
e

B
a
l
a
n
c
e

D
a
t
a
Ye
a
r
s

2
0
0
4
-
2
0
1
3
(N
e
w

C
T

a
t

E
v
a
n
d
e
r

A
n
d
r
e
w
s

A
v
a
i
l
a
b
l
e

Ap
r
i
l

1
,

20
0
8
)
70
0
/
0

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t
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7
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0

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I
R
P

D
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W
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Ja
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b
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20
0
4
Ja
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4
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1
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15
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7
8
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33
9
66
8
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M
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20
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33
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37
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7
45
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20
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1
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1
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24
9
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2
69
6
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8
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(2
7
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5
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2
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24
4
(7
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(8
6
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20
0
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28
0
34
7
37
8
58
6
20
0
9
40
9
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4
50
1
38
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1
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36
1
45
0
45
1
50
9
20
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5
Ja
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b
Ma
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20
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H
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11
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9
)
(3
6
7
)
(1
4
7
)
12
4
(1
8
4
)
(2
6
6
)
20
1
2
27
3
39
0
35
3
26
8
Be
n
n
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M
o
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n
t
a
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n
16
8
16
5
16
8
17
0
17
5
17
7
17
8
20
1
3
23
8
35
7
30
6
23
2
Da
n
s
k
i
n
Su
r
p
l
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s
/
D
e
f
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c
i
e
n
c
y
20
3
23
8
33
9
66
8
(3
7
)
(2
1
3
)
(1
9
8
)
(1
1
3
)
11
1
38
8
20
0
6
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
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g
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p
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t
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c
Pe
a
k

H
o
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.
10
0
19
0
45
9
(2
0
1
)
(5
2
9
)
(5
3
5
)
(4
3
9
)
(2
1
5
)
10
5
(2
2
5
)
(3
0
6
)
Be
n
n
e
t
t

M
o
u
n
t
a
i
n
18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Da
n
s
k
i
n
Su
r
p
l
u
s
/
D
e
f
i
c
i
e
n
c
y
33
0
37
0
45
7
45
9
(2
7
4
)
(2
8
4
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(1
8
5
)
36
9
(3
6
)
20
0
7
Ja
n
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b
Ma
r
Ap
r
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Ju
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Ju
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H
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14
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60
0
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7
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1
8
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2
7
)
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2
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7
3
)
(2
6
9
)
(3
7
1
)
Be
n
n
e
t
t

M
o
u
n
t
a
i
n
18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Da
n
s
k
i
n
Su
r
p
l
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/
D
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f
i
c
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n
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y
28
1
34
1
41
3
60
0
(1
3
)
(3
6
3
)
(3
7
6
)
(2
6
6
)
(1
5
)
33
7
(1
)
(1
0
1
)
20
0
8
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
Se
p
Oc
t
Na
y
De
c
Pe
a
k

H
o
u
r

S
u
p
.
j
D
e
f
.
11
1
58
6
(4
8
4
)
(6
9
9
)
(6
8
9
)
(5
7
3
)
(3
1
8
)
(3
4
2
)
(4
3
3
)
Ev
a
n
d
e
r

A
n
d
r
e
w
s

N
e
w

17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Be
n
n
e
t
t

M
o
u
n
t
a
i
n
18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Da
n
s
k
i
n
Su
r
p
l
u
s
/
D
e
f
i
c
i
e
n
c
y
28
0
34
7
37
8
58
6
(5
2
)
(2
7
6
)
(2
7
3
)
(1
5
1
)
10
9
48
5
10
3
20
0
9
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
Se
p
Oc
t
Na
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c
Pe
a
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H
o
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S
u
p
.
j
D
e
f
.
(4
4
)
38
0
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2
2
)
(7
7
7
)
(7
8
0
)
(6
6
3
)
(3
9
5
)
(4
0
7
)
(4
9
0
)
Ev
a
n
d
e
r

A
n
d
r
e
w
s

N
e
w

18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Be
n
n
e
t
t

M
o
u
n
t
a
i
n
18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Da
n
s
k
i
n
Su
r
p
l
u
s
/
D
e
f
i
c
i
e
n
c
y
40
9
48
4
50
1
38
0
(3
5
4
)
(3
6
4
)
(2
4
1
)
45
8
(4
2
)
20
1
0
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
Se
p
Oc
t
Na
v
De
c
Pe
a
k

H
o
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S
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.
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f
.
(9
2
)
50
9
(4
7
9
)
(9
4
5
)
(9
5
2
)
(8
2
4
)
(4
5
0
)
(4
4
5
)
(5
4
8
)
Ev
a
n
d
e
r

A
n
d
r
e
w
s

N
e
w

18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Be
n
n
e
t
t

M
o
u
n
t
a
i
n
18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Da
n
s
k
i
n
Su
r
p
l
u
s

/

D
e
f
i
c
i
e
n
c
y
36
1
45
0
45
1
50
9
(4
7
)
(5
2
2
)
(5
3
6
)
(4
0
2
)
(2
3
)
43
8
(1
0
0
)
20
1
1
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
Se
p
Oc
t
Na
v
De
c
Pe
a
k

H
o
u
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S
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p
.
/D
e
f
.
(1
4
1
)
(3
0
)
(4
3
)
47
1
(5
3
8
)
(1
0
3
3
)
(1
0
4
3
)
(9
0
7
)
(5
0
4
)
(1
8
)
(4
9
2
)
(6
0
7
)
Ev
a
n
d
e
r

A
n
d
r
e
w
s

N
e
w

18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Be
n
n
e
t
t

M
o
u
n
t
a
i
n
18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Da
n
s
k
i
n
Su
r
p
l
u
s
/
D
e
f
i
c
i
e
n
c
y
31
2
41
8
40
0
47
1
(1
0
6
)
(6
1
0
)
(6
2
7
)
(4
8
5
)
(7
7
)
42
0
(4
7
)
(1
5
9
)
20
1
2
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
Se
p
Oc
t
Na
v
De
c
Pe
a
k

H
o
u
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S
u
p
.
j
D
e
f
.
(1
8
0
)
(5
8
)
(9
0
)
26
8
(6
1
2
)
(1
1
2
1
)
(1
1
3
4
)
(9
8
4
)
(5
5
4
)
(4
1
)
(5
1
3
)
(6
7
0
)
Ev
a
n
d
e
r

A
n
d
r
e
w
s

N
e
w

18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Be
n
n
e
t
t

M
o
u
n
t
a
i
n
18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Da
n
s
k
i
n
Su
r
p
l
u
s
/
D
e
f
i
c
i
e
n
c
y
27
3
39
0
35
3
26
8
(1
8
0
)
(6
9
8
)
(7
1
8
)
(5
6
2
)
(1
2
7
)
39
7
(6
8
)
(2
2
2
)
20
1
3
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
Se
p
Oc
t
Na
v
De
c
Pe
a
k

H
o
u
r

S
u
p
.
j
D
e
f
.
(2
1
5
)
(9
1
)
(1
3
7
)
23
2
(8
1
4
)
(1
2
0
8
)
(1
2
2
7
)
(1
0
6
5
)
(6
0
8
)
(6
2
)
(5
8
4
)
(7
3
3
)
Ev
a
n
d
e
r

A
n
d
r
e
w
s

N
e
w

18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Be
n
n
e
t
t

M
o
u
n
t
a
i
n
18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Da
n
s
k
i
n
Su
r
p
l
u
s
/
D
e
f
i
c
i
e
n
c
y
23
8
35
7
30
6
23
2
(3
8
2
)
(7
8
5
)
(8
1
1
)
(6
4
3
)
(1
8
1
)
37
6
(1
3
9
)
(2
8
5
)
Ma
y
Ju
n
Ju
l
Au
g
Se
p
Oc
t
Na
y
De
e
(2
8
0
)
(2
7
4
)
(2
5
4
)
(2
2
)
24
4
(7
0
)
(8
6
)
(3
7
)
(2
1
3
)
(1
9
8
)
(1
1
3
)
11
1
38
8
(2
7
4
)
(2
8
4
)
(1
8
5
)
36
9
(3
6
)
(1
3
)
(3
6
3
)
(3
7
6
)
(2
6
6
)
(1
5
)
33
7
(1
)
(1
0
1
)
(5
2
)
(2
7
6
)
(2
7
3
)
(1
5
1
)
10
9
48
5
10
3
(3
5
4
)
(3
6
4
)
(2
4
1
)
45
8
(4
2
)
(4
7
)
(5
2
2
)
(5
3
6
)
(4
0
2
)
(2
3
)
43
8
(1
0
0
)
(1
0
6
)
(6
1
0
)
(6
2
7
)
(4
8
5
)
(7
7
)
42
0
(4
7
)
(
1

5
9
)
(1
8
0
)
(6
9
8
)
(7
1
8
)
(5
6
2
)
(1
2
7
)
39
7
(6
8
)
(2
2
2
)
(3
8
2
)
(7
8
5
)
(8
1
1
)
(6
4
3
)
(1
8
1
)
37
6
(1
3
9
)
(2
8
5
)
20
1
0
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
Se
p
Oc
t
Na
v
De
c
Pe
a
k

H
o
u
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S
u
p
.
/D
e
f
.
(2
8
3
)
(2
3
8
)
(1
7
2
)
10
2
(6
3
2
)
(1
1
7
7
)
(1
0
8
9
)
(9
5
4
)
(6
9
5
)
(6
6
)
(4
2
2
)
(6
4
8
)
Ev
a
n
d
e
r

A
n
d
r
e
w
s

N
e
w

C
T
18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Be
n
n
e
t
t

M
o
u
n
t
a
i
n
18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
7
17
8
Da
n
s
k
i
n
Su
r
p
l
u
s
/

D
e
f
i
c
i
e
n
c
y
17
0
21
0
27
1
10
2
(2
0
1
)
(7
5
4
)
(6
7
3
)
(5
3
2
)
(2
6
8
)
37
2
(1
9
9
)
20
1
1
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
Se
p
Oc
t
Na
v
De
c
Pe
a
k

H
o
u
r

S
u
p
.
j
D
e
f
.
(3
4
1
)
(3
2
0
)
(2
2
2
)
(6
8
0
)
(1
2
7
1
)
(1
1
8
3
)
(1
0
3
8
)
(7
4
3
)
(9
9
)
(4
6
7
)
(7
0
9
)
Ev
a
n
d
e
r

A
n
d
r
e
w
s

N
e
w

C
T
18
0
17
8
17
6
17
2
16
8
16
5
16
8
17
0
17
5
17
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IDAHO POWER COMPANY
CASE NO. IPC-O6-
FIRST PRODUCTION REQUEST
OF COMMISSION STAFF
RESPONSE TO
REQUEST NO.
18 Aurora Simulation - Utilizing the 2004 IRP assumptions with updates to fuel prices forecasts
Ran a simulation to determine transmission utilization if no new generation or DSM resources are
deployed within the Idaho Power bubbles. The transmission limits to the Idaho Power South (primary
load bubble) are reported in the below graph. The graph represents the number of hours that the "
paths" are fully utilized.
Idaho Power Co. Aurora Simulation
number of hours by year
with full transmission paths
2004 IRP with updates
500
Zone Out
IiIWECC-Wyoming
. WECC-Utah
0 WECC-OR+WA-IDNorth
0 WECC-NevadaNorth
.WECC-Montana
IiIWECC-ldaho East
3000
2500
2000
~ 1500
1000
00 ~ 0 ~ N M V ~ 00 ~ 00 ~ 0 ~ N M V ~ 00 ~ 00 ~ 0 ~ N
g g g
o 0 0 0 0 0 0 0 0 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 8 8 8N N N N N N N N N N N N N N N N N N N N N N N N N N
!Report Year!
The resulting deployment of Demand Side Resources within the model represents curtailment of load.
The graph below shows the number ofMWh per day that the model utilized Demand Side Resources
within the Idaho Power South bubble.
Idaho Power Co Aurora Simulation
Demand Side Output (Curtailment) by day
20041RP with updates
000,
Sum of Demand Side Output000,
000,
000,
.s::
:;;
000,
000,
I Report- YearIReport MonthIReport Day!
Request 18 B - Long Term Optimization (resource addition) study 6/1/2007-12/31/2032
resulted in resource addition of:
250 MW of Wind in the Idaho East Bubble (5 x 50MW Projects 2 in 2008, 2 in 2009 and
1 in 2016)
300 MW of CHP in the Idaho South Bubble (50 x 6 MW Project 2 in each year 2008-
2032)
800 MW of Pulverized Coal in the Idaho South Bubble (3 x 600MW Project 1 in 2012
1 in 2016 and 1 in 2032)
The timing and out put of all the above projects are shown graphically below:
Idaho Power Co.
RMT output by year and month for Production Request #18B
1,400,000
800,000 IBlTotal1
200,000
000,000
600,000
400,000
200,000
I ReporCYearl Report Month I
A peaking project was not select by the L T optimization process in Aurora. A significant
number of CHP projects were identified in the optimized run. Aurora was limited to 2
projects per year and it identified these as the most economic and deployed them to the
limits set. The actual availability of this number of projects and the variability of sizes
and costs of the wide spectrum of possible CHP projects was not available to the model.
IDAHO POWER COMPANY
CASE NO. IPC-O6-
FIRST PRODUCTION REQUEST
OF COMMISSION STAFF
RESPONSE TO
REQUEST NO. 29
Please see Response to Request No. 29
Some of the information requested in Request No. 29
is CONFIDENTIAL only that information which is
not CONFIDENTIAL will be provided to Mountain
View Power
)tract Document Page 1 I
Rate Schedule TI-l Service Agreement
Contract No. 133234
IS SERVICE AGREEMENT (Agreement) is made and entered into on January 06, 2005,
and between Northwest Pipeline Corporation (Transporter) and IDAHO POWER COMPANY (Shipper).
EREAS:
Transporter and Shipper desire to use this Agreement to track Shipper ' s Receiving Party Imbalance at
the Bennatt delivery point, pursuant to Section 15 of the General Terms and Conditions of
Transporter s FERC Gas Tariff.
EREFORE, in consider~tion of the premises and mutual covenants set forth herein, Transporter and Shipperree as follows:
Tariff Incorporation. Rate Schedule TI-l and the General Terms and Conditions (GT&C) that apply to Rate
hedule TI-l, as such may be revised from time to time in Transporter s FERC Gas Tariff (Tariff), are
corporated by reference as part of this Agreement, except to the extent that any provisions thereof may be
dified by non-conforming provisions herein.
Transportation Service. Subj ect to the terms and conditions that apply to service under this Agreement,
ansporter agrees to receive, transport and deliver natural gas for Shipper, on an interruptible basis. The
ximum Daily Quantity of natural gas and the receipt and delivery points are set forth on Exhibit
Transportation Rates. Shipper agrees to pay Transporter for all services rendered under this Agreement at
e rates set forth or referenced herein. The maximum currently effective rates (Recourse Rates) set forth
the Statement of Rates in the Tariff, as revised from time to time, that apply to Rate Schedule TI-l will
ply to service hereunder unless and to the extent that negotiated rates apply as set forth on Exhibit D.twi thstanding the foregoing, a temporary discounted Recourse Rate may apply pursuant to the terms set
rth on a Rate Schedule TI-l Temporary Discount form. Additionally, if applicable under Section 21 of the&C, Shipper agrees to pay Transporter a facility reimbursement charge as set forth on Exhibit C.
Transportation Term. This Agreement becomes effective on the date first set forth above. The primary term
gin date for the transportation service hereunder is set forth on Exhibit A. This Agreement will remain in
11 force and effect through the primary term end date set forth on Exhibit A and, if Exhibit A indicates
at an evergreen provision applies, through the established evergreen rollover periods thereafter until
rminated in accordance with the notice requirements under the applicable evergreen provision.
Non-Conforming Provisions. All aspects in which this Agreement deviates from the Tariff, if any, are set
rth as non-conforming provisions on Exhibit B. If Exhibit B includes any material non-conforming
ovisions, Transporter will file the Agreement with the Federal Energy Regulatory Commission (Commission)d the effectiveness of such non-conforming provisions will be subject to the Comm~ssion acceptance ofansporters filing of the non-conforming Agreement.
Exhibit Incorporation. Exhibit A is attached hereto and incorporated as part of this Agreement. If
hibits B, C and/or D apply, as noted on Exhibit A to this Agreement, then such Exhibits also are attached
reto and incorporated as part of this Agreement.
Regulatory Authorization. Transportation service under this Agreement is authorized pursuant to the
mmission regulations set forth on Exhibit A.
Superseded Agreements, When this Agreement takes effect, it supersedes, cancels and terminates the
llowing agreement (s): None
WITNESS WHEREOF, Transporter and Shipper have executed this Agreement on January 06, 2005.
)AHO POWER COMPANY
" /S/
Northwest Pipeline Corporation
By: /S/
,me: VERN PORTER
tIe: MANAGER - POWER SUPPLY OPER.
Name: MIKE RASMUSON
Title: MANAGER NWP MARKETING SERVICES
1/1 fI/'"'I
ltract Document Page 2.
EXHIBIT A
(Dated January 06, 2005, Effective January 06, 2005)
to the
Rate Schedule TI-l Service Agreement
(Contract No. 133234)
between Northwest Pipeline Corporation
and IDAHO POWER COMPANY
SERVICE DETAILS
Maximum Daily Quantity: 1 Dth per day
Receipt Point (s): All Transportation Receipt Points
Delivery Point (s): All Transportation Delivery Points
Transportation Term:
a. Primary Term Begin Date:
January 07 2005
b. Primary Term End Date:
February 28, 2005
c. Evergreen Provision:
Yes, see Section 8 of Rate Schedule TI-l
Regulatory Authorization: 18 CFR 284,223
Additional Exhibits:
Exhibi t
Exhibi t
Exhibi t
1/1 Of...,
AGENCY DELEGATION
NORTHWEST PIPELINE CORPORATION
Northwest Pipeline Corporation ("Transporter ) and Idaho Power Co.Shipper ) BA # 523
to the following agreement(s) ("Agreement(s)"
Agreement Type
TF-
TF-
are parties
Agreement Date
9/24/2001
11/1/2002
Agreement Number
126951
126442
Shipper hereby designates IGI Resources, Inc.as its Agent and notifies-Transporter
that such Agent is authorized (as indicated below) (1) to perfonn certain responsibilities pertaining to theAgreement(s) and/or (2) to request and/or execute new agreements on behalf of Shipper, with any such
new agreements deemed added to the above Agreement(s) list upon execution:
-1L
All Access
Nominations
Contract Inquiry
Contract Request
Contract Execution
Capacity Release Offers
Capacity Release Bids
Discount Request
Imbalan,ce Trading
Receive Billings
Invoice Review
Make Payments
--L--L
l..-.lL-.lL
(Perfonn all listed options)
(Operator / Shipper / Inquiry)
(Access agreements infonnation)
(Submit request for amendment)
(Execute Amendments / Execute new Contracts)
(Submit Request for Capacity Release)
(Submit Capacity Release Bids)
Detailed description of other responsibilities being delegated to Agent:
OFO designated Agent contact (required only if Agent is responsible for Nominations):
(E-mail) IGIDispatch~bp.com
In lieu of the otherwise designated addresses for communications under the Agreement(s), all notices
invoices and correspondence concerning the above mentioned delegated duties shall be directed to Agent
at the following address:
IGI Resources, Inc.
701 Morrison-Knudsen Plaza Drive
Suite 300
Boise. ID 83707-6488
Attn: Rachelle Harper
Phone: [phone]
Agency Delegation
Page 2
Shipper shall remain liable to Transporter for all of its obligations as Shipper under the Agreement(s).
Shipper hereby indemnifies and holds Transporter harmless from any and all liabilities, losses, damages
expenses and other obligations of any nature whatsoever that Transportermay suffer as a result of any and
all claims, demands, costs, attorney fees and judgements against Transporter resulting ITom Transporter
reliance on Agent, including but not limited to payment made by Transporter to Agent or actions taken by
Transporter pursuant to Agent's actions or inaction under the Agreement(s).
Shipper s designation and appointment of Agent shall become effective March 17.2004, and shall remain
in effect until the last day of October 31. 2007 . Shipper or Agent may terminate this delegation and
appointment by giving at least seven (7) business days written notice to Transporter; provided, however
such termination will not become effective until the first day of the month following such notice. This
delegation and designation shall automatically terminate upon the termination or cancellation of the
Agreement(s).
On the date this Agency Delegation takes effect, it supersedes, cancels and terminates the following
Agency Delegation(s):
Dated
November 2002
Agent
IGI Resources Inc.
SHIPPER
Idaho Power Company
~pa (Pl
By.
. ~ . "
(Signature)
Name: ~/ZL 13, 15e:;/L:c,v~,Q
(Please Print)
Title: bE.v. mAl? IltdtJ!. f/I~v f'Lmwv')vE-,
(Please Print)
AGENT
IGI Resources
Company Name (Please Print)
By:
(Signature)
Name:
(Please Print)
Title:
(Please Print)
Please fax a signed copy ofthis agreement to the following:
Marketing Services, Northwest Pipeline CorporationFax: [phone]
Hotline Phone: (80l) 584-7301
TF0360 030004P126Third Revised Sheet No. 60TF04 Second Revised Sheet No. 60
TF05Laren M. Gertsch, DirectorTF06083104 100104
TF07
RATE SCHEDULE SGS-
Storage Gas Service - Interruptible
AVAILABILITY
This open-access Rate Schedule is available on a first-come, first-served basis to
any Shipper for the purchase of natural gas storage service from Transporter when
Shipper and Transporter have executed a Service Agreement for the storage of gas under
this Rate Schedule and have arranged for the related transportation of gas to and from the
Jackson Prairie Storage Project under one of Transporter s Transportation Rate Schedules.
APPLICABILITY AND CHARACTER OF SERVICE
Applicability. This Rate Schedule shall apply to interruptible storage service
consisting of Transporter s injection, storage and withdrawal of Shipper s gas at the
Jackson Prairie Storage Project. Delivery of natural gas by Shipper to Transporter for
injection and by Transporter to Shipper upon withdrawal shall be at the point of
interconnection between the Jackson Prairie Storage Project and Transporter s main
transmission line.
Character of Service. Storage gas service rendered to Shipper under this Rate
Schedule shall be interruptible up to Shipper s Interruptible Storage Capacity and
Maximum Withdrawal Quantity, and shall be subject to the executed Service Agreement
and the limitations of this Rate Schedule.
Interruptible service shall be available only to the extent that the injection, storage
and withdrawal capacity available to Transporter is not being utilized for Rate Schedule
SGS-2F firm service or for Transporter s system balancing requirements.
If and to the extent Shipper s Working Gas Inventory cannot continue to be
accommodated within the storage capacity available to Transporter, for any reason, or
such utilized storage capacity is needed to meet Transporter s firm obligations under Rate
Schedule SGS2F or Transporter s system balancing requirements, Transporter will notify
Shipper that, within seven days of such notice, Shipper is required to reduce the level of
its Working Gas Inventory existing on the day of such notice to a level specified by
Transporter.
Prior to the end of any seven day period (or any extension of such period, as
applicable ) Transporter may notify Shipper that it has revised the required level
applicable to Shipper s Working Gas Inventory. If the new level is higher than the
previously specified
TF0361 060004P126Sixth Revised Sheet No. 61TF04 Fifth Revised Sheet No. 61
TF05Laren M. Gertsch, DirectorTF06083104 100104TF07
RATE SCHEDULE SGS-
Storage Gas Service - Interruptible (Continued)
APPLICABILITY AND CHARACTER OF SERVICE (Continued)
level, the seven day period continues to apply to that portion of Shipper s Working Gas
Inventory that is in excess of the revised level. If the revised level is lower than the
previously specified level, requiring additional gas to be withdrawn, the seven day period
applicable to the volume of Shipper s Working Gas Inventory in excess of the previously
specified level is still valid but a new seven day period will apply to the volume of
Shipper s Working Gas Inventory that is in excess of the newly specified level.
However, if Shipper has nominated Working Gas Inventory from the Jackson
Prairie Storage Project using primary Receipt and Delivery Points under a Rate Schedule
TF-1 or Rate Schedule TF-2 service agreement and Transporter is unable to provide the
related transportation, then such seven day period shall be extended by one day for each
day Transporter is unable to render such transportation. Transporter shall not extend the
seven day period if Transporter is unable to provide the related transportation under a
Rate Schedule TF-l Service Agreement using alternate points or overrun nominations or
under a Rate Schedule TI -1 Service Agreement. If Shipper fails to reduce its Working
Gas Inventory to the level specified by Transporter within seven days (or any applicable
extensions) of receiving notice ITom Transporter, then Transporter shall take title to all of
Shipper s Working Gas Inventory in excess of the Working Gas Inventory level specified
by Transporter, free and clear of any adverse claims.
MONTHLY RATE
Each month, Shipper will pay Transporter for service rendered under this Rate
Schedule the amount specified in this Section 3 , as applicable.
Volumetric Charge. Shipper will pay Transporter for service rendered hereunder
a volumetric charge in an amount equal to the sum of the daily product of Shipper
Working Gas Inventory and the Maximum Currently Effective Rate per Dth as set forth
on Sheet No.7 of this Tariff.
The related transportation of gas to and from the Jackson Prairie Storage Project
shall be subject to separate transportation charges under Transporter s applicable
open-access Transportation Rate Schedules. The volumetric charge set forth in this
Section 3 is exclusive of the aforementioned transportation charges.
TF0362 050004P126Fifth Revised Sheet No. 62TF04 Fourth Revised Sheet No. 62
TF05Laren M. Gertsch, DirectorTF06083104 100104
TF07
RATE SCHEDULE SGS-
Storage Gas Service - IntelTUptible
(Continued)
MONTHLY RATE (Continued)
Discounted Recourse Rates. Transporter reserves the right to discount at any time
the Recourse Rates for any individual Shipper under any service agreement without
discounting any other Recourse Rates for that or another Shipper; provided, however, that
such discounted Recourse Rates shall not be less than the Minimum Currently Effective
Rates set forth on Sheet No.7 of this Tariff, or any superseding tariff. Such discounted
Recourse Rates may apply to specific volumes of gas, such as volumes injected
withdrawn or stored above or below a certain level or all volumes if volumes exceed a
certain level, and volumes of gas injected, withdrawn or stored during specific time
periods. If Transporter discounts any Recourse Rates to any Shipper, Transporter will file
with the Commission any required reports reflecting such discounts.
Negotiated Rates. Notwithstanding the general provisions of this Section 3, if
Transporter and Shipper mutually agree to Negotiated Rates for service hereunder, such
Negotiated Rates will apply in lieu of the otherwise applicable rates identified in this
Section 3.
FUEL GAS REIMBURSEMENT
Shipper shall reimburse Transporter for fuel use in-kind, as detailed in Section 14
of the General Terms and Conditions.
DEFINITIONS
1 Shipper s IntelTUptible Storage Capacity shall be the maximum quantity of gas in
Dth which Transporter may store for Shipper s account and shall be specified in the
executed Service Agreement between Transporter and Shipper.
5.2 Shipper s Maximum Withdrawal Quantity shall be the maximum quantity of gas
in Dth which Transporter may withdraw from storage for Shipper s account on a daily
basis, except as provided in Section 6., and will be specified in the executed Service
Agreement between Transporter and Shipper.
3 Shipper s Working Gas Inventory shall be the actual quantity of working gas in
storage for Shipper s account at the beginning of any given day.
TF0363 030004P126Third Revised Sheet No. 63TF04 Sub Second Revised Sheet No. 63
TF05Laren M. Gertsch, DirectorTF06083104 100104
TF07
RATE SCHEDULE SGS-
Storage Gas Service - Interruptible
(Continued)
WITHDRAWALS FOR SHIPPER'S ACCOUNT
1 General Procedure. Shipper may request Transporter to withdraw gas at any time
during the year. When Shipper wants to withdraw gas under this Rate Schedule on any
day, it shall give notice to Transporter specifying the volume of gas within Shipper
Working Gas Inventory which it wishes to withdraw under this Rate Schedule during
such day. Transporter shall thereupon withdraw the volume of gas so nominated, up to
Shipper s Maximum Withdrawal Quantity, subject to the limitations set forth in this Rate
Schedule and subject to acceptance of such volume by the party under whose Service
Agreement the gas is to be transported. If Transporter cannot accommodate all
interruptible withdrawal nominations, such nominations will be scheduled based on the
rate paid by each Shipper, from the highest rate to the lowest rate. Shipper may also
submit a nomination to withdraw interruptible volumes in excess of its Maximum
Withdrawal Quantity and Transporter, at its sole discretion, may schedule such
withdrawals.
Withdrawal Limitation. Withdrawals may be scheduled only to the extent that
withdrawal capacity is available to Transporter which is not being utilized for Rate
Schedule SGS-2F service or for Transporter s system balancing requirements. In no
event shall withdrawals for a Shipper exceed the balance of gas stored in Shipper
account.
INJECTIONS FOR SHIPPER'S ACCOUNT
General Procedure. Shipper may request Transporter to inject gas at any time
during the year. When Shipper wants to inject gas under this Rate Schedule on any day,
it shall give notice to Transporter, specifying the volume of gas it desires injected under
this Rate Schedule on such day, including applicable fuel reimbursement requirements.
Transporter shall thereupon inject the volume of gas so nominated, subject to the
limitations set forth in this Rate Schedule and subject to delivery of such volume, and
shall retain any fuel use reimbursement furnished in-kind in accordance with Section 14
of the General Terms and Conditions. If Transporter cannot accommodate all
interruptible injection nominations, such nominations will be scheduled based on the rate
paid by each Shipper, from the highest rate to the lowest rate.
TF0364 040004P126Fourth Revised Sheet No. 64TF04 Third Revised Sheet No. 64
TF05Laren M. Gertsch, DirectorTF06083104 100104
TF07
RATE SCHEDULE SGS-
Storage Gas Service - Interruptible
(Continued)
INJECTIONS FOR SHIPPER'S ACCOUNT (Continued)
7.2 Injection Limitation. Injections may be scheduled only to the extent that injection
and storage capacity is available to Transporter which is not being utilized for Rate
Schedule SGS-2F service or for Transporter s balancing requirements.
In no event shall injections result in the balance of gas stored in Shipper s account
exceeding Shipper s Interruptible Storage Capacity.
TRANSFER OF WORKING GAS INVENTORY
Shippers subject to this Rate Schedule and to Rate Schedule SGS-2F may,agree to
transfer their respective Working Gas Inventories between themselves. Participating
Shippers must notify Transporter s Marketing Services personnel of their intent to
transfer such Working Gas Inventories, in writing, prior to the beginning of the Gas Day
in which such transfer will occur. Transfers of Working Gas Inventory may not result in
any Shipper taking title to Working Gas Inventory volumes that exceed such Shipper
Rate Schedule SGS-2F Storage Capacity or Rate Schedule SGS-2I Interruptible Storage
Capacity.
Pursuant to the January 15 , 1998 Gas Storage Project Agreement, owners of the
Jackson Prairie Storage Project may transfer portions of their respective available
working gas inventories, as defined in the Project Agreement, to each other. Upon
agreement of the parties, and subject to the terms ofthe Project Agreement, Transporter
may utilize its ownership account on behalf of a Rate Schedule SGS-2I Shipper to
transfer such Shipper s Working Gas Inventory to an owner s available working gas
inventory account. Conversely, an owner may transfer its available working gas
inventory to a Rate Schedule SGS-2I Shipper s Working Gas Inventory account.
EVERGREEN PROVISION
Evergreen Provision. If Transporter and Shipper agree to include an evergreen
provision as indicated on Exhibit A of the Service Agreement, the following conditions
will apply:
(a)The established rollover period will be one month.
TF0365 040004P126Fourth Revised Sheet No. 65TF04 Third Revised Sheet No. 65
TF05Laren M. Gertsch, DirectorTF06083104 100104
TF07
10.
RATE SCHEDULE SGS-
Storage Gas Service - Interruptible
(Continued)
EVERGREEN PROVISION (Continued)
(b) Either Transporter or Shipper may tenninate the Service Agreement in its
entirety upon the primary tenn end date or upon the conclusion of any evergreen
rollover period thereafter by giving the other party tennination notice at least
thirty days before the termination date.
(c) Tennination notice under Section 9.1(b) will be deemed given when
posted on Transporter s Designated Site. If Transporter gives tennination notice
such termination notice also will be given via Internet E-mail or fax if specified
by Shipper on the Business Associate Infonnation form.
GENERAL TERMS AND CONDITIONS
This Rate Schedule incorporates the General Tenns and Conditions contained in
this Tariff except Sections 13, 16 24 and 25, and except as modified in the
executed Service Agreement.
itract Document Page 1 I
Rate Schedule SGS-2I Service Agreement
Contract No. 134276
IS SERVICE AGREEMENT (Agreement), made and entered into on January 09, 2006,
and between Northwest Pipeline Corporation (Transporter) and Idaho Power Company (Shipper).
EREFORE, in consideration of the premises and mutual covenants set forth herein, Transporter and Shipperree as follows:
Tariff Incorporation. Rate Schedule SGS-2I and the General Terms and Conditions (GT&C) that apply to Rate
hedule SGS-2I, as such may be revised from time to time in Transporter s FERC Gas Tariff (Tariff), are
corporated by reference as part of this Agreement, except to the extent that any provisions thereof may be
dified by non-conforming provisions herein.
Storage Service. Subject to the terms and conditions that apply to service under this Agreement,
ansporter agrees to inj ect, store and withdraw natural gas for Shipper, on an interruptible basis. The
ximurn Withdrawal Quantity and Interruptible Storage Capacity are set forth on Exhibit A. If contract-
ecific OFO parameters are set forth on Exhibit A, whenever Transporter requests during the specified time
riod, Shipper agrees to flow gas as requested by Transporter, up to the specified volume through the
ecified transportation corridor.
Storage Rates. Shipper agrees to pay Transporter for all services rendered under this Agreement at the
tes set forth or referenced herein. The maximum currently effective rates (Recourse Rates) set forth in
e Statement of Rates in the Tariff, as revised from time to time, that apply to Rate Schedule SGS-2I will
ply to service hereunder unless and to the extent that discounted Recourse Rates apply as set forth on
hibit A or negotiated rates apply as set forth on Exhibit
Service Term. This Agreement becomes effective on the date first set forth above. The primary term begin
te for the storage service hereunder is set forth on Exhibit A. This Agreement will remain in full force
d effect through the primary term end date set forth on Exhibit A and, if Exhibit A indicates that an
ergreen provision applies, through the established evergreen rollover periods thereafter until terminated
accordance with the notice requirements under the evergreen provision.
Non-Conforming Provisions. All aspects in which this Agreement deviates from the Tariff, if any, are set
rth as non-conforming provisions on Exhibit B. If Exhibit B includes any material non-conforming
ovisions, Transporter will file the Agreement with the Federal Energy Regulatory Commission (Commission)
d the effectiveness of such non-conforming provisions will be subject to the Commission acceptance ansporter s filing of the non-conforming Agreement.
Exhibit Incorporation. Exhibit A is attached hereto and incorporated as part of this Agreement. If
hibits Band/or D apply, as noted on Exhibit A to this Agreement, then such Exhibits also are attached
reto and incorporated as part of this 'Agreement.
Regulatory Authorization. Storage service under this Agreement is authorized pursuant to the Commission
gula tions set forth on Exhibit A.
Superseded Agreements. When this Agreement takes effect, it supersedes, cancels and terminates the
llowing agreement (s): None
WITNESS WHEREOF, Transporter and Shipper have executed this Agreement on January 09, 2006.
faho Power Company
!: IS/
Northwest Pipeline Corporation
By: /S/
Name: MIKE RASMUSON'me: VERN PORTER
tIe: MANAGER - POWER S UPPL Y OPER.Title: MANAGER NWP MARKETING SERVICES
1/10/2
ltract Document Page 2 I
EXHIBIT A
(Dated January 09, 2006, Effective January 09, 2006)
to the
Rate Schedule SGS-2I Service Agreement
(Contract No. 134276)
between Northwest Pipeline Corporation
and Idaho Power Company
SERVICE DETAILS
Maximum Withdrawal Quantity: 30,000 Dth per day
Interruptible Storage Capacity: 200,000 Dth
Recourse or Discounted Recourse Storage Rates:
a. Volumetric Charge (per Dth of Shipper ' s Working Gas Inventory):
Maximum Currently Effective Tariff Rate
b. Rate Discount Conditions Consistent with Section 3.2 of Rate Schedule SGS-2I:
Not Applicable
Service Term:
a. Primary Term Begin Date:
January 11, 2006
b. Primary Term End Date:
February 28, 2006
c. Evergreen Provision:
Yes, see Section 9.1 of Rate Schedule SGS-
Regulatory Authorization: 18 CFR 284.223
Additional Exhibits:
Exhibit B No
Exhibi t D No
1/10/2
Duke Enermr.(jj)
Gas Transmission
DUKE ENERGY GAS
TRANSMISSION
Suite 2600, 4251st Street
Fifth Avenue Place, East Tower
Calgary, AS
T2P 3LB
Attn: Dave Churchman
Idaho Power Company
1221 , W. Idaho Street
Boise, Idaho
83702
Dear Dave:
Re: Customer Interface Aqreement
Please find attached a fully executed copy of your Customer Interface Agreement, for
your files.
If we can be of further assistance, please do not hesitate to contact Gas Scheduling at
[phone].
Sincerely,
Gas Scheduling
DEGT West, BC Pipeline & Field Services
www.duke-energy.com
CUSTOMER INTERFACE USER AGREEMENT
Shipper/Customer Name:
~",..
(Jo"./-(
/" ;"
pet ;\. r,
(herein re.ftrred to as "you
, "
Customer" or "Shipper
Jcir1(.o(or
'1
2.5 2-06,6
Westcoast Energy Inc., carrying on business as Duke Energy' Gas Transmission ("DEGT") has
developed an internet-based Customer Interface (the "Cu,stomer Interface ) for conducting data
entry, reporting, capacity allocation bidding, ~otifications and other communications, including
nominations, statements, authorizations and curtailments. This Agreement sets out the terms on
which DEGT offers the Customer Interface to you.
, '
Date:
References in this Agreement and the Schedules to this Agreement to the "Tariff' refer to
Westcoast Energy .Inc.'s--General Terms and Conditions - Service, as filed with or otherwise
approved by the National Energy Board and in effect from time to time in accordance with Part
IV ofthe National Energy Board Act (Canada).
In consideration ofDEGT permitting you to access the Customer Interface, you agree and DEGT
agrees as follows:
Purpose
The Customer Interface is intended to provide a method for you to conduct business on DEGT's
Pipeline and Field Services Systems via the Internet. The Customer Interface may be used only
for the purposes set out in Schedule A, as amended by DEGT from time to time. The Customer
Interface is not to be used for any other purpose without the express written consent ofDEGT.
Access
, '
The Customer Interface can be accessed at the DEGT Pipeline and Field Services Website (the
Website ) on the World Wide Web at www.wei~pipeline.com or other web site as determined
by DEGT by clicking on the "Customer Activities~' link on the' navigation bar of the homepage.
In order to access the Customer Interface, the following items are required:
. .' .
(a)the hardware, software, telecommunications lines, Internet access and other items in the
Customer operating environment, all of which you are required to provide at your cost
" '
and for which the requirements are set out in Schedule B;
(b)a Customer Administrator user identification and password, as detailed in Section 4; and
(c)a user identification and password, as detailed in Section 4.
DEGr may from time to time change the customer operating environment requirements upon at
least 90 days prior w'ritten notice to you.
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\I~
Use of Password
You are responsible for all use of the Customer Interface by you, your agents and by any person
using an activated identification and password issued pursuant to this Agreement, and you must
ensure that all user identifications and passwords are kept confidential. No user may assign his
or her identification or password to another user. DEGT and all other users of the Customer
Interface are entitled to rely on and use, and treat as authorized by you, all information delivered
and data entered through the Customer Interface by you, your agents or any person using an
activated user identification and password issued pursuant to this Agreement.
Customer Administrator and Changes in Users or Ids
You must designate an initial Customer Administrator for the Customer Interface by completing
and signing Schedule C and returning it to DEGT along with a complete and executed copy of
this Agreement. Thereafter, you may change the person designated as Customer Administrator
by having one of your officers complete and sign a new Schedule C and deliver it to DEGT.
The Customer Administrator is responsible for, and has authority to initially appoint, add, delete
modifY and administer all user IDs for your access to the Customer Interface and to modifY
information about you on the Customer Interface.
Your Customer Administrator may add or withdraw user access to the Customer Interface and
determine or change a user s access level or password by means of the User Administration
screens within the Customer Interface. Each request for a new user ID or change in a user
access level or password will be effective as soon as practical after receipt by DEGT of your
Customer Administrator s on-line request. However, you cannot assign a new Customer
Administrator by this on-line method.
You may assign agents to use the Customer Interface on your behalf by completing and signing
Schedule ,. D, Customer Interface Appointment of Agent form, and delivering to DEGT.
Thereafter you may make changes to such agents only by having one of your officers complete
and sign a new Schedule D and delivering it to DEGT. This procedure cannot be completedonline:
Contractual Obligations
You understand and agree that:
(a)each nomination and communication submitted by you through the Customer Interface
will bind you in accordance with the terms ofthe service agreement tolls and tariffs
between you and DEGT;
(b)you will bind yourself contractually to DEGT, in accordance with the terms of the Tariff
when you submit a capacity bid through the Customer Interface; and
(c)any person to whom you give a user identification to access the Customer Interface, or
any person that you have authorized to act as your agent on the Customer Interface, will
have all necessary power and authority to use the Customer Interface and enter into
obligations, agreements and contracts which will be binding on you.
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G=-,
Ownership and Restrictions on Use
Title to and all rights (including all intellectual property rights) in all software comprising the
Customer Interface and the Website provided by DEGT, and all information and material
contained in the Customer Interface provided by DEGT (all such software, information and
material collectively called the "Proprietary Material") shall be owned by and remain in DEGT
or its licensors. You must not try to disassemble, decompile, translate or convert into human
readable form or into any other computer language, or otherwise reverse engineer or modify, all
or any part of the Proprietary Material, or use any of the Proprietary Material to develop any
derivative works or any functionally compatible or competing software.
Termination
In addition to the other tenDS and conditions herein, DEGT may suspend or terminate your
access to the Customer Interface for any reason including breach of this Agreement, or if you,
your agent or any person using one of the user identifications issued pursuant to this Agreement
otherwise uses, or appears to use, the Customer Interface, any other part of the Website or any of
the Proprietary Material for any improper, fraudulent or malicious purpose, including, without
limitation, to impair utilization of the Customer Interface by others. In the event this action is
required, DEGT shall provide notice with reason to the Customer for such action.
Access Levels and Receipt of Unauthorized Information
The Customer Interface has been designed so that each Customer s information can only be
accessed by that Customer or its agent for the purposes of such information, and so that each user
can access only the information to which that user is entitled, by access level as determined by
you. You agree that you will not attempt to access, download, copy or otherwise use any
information on the Customer Interface thaJ you are not authorized to access, and you agree to
ensure that your agents and each individual user authorized by you does not attempt the same.
, however, you, your agent or any user authorized by you does access, receive or otherwise
obtain any such unauthorized information, then you agree- to promptly notifYDEGT, and you,
agree not to download, copy, transmit or otherwise use any of such unauthorized information
except as may be expressly instructed by DEGT.
You acknowledge and agree that DEGT, as the operator and owner of the Customer Interface
will have access to, and the ability to review to the fullest extent allowed by law, all messages
electronic mail, files and other communications of any sort on the Customer Interface, whether
or not such communications are designated as private or confidential.
DEGT Disclaims and Limits its Liability
While DEGT will use reasonable efforts to ensure that the Customer Interface is operational on a
regular basis and that all information posted by DEGT to the Customer Interface is accurate and
free from viruses or other potentially harmful content, DEGT cannot represent and warrant this
and DEGT will not be 'responsible for any problems or damage caused to you, or to the system or
equipment you are using to access the Customer Interface, whether as a result of accessing the
Website or Customer Interface or using any Proprietary Material or transmitting information to
C:\Documents and Settings\treimerILocal Settings\Temporary Internet Files\OLKI3Customer Interface User Agreementdoc
July 14. 2004
G=-
or from the Customer Interface, or viewing or downloading any information, or otherwise using
the Customer Interface in any manner.
You acknowledge that use of the Customer Interface involves transmission over the Internet
your proprietary and confidential information. While DEGT will use reasonable efforts to
maintain the privacy of your proprietary and confidential information in the possession
DEGT, DEGT cannot guarantee the security of such information during its transmission over the
Internet. Nor can DEGT guarantee the availability ofthe Internet. DEGT will not be responsible
for unauthorized access to, alteration of, disclosure of, or use of your transmissions or
information, any material or information sent or received or not sent or received, or any
transactions entered into or through the Customer Interface. You specifically agree that DEGT
will not be liable for any threatening, defamatory, obscene, offensive or illegal content or
conduct of any other party or any infringement of another s rights, including intellectual property
rights.
THE CUSTOMER INTERFACE IS PROVIDED "AS IS" WITHOUT WARRANTY OF ANY
KIND. DEGT EXPRESSLY DISCLAIMS ALL REPRESENTATIONS, WARRANTIES AND
CONDITIONS EXPRESS OR IMPLIED, INCLUDING BUT NOT LIMITED TO IMPLIED
REPRESENTATIONS WARRANTIES AND CONDITIONS OF QUALITY,
PERFORMANCE, MERCHANTABILITY, DURABILITY, FITNESS FOR A PARTICULAR
PURPOSE, TITLE AND THOSE ARISING BY STATUTE OR OTHERWISE IN LAW OR
FROM A COURSE OF DEALING OR USE OF TRADE. WITHOUT LIMITATION, DEGT
DOES NOT REPRESENT OR WARRANT THAT:
, .
THE WEBSITE OR THE CUSTOMER INTERFACE WILL PERFORM TO YOUR
PERFORMANCE STANDARDS OR THAT INFORMATION CONCERNING YOU
ON THE CUSTOMER INTERFACE WILL BE KEPT CONFIDENTIAL, OR
(ii) THE OPERATION OF THE WEBSITE OR THE CUSTOMER INTERFACE WILL BE
ERROR FREE OR UNINTERRUPTED, THAT DEFECTS WILL BE CORRECTED
THAT THE CUSTOMER INTERFACE WILL BE FREE FROM VIRUSES OR
OTHER HARMFUL COMPONENTS OR THAT THE RESULTS OBTAINED FROM
" " .
" ITS, USE WILL BE c:O~~T, ACCURATE, TI~L Y ~R ()THERWISE RELIAB~~.
IN NO EVENT SHALL DEGT BE LIABLE FOR ANY DAMAGES, WHETHER DIRECT
COMMERCIAL, ECONOMIC, SPECIAL, INCIDENTAL, INDIRECT, CONSEQUENTIAL
PUNITIVE OR EXEMPLARY DAMAGE HOWSOEVER ARISING, IN CONNECTION
WITH THE WEBSITE OR THE CUSTOMER INTERFACE EVEN IF DEGT HAS BEEN
ADVISED OR FORESEES THE POSSIBILITY ANY OF THESE DAMAGES
OCCURRING, INCLUDING WITHOUT LIMITATION ANY LOST REVENUE, FAILURE
TO REALIZE EXPECTED PROFITS OR SAVINGS, OR FOR ANY CLAIMS MADE BY A
THIRD PARTY.
(i)
10.Changes
DEGT reserves the right to change, suspend or discontinue any aspect of the Customer Interface
or the Web site, without prior notice or liability. In the event this action is required DEGT shall
provide notice with reason to Customer for such action.
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July 14 2004
11.Contingency
If for any reason the Website or the Customer Interface is not operable, or if DEGT for any
reason expects either to not be operable, for more than a reasonable period of time, then, without
in any way limiting the provisions of paragraph 9 above and the disclaimers and limits of
liability set out, DEGT may, without obligation or liability, notify you or your agents of an
alternate means of conducting business with and obtaining information from DEGT.
12.Indemnity
You agree to indemnify DEGT and hold DEGT harmless for all actions, damages, expenses, fees
(including, without limitation, legal fees and amounts paid in settlement) and liabilities
whatsoever incurred by DEGT in connection with use of the Customer Interface and the Website
by you, your agents or any person using an identification and password authorized pursuant to
this Agreement.
13.Notice
Any notice which DEGT is permitted or required to give in connection with this Agreement, the
Website or the Customer Interface must be given in accordance with the Tariff.
14.Governing Law
This Agreement will be interpreted in accordance with the laws ofthe Province of British
Columbia and the laws of Canada applicable therein.
15.Entire Agreement
This Agreement constitutes the entire agreement ofthe parties relating to the subject matter
hereof, and there are no repres~ntations or warranties made by either party other than those
contained herein.
16.urement
, ,
This Agreement will be binding on, and enure to the benefit of, the parties hereto and their
respective successors and permitted assigns.
17.Assignment
You shall not transfer or assign all, or any part, of this Agreement without the prior written
consent DEGT.
18.Waiver
A waiver of rights by you or DEGT in respect of a failure by the other party to this Agreement to
perfonn an obligation under this Agreement will not be construed as a waiver of rights in respect
of any continuing or subsequent failure to perform such obligation or as a waiver of rights in
respect of the performance of any other obligation under this Agreement.
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19.Amendment
Excepting changes to the schedules made by DEGT, no amendment, alteration or waiver of any
provision of this Agreement shall be binding upon either you or DEGT unless the same is
effected in writing and executed by each of you and DEGT.
IN WITNESS WHEREOF the parties hereto have signed this Agreement as ofthe date shown on
page 1.
WESTCOASTENERGY INC., carrying on
business as DUKE ENERGY GAS
TRJ\~S~ISSIO~Jda4o
CUSTOMER ~AME
By: L-
RW"'!.f t:L fl Ct /'1
By: /4/ 1'10/'1 i~,. Ie/'
~/lc:u7e/" I /JI.L"Cf' J;j7f/(J p~"c;.;;'uy'1S
Gary C. Weilinger
Vice President, Duke Energy Gas Transmission
President, BC Pipeline and Field Services DivisIons
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SCHEDULE A
CUSTOMER INTERFACE
The CustomerInterface may be used only for the following purposes:
(a)to submit and maintain nominations for gas, in accordance with the Tariff;
(b)to receive messages and reports on the status of nominations;
(c)
(d)
to generate and view Customer specific reports;
to bid on available capacity in accordance with Article 9 ofthe Tariff;
(e)to view available site maps;
(f)to view available service;
(g)
(h)
to receive notifications, and other communications from DEGT
to notify DEGT of the Reported Volume of residue gas delivered for the account
Customer/Shipper at ~he outlet of a Processing Plant or at a Receipt Point in Zone 3 or
Zone 4, or a correction in such Reported Volume, all in accordance with Section 6.05 of
the Tariff;
(i)by DEGT to deliver to each Customer/Shipper or its agent, such reports for such
Customer/Shipper as DEGT may from time to time select; and.
(j)
DEGT communications including among other items, nominations, statements,
authorizations, constraints, priority interruptions, and heat values.
(k)To list on the electronic bulletin board ("EBB") for reviewing by other Shippers, the Finn
Service Contract Demand that Shippers have indicated are available to others or that
Shipper requires from others for assignment on Westcoast Zones 3 & 4 and Westcoast
Alberta Zones A, B or C.
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Westcoast
Energy
SCHEDULE B
CUSTOMER OPERATING ENVIRONMENT REQUIREMENTS
Hardware/Software Requirements
The minimum hardware/software requirements to effectively use the Customer Interface should
be at or greater than the following specifications:
Pentium 100 Computer.
64MB of RAM.
Minimum of 800X600 screen resolution, 256 colours.
56kb or faster connection to the Internet.
Vendor supported versions of Microsoft Internet Explorer with popup blocker disabled, or
configured, as per the instructions on the Customer Interface s Troubleshooting Guide for
RGTIPIant Data (http://inoms. wei-pipeline.com/wei-html/companvinfo/RGT PD/troubleshootinq.shtml)
Internet Service Provider
Customer is responsible for obtaining and maintaining, at Customer s own expense, a
subscription through an Internet Service Provider (ISP) in Customer s own area in order to attain
an Internet access account.
Adobe Acrobat Reader
A vendor supported version of Adobe Acrobat Reader is required to view a report as a .PDF file.
As long as it is available for download uom the vendor, the Acrobat Reader link can be accessed
uom the Pipeline and Field Services Website. Presently there is no charge for the Adobe
Acrobat Reader however this is subject to change without notice.
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July 14 2004
SCHEDULE C
CUSTOMER ADMINISTRATOR
Please type or print below
Date:1- 2~
--
tJ~Circle one~HANGE / DELETE
Customer Information
Customer Name:
.~ /
../--CtCt 0 lJi#el'~tJ~ /1
Customer Address:
Street /22/ Vr/. Ic/c;.ho
City
lJt.1 ;::Se I 720
Sd-
Province
Postal Code ~ 5'/02-DUNS #()t) ,-
(;q
2- 727 /
Please indicate Customer s business association with Duke Energy
Shipper ~eceipt Point Operator 0 By-Product Marketer Transporter 0 Shipper Capacity EBB 0
Customer Information Services & Technology Support
Name j)q tic Cl vJ ci rvI Cl r'I Phone Numbet 2()f - Jfif - 5"'t
Customer Administrator Information
Th~ Customer Administrator will be the main contact person for you regarding the Customer
Interface and the only person authorized by you to request additional passwords or deletions. Please
keep your Customer Administrator identification and password confidential. The sharing of this ID is
not pennitted. The Customer Administrator may be an Agent of the Customer. The Agent must be a
corporate or partnership entity. "
" "' ,
Name V&i"'CltA,c:h~aVl Company "Iclaho N()Jtr (!OW-'pQ,A
Agent: Yes: No: * If yes, please complete Schedule D attached
Position ;;o./Jsach~ SfJf'6o Phone Number 20J"- 3!i? .s6 2(.
Department ?o w-i' (u.-p jl t!IJ'-'rD h :.w,S
DcJI ~ ...J.wo.t';1 .J;CIc.t,"/'M/U, ccJv1-t Mail Address Fax Number 20 F - J S' g- --5-
User r;r Requested: . C ~ II. h..cl Password: DC () ~as z,S,
Vtt-1.t
---
'-../ neo-)\2_~4';J
Signature of Officer
Name of Officer: tf/1/'tWr1 ~f'I.e/'
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July 2004
All Shippers: #06-054Date: 04/6/06Time: 09:45 MST
To:All Shippers
Subject:Jackson Prairie Storage Service Open Season Results
Northwest received binding precedent agreements for its incremental storage service at
Jackson Prairie that totaled 104 000 Dth/d of finn deliverability capacity and the
associated 1.2 TBtu of storage working gas capacity. The parties and the capacity that
were awarded the incremental storage are as follows:
Terasen Gas
Cascade Natural
Idaho Power
Boeing Company
233 Dth
000 Dth
267 Dth
500 Dth
The weighted average contract tenn for the above awarded capacity is 31.18 years.
Northwest plans to file an application with FERC for authorization to provide the
incremental storage services concurrently with an application for authorization to
construct and operate the proposed Jackson Prairie withdrawal expansion project.
The incremental storage service at Jackson Prairie will help Northwest to continue
providing cost effective and reliable finn service for the growing needs of its customers
in the Pacific Northwest " says Allison Bridges , vice president of commercial operations
If you have any questions please contact Mike Rasmuson at [phone] or Jeff
Leishman at [phone].
PRECEDENT AGREEMENT
FOR INCREMENTAL FIRM STORAGE SERVICE
AT JACKSON PRAIRIE
This Precedent Agreement for increm~~t~ firm storage service at Jackson Prairie
("Agreement") is made and entered into thist'~day of February 2006, by and between
Northwest Pipeline Corporation Delaware corporation ("Northwest"and
Yd",-\"o I~ WJr Cc.'W\f(;'I"al1. 3C!dAQ corporation "Shipper
).
Northwest and
Shipper also are sometimes referred to individually as "Party" and collectively as the "Parties
WITNESSETH:
WHEREAS, Northwest owns and operates an interstate natural gas transmission system.
subject to the jurisdiction of the Federal Energy Regulatory Commission ("FERC"
WHEREAS, the Jackson Prairie Storage Project ("Jackson Prairie ) is jointly owned by
Northwest, Avista Corporation and Puget Sound Energy, Inc. ("Puget") and is operated by Puget
under FERC jurisdiction;
WHEREAS, a phased expansion of storage gas capacity at Jackson Prairie commenced in
2002, as authorized in Docket No. CP02-384 ("Capacity Expansion ), feir up to 10.5 Bcf (6.3 Bcf
working gas plus 4.2 Bcf cushion gas), and at current development rates the Capacity Expansion
is assumed to be completed by late 2010;
WHEREAS , Northwest anticipates that Puget, as Jackson Prairie operator, will seek
FERC authorization to construct and operate Jackson Prairie expansion facilities to increase finn
withdrawal capacity by 300 MMcfi'd effective on or about November 1 , 2008 ("Deliverability
Expansion
WHEREAS, Northwest, as a one-third owner of Jackson Prairie holds the rights for 2.
Bcf of the on-going phased storage working gas capacity from the Capacity Expansion and 100
MMcf/d of the anticipated Deliverability Expansion;
WHEREAS, Northwest intends to utilize the fIrst approximately 0.93 Bcf of its 2.1 Bcf
share of the storage working gas capacity from the Capacity Expansion for system balancing. ,
operations and currently anticipates that such additional system balancing capacity will be fully
developed by about year-end 2006;
WHEREAS, subject to issuance and acceptance of all necessary FERC approvals
Northwest desires to utilize its 100 MMcf/d (104 MDthld) share of the anticipated Deliverability
Expansion ("Deliverability ), along with the last approximately 1.17 Bcf (1.2 TBtu) of its 2.
Bcf share of the storage working gas capacity from the Capacity Expansion ("Capacity"), to
provide incremental firm storage service at Jackson Prairie under Rate Schedule SGS-2F;
WHEREAS, Northwest initiated an Open Season on February 1 2006, soliciting binding
film commitments for its contemplated new incremental finn storage service at Jackson Prairie;
and
WHEREAS, in response to the Open Season, Shipper requests incremental fmn storage
service from Northwest as set forth herein.
NOW, THEREFORE, in consideration of the mutual covenants and agreements herein
contained, and subject to all of the tenns, conditions and provisions herein set forth, Northwest
and Shipper do hereby agree as follows:
ARTICLE I
FIRM STORAGE SERVICE COMMITMENTS
1.1 Shipper agrees to electronically request and execute a Rate Schedule SGS-2F storage
service agreement in the fonn approved by the FERC and reflecting' the phased fmn storage
service tenns and conditions described herein and on Exhibit A hereto within fifteen days after
notification by Northwest that the authorized fonn of service agreement for such storage service
is available in Northwest Passage.
1.2 Northwest agrees to timely pursue the FERC certificate and/or tariff authorizations
necessary to establish and provide the incremental film storage service described herein, and
Shipper agrees to support Northwest's applications to FERC for such authorizations.
The Parties agree that the Deliverability contract demand component of the incremental
finn storage service for Shipper, as set forth on Exhibit A, will be available the later of
November 1 , 2008 , or the in-service date of the anticipated 300 MMcf/d Deliverability
Expansion at Jackson Prairie. The Parties further understand and agree that, prior to availability
of such Deliverability contract demand, Shipper would be able to utilize best-efforts withdrawal
rights under Rate Schedule SGS-2F in conjunction with its fmn Capacity rights.
1.4 The Parties agree that the ratio of Shipper s Deliverability contract demand, as set forth
on Exhibit A, to Northwest's total Deliverability capacity at Jackson Prairie will be used to
detennine Shipper s allocated monthly shares of the total approximately 1.2 TBtu of Capacity at
Jackson Prairie that Northwest proposes to dedicate to incremental finn storage service. The
Parties further agree that allocations of such Capacity to Shipper will commence the later of (i)
February 1 , 2007, (ii) Northwest's receipt and acceptance of all necessary FERC approvals, or
(iii) the completion of the approximately 0.93 Bcf of working gas capacity from the Capacity
Expansion targeted for Northwest's system balancing; and that such allocations will continue on
a monthly basis as the Capacity is developed. Northwest currently assumes that the total 1.2
TBtu of Capacity will be developed at a rate of approximately 20 000 Dth/month from early
2007 through mid-2008 , and at a rate of approximately 30 000 Dth/month thereafter, but the
Parties understand that such rates may vary.
Shipper agrees that the maximum rates approved by the FERC for Northwest's proposed
phased incremental storage service under Rate Schedule SGS-2F will apply to Shipper
~"""'"- -,. "", ", ~
.0""""...
Deliverability contract demand and phased Capacity demands hereunder. Based upon
preliminary facility cost estimates and recent cushion gas cost forecasts, Northwest estimates that
the phased daily rates per Dth of firm Capacity demand will be approximately $0.00272 for
2007, $0.00256 for 2008 , $0.00231 for 2009 and $0.00214 for 2010, and that the initial daily rate
per Dth of Deliverability contract demand will be approximately $0.08420. Northwest estimates
that, effective upon completion of the phased Capacity, the daily rates per Dth for the
incremental Capacity demand and Deliverability contract demand will be approximately
$0.00462 and $0.05392, respectively, reflecting incremental cost recovery equally split between
Deliverability contract demand and Capacity demand consistent with traditional FERC storage
rate design methodology. In its FERC application, Northwest agrees to propose phased rates
based upon updated cost estimates, consistent with the phased Capacity development, for the
incremental storage service hereunder.
Shipper agrees that the maximum rates approved by the FERC for best-efforts withdrawal
service for Northwest's proposed incremental storage service under Rate Schedule SGS-2F will
apply to Shipper s storage withdrawals. Northwest agrees to propose that such rate will be
equivalent to the Rate Schedule SGS:"2F demand charge for non-incremental service (i.e.
cUlTently, $0.01689 per Dth) and that such rate will apply only during the period between
commencement of the phased Capacity availability and the in-service date of the Deliverability
Expansion.
Shipper agrees that the fuel use reimbursement factor approved by the FERC for
Northwest's proposed incremental service under Rate Schedule SGS-2F will apply to Shipper
injections of storage gas hereunder. Northwest agrees to propose that such fuel use
reimbursement factor will be the same factor that applies to non-incremental Rate Schedule
SGS-2F service.
If the posted Open Season procedures result in Northwest awarding a level of
Deliverability contract demand to Shipper that is less than Shipper s initially requested level as
set forth on Exhibit A, Shipper agrees that Exhibit A will be deemed amended to reflect the
awarded incremental Deliverability contract demand level upon Northwest's formal notice to
shipper of the awarded quantity.
ARTICLE II
CONDITIONS PRECEDENT
The Parties understand and agree that the firm storage service commitments set forth in
Article I are expressly contingent upon satisfaction of all of the following conditions precedent:
(a) Puget, as Jackson Prairie operator, seeking and receiving acceptable FERC
authorization to construct and operate the Deliverability Expansion;
(b) Northwest receiving binding commitments in the Open Season that in aggregate
cover 100 percent of the offered incremental storage service;
(c) Northwest obtaining approval no later than March 31 , 2006, from its Management
Committee and, if required, from The Williams Companies, Inc. Board of Directors to
participate as an equal owner in the contemplated De1iverabi1ity Expansion to offer the
incremental storage service as proposed; and
(d) Northwest receiving and accepting all necessary FERC certificate and/or tariff
approvals to provide the offered incremental storage service.
ARTICLE III
TERMINATION
Northwest may terminate this Agreement upon 10 days written notification to Shipper in
the event the conditions precedent set forth in Article II are not aU satisfied by July 1 2007.
3.2 This Agreement will terminate on the date of execution of the Rate Schedule SGS-
service agreement contemplated by Section 1.1. Thereafter, the Parties ' rights and obligations
related to the incremental firm storage service described herein shall in all respects be subject to
the terms and conditions of such service agreement and Northwest's tariff, as either or both may
be modified.
ARTICLE IV
OTHER AGREEMENTS
It is expressly agreed by the Parties that the execution of this Agreement, and the
colTesponding rights and obligations of the Parties hereunder, are without prejudice to any
additional rights or obligations which Northwest and Shipper may have to each other under any
existing separate and distinct agreements.
ARTICLE V
SUCCESSION AND ASSIGNMENT
Any entity which will become a successor to this Agreement by purchase, merger or
consolidation will be entitled to the rights and will be subject to the obligations of its predecessorin interest under this Agreement.
Northwest and/or Shipper may, without relieving itself of its obligations under this
Agreement, assign this Agreement to any entity or entities with which it is affiliated including
without limitation any wholly owned subsidiary. Otherwise, no assignment of this Agreement or
of any of the rights or obligations hereunder will be effective without the express prior written
consent of the other party, which will not be unreasonably withheld. Shipper acknowledges and
agrees that Northwest may decline to consent to an assignment by Shipper to a party that does
not or cannot demonstrate satisfaction of Northwest's creditworthiness requirements.
ARTICLE VI
NO THIRD PARTY BENEFICIARIES
This Agreement will not create any rights in any third parties, and no provision will be
construed as creating any obligations for the benefit of, or right in favor of, any person or entity
other than Northwest or Shipper.
ARTICLE VII
NOTIFICATIONS AND COMMUNICATIONS
7.1 Except as otherwise provided herein, any notice contemplated or required by this
Agreement will be in writing and will be considered duly delivered when sent by registered or
certified mail, or by facsimile, to the appropriate party at the appropriate address set forth below
or at such other address as Northwest or Shipper may from time to time designate by express
written notice.
Northwest:Northwest Pipeline Corporation
295 Chip eta Way
Salt Lake City, UT 84108
Fax No.: [phone]
Attn: Mike Rasmuson or Jeff Leishman
Marketing Services
Shipper (company name)
(address line 1)
(address line 2)
(fax no.
(contact name)
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127. \
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ARTICLE VIII
SEPARATE CLAUSES
8.1 Each clause is separate from other clauses. If any clause or provision of this Agreement
be deemed invalid, the remaining clauses and provisions will remain in full force and effect.
ARTICLE IX
ENTIRE AGREEMENT
This Agreement contains the entire agreement between the Parties with respect to the
subject matter hereof, and supersedes any and all prior agreements, understandings and
commitments, whether oral or written; concerning the subject matter hereof, and any and all such
prior agreements, understandings and commitments are hereby deemed to be void and of noeffect.
No amendments to or modifications of this Agreement will be effective unless agreed
upon in a written instrument executed by the Parties, which expressly refers to this Agreement.
ARTICLE X
GOVERNING LAW
10.. The construction, interpretation, and enforcement of this Precedent Agreement will be
governed by the laws of the State of Utah, notwithstanding any conflict of law rules, which
would refer any matter to the laws of a jurisdiction other than the State of Utah.
IN WITNESS WHEREOF, the parties hereto have caused this Agreement to be duly
executed as of the day and year first above written.
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NORT 'ION
By:
AllIson Bridges
Vice President, Commercial Operations af;~~B I"J
Shipper Name.
Na e: :::fOtMt:J' C. J11; lit'
Tiile
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51", I//c'?r(J.); cle.,.. R,u/-u S~fJ
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EXHIBIT A
PRECEDENT AGREEMENT FOR INCREMENTAL FIRM STORAGE SERVICE
DATED FEBRUARY ?-ii'2006
BETWEEN NORTHWEST AND SHIPPER
Deliverability Contract Demand:
The lesser of , 2-t l Dthld or the quantity awarded by Northwest to Shipper, starting the
later of November 1 , 2008 or completion of the Deliverability Expansion.
(Note: Deliverability Contract Demand can not exceed 104 000 Dthld.
Storage Capacity Demand:
Phased Capacity dedicated to incremental firm storage service will be allocated to Shipper every
month as it is developed, but commencing no earlier than February 1 , 2007.' Such allocations
will be pro rata based on the shipper s share of the maximum 104 000 Dthld of Deliverability
contract demand and will continue until the approximately 1.2 TBtu of Capacity has been
allocated to incremental storage customers.
Primary Term End Date: ),r::.v. I with the standard bi-Iateral SGS-2F evergreen
. .
provISIOn.
(Note: Termination date cannot be earlier than October 31 2028.
Rate:
Shipper will pay the maximum incremental reservation rates approved by FERC for
Deliverability contact demand and Capacity demand and will pay the best-efforts withdrawal
charge approved by FERC for any storage withdrawals scheduled prior to the in-service date for
the Deliverability contract demand.
AMEND MENT #2
Contract #126951
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THIS AMENDMENT is made and entered into this 16th day of December 2003, by
and between Northwest Pipeline Corporation (Transporter) and Idaho Power Company (Shipper).
WHEREAS , Transporter and Shipper are parties to that certain finn transportation agreement
(#126951) dated August 2 2001 , as amended November 21 2001 , (Agreement);
WHEREAS, Transporter and Shipper desire to amend the Agreement to remove certain
provisions that are inconsistent with recent Commission precedents disallowing non-confonning
contract provisions concerning early tennination rights and delivery pressure obligations; and
WHEREAS, Transporter and Shipper also desire to revise Exhibit "C" ofthe Agreement to
more fully describe the methodology for adjustment/true-up ofthe annual Facility Reimbursement
Charge.
NOW, THEREFORE, the parties hereto agree as follows:
The existing language contained in paragraph 2.1 (b) of the Agreement shall be replaced by
the following:
(b) ill recognition of Shipper s obligation to pay the Delivery Facilities Cost-of-
Service Charge set forth in Exhibit "c" hereto, the Maximum Currently Effective
Tariff Rates ptherwise applicable under Section 2.1(a) will be discounted to the
Minimum CUlTently Effective Tariff Rates so long as Shipper is paying the Facilities
Cost-of-Service Charge as set forth in Exhibit "c" attached. However, such
discounts will not apply whenever, and to the extent, Shipper (or any replacement
shipper) utilizes receipt and/or delivery points that are not located on the Delivery
Facilities. If in any rate proceeding the FERC requires an allocation of additional
costs (excluding any such costs that are covered by the Facilities Cost-of-Service
Charge) to transportation service under this Agreement, the previously applicable
discount rate will no longer apply and this Agreement will be concurrently amended
to establish a new rate discount calculated to recover all direct and allocated costs
deemed attributable by the FERC to service under this Agreement. Further, in the
event that Shipper exercises its right under Transporter s tariff to cease paying the
Delivery Facilities Cost-of-Service charge, the previously applicable discount rate
will no longer apply and this Agreement will be concurrently amended to establish a
new rate discount calculated to recover all direct and allocated costs included in the
fonner Delivery Facilities Cost-of-Service charge for operation and maintenance
administrative and general and general items.
2. Both the existing Exhibit B and the Exhibit B revised by Amendment dated November 21
2001 to become effective concUITently with the effective date of Amendment #2 to Contract #
126442 shall be superseded and replaced with the attached Exhibit B'
The existing Exhibit C shall be superseded and replaced with the attached Exhibit
4. This Amendment shall be binding upon and inure to the benefit of the parties hereto and their
respective successors and assigns.
5. This amendment shall be effective as of the date hereof. In all other respects, the tenns and
provisions of the Agreement shall remain in full force and effect.
IN WITNESS WHEREOF, the parties hereto have executed two duplicate original copies of
this Amendment to be effective as of the date and year first written above.
IDAHO POWER CO~ ANY NORTHWEST PIPELINE CORPORATION
By: By:Name: Karl Bokenkamp Name: Mike Rasmuson
Title: General Manager, Power Supply Planning Title: Manager, Marketing Services
Primary Delivery Point
Elmore Meter Station
EXHIBIT "
to the
TRANSPORTATION AGREEMENT
DATED AUGUST 2nd, 2001
(As Amended December 16, 2003)
between
NORTHWEST PIPELINE CORPORATION
and
IDAHO POWtR COMPANY
DELIVERY POINTS
Maximum Daily
Delivery Obligation
MDDO"
for each
f!mtl
MDDO
Pressure
(PSi2)
500 390
EXHIBIT "
to the
SERVICE AGREEMENT
DATED August 2 2001
(As Amended December 16, 2003 to be effective concuITently with the effective
date of Amendment #2 to Contract #126442)
between
NORTHWEST PIPELINE CORPORATION
and
IDAHO POWER COMPANY
DELIVERY POINTS
Maximum Daily
Delivery Obligation
MDDO"
for each
Primary
Delivery Point
MDDO
(Dth)
Pressure
(psig)
--------------------------------
Elmore Meter Station 977 390
EXHIBIT "
to the
TRANSPORTATION AGREEMENT
DATED AUGUST 2nd, 2001
(As Amended December 16 2003)
between
NORTHWEST PIPELINE CORPORATION
and
IDAHO POWbR COMPANY
FACILITY REIMBURSEMENT OBLIGATION
DESCRIPTION OF NEW FACILITIES:
The new Delivery Facilities contemplated by Section 1 (b) of the Rate ScheduleTF-which are necessary to provide service under this Agreement are set forth in more detail in the
Facilities Agreement between Shipper and Transporter, dated August 2nd, 2001 (the "FacilitiesAgreement"), and include the following:
Dual taps on the 22" and 24" mainlines
200-feet of 16-inch lateral
Meter station at the delivery point
RESPONSIBILITY FOR NEW FACILITY COST:
The total estimated reimbursable cost ofthe Delivery Facilities is $1 893 682, withan estimated annual cost-of-service (the "Cost-of-Service ) charge of $419 054. Pursuant to Section
21 ofthe General Tenns and Conditions of Transporter s FERC gas Tariff, Shipper is responsible to
pay for the actual Cost-of-Service for the new Delivery Facilities described above and has elected the
payment option set forth below.
TERMS AND CONDITIONS OF COST -OF -SERVICE CHARGE:
Type of Charge: Annual
Charge: $419 054 for the first year and adjusted annually thereafter in accordance
with the following:
The annual Cost-of-Service charge will be adjusted and trued up annually to reflect
actual costs incurred by Transporter, using the methodology set forth in Attachment "A" tothis Exhibit.
Tenn of Charge:30- years from the in-service date
ATTACHMENT A
Regulatory Policies and Rate-Making True-up Principles
General Principles
The calculations are consistent with the methodologies underlying Northwest's cun-entlyeffective
transportation rates as established in its last rate case. These principles can only be changed in future
general rate proceedings.
The "true-up period" is a calendar year (or partial year if the Agreement is effective for only a
portion of a particular calendar year). The "billing period" is the twelve months ending March 31.
Prior to the conclusion of the billing period, the difference between the actual cost of service and
the amount billed during the true-up period will be invoiced or credited as a lump sum. An
estimated annual Facility Charge will be calculated for the next billing period.
Operation and Maintenance Expense
Direct O&M costs related to the Delivery Facilities are accumulated in a cost center or are allocated
using a gross i:ransmission plant factor. Supervisory and system control costs included in Account
Nos. 850, 851 , 852 and 861 are allocated to the Delivery Facilities using a gross transmission plant
allocation factor.
A&G costs are allocated in accordance with Kansas Nebraska KN'methodology. The KN
methodology utilizes plant and direct labor factors. Labor related A&G costs are allocated based
upon direct labor factors for the true-up period and plant-related A&G costs are allocated based on
gross direct plant at the end of the period.
Depreciation Expense
Direct depreciation expense is calculated on a straight-line rate over the 30-year life of the Delivery
Facilities.
Indirect depreciation expense includes general and intangible plant depreciation that is allocated
based on a ratio of gross direct plant for the Delivery Facilities to total system gross direct plant at
the end of the true-up period.
Ad Valorem and Other Taxes
Ad Valorem taxes are based upon the most recent tax bills applicable to the county where the
Delivery Facilities are located applied to the average net plant.
Payroll taxes are allocated upon the ratio of direct labor to total system direct labor for each true-up
period.
Other taxes such as state franchise taxes and state sales and use taxes, as applicable, are allocated
based upon the ratio of gross direct plant for the Delivery Facilities to total system gross direct plantat the end of the true-up period.
Federal and State Income Taxes
Federal and State income tax expenses are based upon the current income tax rates and the taxable
portion of return in effect during the true-up period.
Return
Return on debt and equity and the applicable capital structure are based upon the last litigated or
settled general rate case where the components are stated. See "Changes Resulting ITom General
Rate Filing" section below for return treatment for newly filed rate cases.
Rate Base
Rate base is comprised of direct and indirect plant and is the net of gross plant investment
accumulated depreciation and accumulated deferred income taxes related to the Delivery Facilities.
Rate base is calculated using the average of all months in the true-up period plus the last month of
the prior true-up period, if applicable.
Gross direct plant investment is based upon actual costs incurred for installation of the Delivery
Facilities. New capital expenditures will be added to gross direct plant investment when incucred.
To the extent that the gross direct plant investment has not been fully depreciated prior to the
expiration of Exhibit C to the Transportation Agreement, the remaining net book value of the
facilities, including any related income taxes, will be billed as part of the final true-up calculation.
Indirect rate base includes an allocation of general items (general plant, intangible plant, materialsand supplies and prepayments). Each of the general items is the average of all months in the true-up
period plus the month immediately preceding the true-up period. Indirect rate base is assigned to theDelivery Facilities based upon the ratio of gross direct plant for the Delivery Facilities to total system
gross direct plant at the end of the true-up period.
Donations
Donations are allocated to the Delivery Facilities based upon the ratio of direct labor to total systemdirect labor for each true-up period.
Carrying Costs
Carrying costs are calculated using the interest computed in confonnance with FERC regulations
ITom the date of each collection through the date ofthe refund or billing, as applicable.
Audit Rights
Northwest will make its accounting records and workpapers available for audit or review at its
offices during a six-month period after the true-up calculation is invoiced. Infonnation will be
considered correct if not challenged during that time period.
Changes Resulting from General Rate Filings
Changes may be made to the principles underlying Northwest's currently effective transportation
rates in Northwest's general rate proceedings.
The Commission s final detennination on all principles decided by litigation or settlement of each
general rate case will be reflected in the true-up calculation.
All changes to rate making principles that may be made in Northwest's general rate cases pertinent to
the computation of the true-up cost of service for the Delivery Facilities will be reflected in the next
applicable billing period and in Northwest's true-up calculations for all applicable periods reflecting
such retroactive or prospective changes, as required under the tenns of the Commission s order.
True-up calculations will reflect the basis for the adjustment for any under-collections or over-
collections, including interest computed in confonnance with FERC regulations ITom the date of
each collection through the date ofthe payment or refund in the next applicable true-up calculation.
During each billing period, final rates of return on debt and equity and capital structure applicable to
any portion ofthe annual true-up period covered by final base tariff rates will be used. To the extent
that any portion or all of the annual true-up period falls during a subj ect to refund period wherein the
Commission has not finally resolved the applicable rates of return on debt and equity and capital
structure, initial billings will be based on the rates of return on debt and equity and capital structure
included in Northwest's subject to refund base tariff rates.
If the applicable rate of return on debt or equity, or the capital structure components are subsequently
modified due to any final Commission order in a general rate proceeding, the difference between thecost of service previously billed under the subject to refund rates for return on debt and equity and
capital structure and the cost of service developed by applying the Commission s final order for theapplicable time periods will be refunded or billed during the next applicable true-up calculation.
Such refund or billing will include interest computed in confonnance with FERC regulations ITom
the date of each collection through the date of the refund or billing.
ALvIENDMENT # 1
CONTRACT #126951
THIS Al\1ENDMENT is entered into this 21~l day of November, 2001, by and betweenNORTHWEST PIPELIN~ CORPORATION (Northwest), hereinat1er referred to as
Transporter , and IDAHO POWER COMPA1"N, hereinafter referred to as ..Shipper.
'")"-.
Transporter and Shipper are parties to that certain Service Agreement (# 126951) dated
August 2, 2001 ("Service Agreement").
Transporter and Shipper desire to amend the Service Agreement to provide for areduction in Contract Demand from 61 500 Dth t-O 36 977 Dth concurrently with theeffective date of .A.1nendment #2 to contract #126442.
AGREEMENT:
NOW THEREFORE~ in consideration of the premises and mutUal covenaJ.1ts containedherein, the parties agree as follows:
The Transportation Contract Demand set forth in Artic.le 1.1 of the ServiceAgreement shall be "977 Dths/day" in place of"61,500 Dths/day.
Exhibits "A" and "Bot of the Service Agreement shall be deleted ill their entiretyand the attached Exhibits "A" apd "E" shall be added to and made a part of the
Service Agreement.
This Amendment shall be effective concurrently with the effective date of
Amendment #2 to contract #126442.
Except as amended herein, the Service Agreement shall remain in full force andeffect.
This Amendment shall b~ binding upon and inure to the benefit of the partieshereto and any successors or assigns or such parties.
This Amendment may be executed in any number of counterparts.
IN 'MTNESS WHEREOF , the parties hereto have executed two duplicate original copies
of this Amendment as of the date and year first written above.
IDAHO POWER COMPANY (Shipper)
By' IS/ KARL BOKENlCAJ\1P
KARL B 0 KENKAt\.fP
MANAGER, THEIDiL~ PRODUCTION
NORTHWEST PIPELINE CORPORA nON (Transporter)
By' /S/ IAN CALDW""ELL
1AN CALDWELL
MAi'l'AGER, TRAl'ISPORTATION & rvIARKETING SERVICES
EXHIB IT
to the
SERVICE AGREElVfENT
DATED August 2, 2001
(As Amended Effective concucrently with the effective
date of Amendment #2 to Contract #126442)
between
NORT~ST ~WE~ CORPORATION
and
IDAHO POWER COIyfP ANY
RECEIPT POINTS
PrimarY
Receipt Point
__n__-
Elmore Lateral In-Line Transfer Point 2/
Primary Ma.ximum
Daily
Receipt Point
Quantity (!vIDQ) 1/
---
977
1/ TIle MDQ must equal the total Transportation Contract Demand as set forth in Section 1.
2/ The ElInore Lateral In~Line Transfer Point is the point of interconnection between the 16"
Elmore Lateral and Northwest's Sumas to Ignacio 22" mainline and 24" lbopline.
-~----
EXHIBIT li
to the
SERVICE AGREEMENT
DATED August 2, 2001
(As Amended Effective ,concurrently with the effective
date of Amendment #2 to Contract #126442)
between
NORTHWEST PIPEL~1S CORPORATION
and
IDAHO POWER COMPANY
DELNER Y POINTS
Ma:rimUID Daily
Delivery Obligation
MDDO"
for each
Primary :tvIDDO
Pressure
(Dth)
(psig)
Delivery Point
----~--
Elmore Meter Station 390 **977
** In the event the hourly peak volume for deliveries under all agreements at this point exceeds
562 Dth's during any 24-hour period, the delivery pressure of 390 psig cannot be guaranteed
for such gas day.
CONTRACT# 126951
SERVICE AGREEMENT
(APPLICABLE TO RATE SCHEDULE TF-
THIS AGREEMENT is made and entered into this 2nd day of August, 2001 , by and
between NORTHWEST PIPELINE CORPORATION (hereinafter referred to as "Transporter
and IDAHO POWER COMPANY (hereinafter referred to as "Shipper
RECITALS:
Shipper is a developer and generator of electric power, and is developing an
electric generating facility to be located in Elmore County, Idaho (the "Plant
Shipper owns certain supplies of natural gas which it desires Transporter to
transport for Shipper s account pursuant to Part 284 of the regulations of the
Federal Energy Regulatory Commission ("FERC"
Shipper has requested service to a new delivery point, which requires new taps on
Transporter s 22" and 24" mainlines; construction of a 16" lateral line, and a
meter station situated at the Plant's delivery point (the "Delivery Facilities
Transporter and Shipper are parties to that certain Facilities Agreement datedAugust 2nd, 2001, which provides for the design, construction, ownership,
operation and maintenance of the Delivery Facilities by Transporter.
Shipper desires to reserve all of the capacity of the Delivery Facilities pursuant to
the tenDS hereof.
AGREEMENT:
NOW, THEREFORE, in consideration of the premises and mutual covenants set forth
herein, the parties agree as follows:
1.1
ARTICLE I - GAS DELIVERIES AND REDELIVERIES
Subject to the tenus, conditions and limitations hereof, Transporter agrees to
receive from Shipper at the Receipt Point(s) specified in Exhibit(s) "A" herein
transport and deliver to Shipper at the Delivery Point(s) specified in Exhibit(s)
B" herein, the following quantities of natural gas, known as the "Transportation
Contract Demand"
Up to 61 500 Dths/day, provided that Transporter s receipt of gas at any Receipt
Point for Shipper s account hereunder on any gas day shall not exceed the
Maximum Daily Quantity ("MDQ") set forth for such Receipt Point on Exhibit
A" hereto, and provided that Transporter s gas daily obligation to deliver gas to
Shipper at any Delivery Point under this Transportation Agreement shall not
exceed the Maximum Daily Delivery Obligation ("MDDO") set forth on Exhibit
. These MDQ and MDDO'1imitations apply only to primary point volumes
and not to alternate point volumes.
1.2 Fuel gas shall be provided in-kind as specified in Rate Schedule TF -1 and in theGeneral Terms and Conditions of Transporter s Federal Energy RegulatoryCommission ("FERC") Gas Tariff (the "Tariff'
1.3 Such transportation shall be on a finn basis.
ARTICLE II - TRANSPORTATION RATES AND CHARGES
(a) Shipper agrees to pay Transporter for all natural gas transportation service
rendered under the tenns of this Agreement in accordance with Transporter s RateSchedule TF-l (Large Customer) as filed with FERC (the "Rate Schedule ), andas such rate schedule may be amended or superseded ITom time to time.
(b) In recognition of Shipper s obligation to pay the Delivery Facilities Cost-of-
Service Charge set forth in Exhibit "C" hereto, the Maximum CUlTently Effective
Tariff Rates otherwise applicable under Section 2.I(a) will be discounted to the
Tariff's Minimum Currently Effective Tariff Rates as long as Shipper is paying
the Facilities Cost-of-Service Charge set forth in Exhibit C attached. However
such discounts will not apply whenever, and to the extent, Shipper (or anyreplacement shipper) utilizes receipt and/or delivery points that are not located on
the Delivery Facilities. Further, in the event that subsequent to the execution date
of this Agreement, FERC requires an allocation of non-Delivery Facilities' costs(excluding any such costs that are covered by the Facilities Cost-of-ServiceCharge) to transportation service under this Agreement the otherwise applicable
discounts hereunder will tenninate. In that event, Shipper will have the right to
tenninate this Agreement and transfer its Cost-of-Service Charge reimbursementobligations to Transporter to replacement or superceding service agreements as
contemplated in Section 21.3( d) of the Tariff. However, in the event that Shipper
does not exercise such right to tenninate this Agreement, during the periodbetween any such FERC order requiring such cost allocation and the effective
date of the allocation, this Agreement may be amended, at Shipper s option, toeither reduce the Transportation Contract Demand or to provide for a new rate
discount, which shall be calculated to ensure Transporter has an opportunity to
recover all such allocated costs.
3.4
2.2 This Agreement shall be subject to the provisions of the Rate Schedule and the
General Terms and Conditions of the Tariff applicable thereto (and as they may
be amended by Article VIII of this Agreement) and effective from time to time
which by this reference are incorporated herein and made a part hereof.
ARTICLE III - GOVERNMENTAL REQUIREMENTS
Shipper shall reimburse Transporter for any and all filing fees actually incurred by
Transporter in seeking governmental authorization for the initiation, extension ortennination of service under this Agreement.
The transportation contemplated herein shall be provided by Transporter pursuant
to Section 284.223 ofthe FERC's regulations.
3.3 Upon termination, this Agreement shall cease to have any force or effect, save as
to any unsatisfied obligations or liabilities of either party arising hereunder prior
to the date of such tennination, or arising thereafter as a result of such
tennination. Provided, however that this provision shall not supersede any
abandonment authorization which may be required.
Shipper hereby acknowledges and agrees that either it or its buyer or seller of
natural gas supplies to be transported to the Plant by means of the Delivery
Facilities is the "importer of record" and it will comply with all requirements for
reporting and submitting payment of duties, fees, and taxes to the United States or
agencies thereof to be made on imported natural gas and for making thedeclaration of entry pursuant to 19 CFR Section 141.19. Shipper agrees toindemnify and hold Transporter hanDless from any and all claims of damage or
violation of any applicable laws, ordinances and statutes to the extent such claims
of damage arise in connection with the importation of the gas to be transported
hereunder and which claims require reporting and/or filing of fees in connection
therewith.
ARTICLE IV - TERM
This Agreement becomes effective upon the in-service date of the DeliveryFacilities and shall remain in full force and effect for an initial tenn of thirty (30)
years from that in-service date, and year-to-year thereafter. Either party may
terminate this Agreement at the expiration of the Initial Primary Tenn or upon
any anniversary thereafter by giving twelve months prior written notice to the
other party, provided however, that if Northwest wishes to tenninate this
Agreement with Shipper at the expiration of the Initial Primary Tenn or upon any
anniversary thereafter, and upon FERC approval, Northwest shall pennit Shipper
the first right of refusal under the procedures as set forth in Northwest's Tariffeven though Shipper is not paying the maximum rate.
ARTICLE V - WARRANTY OF ELIGIBILITY FOR TRANSPORTATION
Shipper warrants for itself, its successors and assigns, that all gas delivered to
Transporter for transportation hereunder shall be eligible for transportation in
interstate commerce under applicable rules, regulations or orders of the FERc.
Shipper will indemnify Transporter and save it hannless from all suits, actions
damages, costs, losses, expenses (including reasonable attorney fees) and
regulatory proceedings, to the extent such suits, actions, damages, costs, losses
and expenses arise ITom Shipper s breach of such warranty.
ARTICLE VI - NOTICES
Unless herein provided to the contrary, any notice called for in this Agreement
shall be in writing and shall be considered as having been given if delivered
personally, or by mail or facsimile, with confirmation of receipt requested, with
all postage and charges prepaid to either Shipper or Transporter at the address
designated below. Routine communications shall be considered as duly delivered
if mailed by ordinary mail. Nonnal operating instructions can be made by either
party by telephone. Unless changed, the addresses of the parties are as follows:
NORTHWEST PIPELINE CORPORATION
O. Box 58900
Salt Lake City, Utah 84158-0900
Statements-
Payments-
Attention: Transportation and Marketing Services
Attention: Treasury Services
IDAHO POWER CONW ANY
Attention: Mr. Peter Stewart
O. Box 70
Boise, Idaho 83707
ARTICLE vn - OTHER OPERATING PROVISIONS
NONE
ARTICLE VTII - ADJUSTMENTS TO GENERAL TERMS AND CONDITIONS
NONE
ARTICLE IX - CANCELLATION OF PRIOR AGREEMENT(S)
NONE
11.1
11.2
11.3
ARTICLE X - SUCCESSORS AND ASSIGNS
10.Any Company which shall succeed by purchase, merger, or consolidation to the
properties, substantially as an entirety, of Shipper, or of Transporter, as the case
may be, shall be entitled to the rights and shall be subject to the obligations of its
predecessor in title under this Agyeement; and either Shipper or Transporter may
assign or pledge the Agreement under the provisions of any mortgage, deed of
trust, indenture, bank credit agreement, assignment, receivable sale, or similarinstrument which it has executed or may execute hereafter; otherwise, neither
Shipper nor Transporter shall assign this Agyeement or any of its rights hereunder
unless it first shall have obtained the consent thereto in writing of the other;
provided further, however, that neither Shipper nor Transporter shall be released
ITom its obligations hereunder without the consent of the other, which consentshall not be unreasonably withheld. As between the parties hereto, suchassignment shall become effective on the first day of the month following written
notice that such assignment has been effectuated.
ARTICLE XI - MISCELLANEOUS
In the event of a conflict between this Agyeement and the Tariff, the tenns of this
Agyeement shall control subject to FERC approval.
This Agyeement and Exhibits A, B and C attached hereto, applicable provisions of
Northwest's tariff, and the applicable Facilities Agyeement incorporated herein by
reference; represent the final expression of the understanding between the Parties
with respect to the subject matter hereof and is the complete and exclusive
statement of the tenns hereof. No prior or contemporaneous oral or written
representations or communications between the Parties or their representatives
course of dealing, or trade usage shall be deemed to modify the wording thereof
of be used in interpreting or construing the meaning of the intent hereof.
The invalidity or unenforceability of any tenn or provision of this Agyeementshall not affect the validity or enforceability of any other tenns or provisions of
this Agyeement and this Agreement shall be construed in all other respects as if
the invalid or unenforceable tenn or provision was omitted.
IN WITNESS WHEREOF, the parties hereto have executed this Agreement as of the day
and year first above set forth.
IDAHO POWER COMPANY
By: ISI
Name: John P. Prescott
Title: Vice President Power Supply
NORTHWEST PIPELINE CORPORATION (Transporter)
By: _/SI
Name: J. Douglas Whisenant
Title: Sr. Vice President and General Manager
EXHIBIT "
to the
TRANSPORTATION AGREEMENT
DATED AUGUST 2nd, 2001
between
NORTHWEST PWELThffi CORPORA TIDN
and
IDAHO POWER COMPANY
RECEWT POINTS
Primary
Maximum Daily
Receipt Point
Quantity (MDQ)
Elmore Lateral In-line Transfer Point 2/500 Dth'
1/ The MDQ must equal the total Transportation Contract Demand as set forth in Section 1.1.
2/ The Elmore Lateral In-line Transfer Point is the point of interconnection between the 16"
Elmore Lateral and Northwest's Surnas to Ignacio 22" mainline and 24" loopline.
EXHIBIT "
. to the
TRANSPORTATION AGREEMENT
DATED AUGUST 2nd, 2001
between
NORTHWEST PIPELINE CORPORATION
and
IDAHO POWER CO~ ANY
DELIVERY POINTS
Maximum Daily
Delivery Obligation
MDDO"
for each
Primary Delivery Point MDDO Pressure
Elmore Meter Station 500 Dth'390 **
** In the event the hourly peak volume exceeds 2 562 Dth's during any 24-hour period, the delivery
pressure of 390 psig cannot be guaranteed for such gas day.
EXHIBIT "
to the
TRANSPORTATION AGREEMENT
DATED AUGUST 2nd 2001
between
NORTHWEST PIPELINE CORPORATION
and
IDAHO POWER COMPANY
FACILITY REIMBURSEMENT OBLIGATION
DESCRIPTION OF NEW FACILITIES:
The new Delivery Facilities contemplated by Section 1(b) of the Rate Schedule
TF -, which are necessary to provide -service under this Agreement are set forth in more detail inthe Facilities Agreement between Shipper and Transporter, dated August 2nd 2001 (theFacilities Agreement"), and include the following:
Dual taps on the 22" and 24" mainlines
200-feet of 16-inch lateral
Meter station at the delivery point
RESPONSIBILITY FOR NEW FACILITY COST:
The total estimated reimbursable cost of the Delivery Facilities is $1 893 682with an estimated annual cost-of-service (the "Cost-of-Service ) charge of $419,054. Pursuant
to Section 21 of the General Terms and Conditions of Transporter s FERC gas Tariff, Shipper is
, responsible to pay for the actual Cost-of-Service for the new Delivery Facilities described above
and has elected the payment option set forth below.
TERMS AND CONDITIONS OF COST-OF-SERVICE CHARGE:
Type of Charge: Annual
Charge: $419 054 for the first year and adjusted annually thereafter in accordance
with the following:
The annual Cost-of-Service charge will be re-determined annually to reflect actual
costs incurred by Transporter, using rate calculation methodologies underlying
Transporter s currently effective transportation rates and, for purposes of the
depreciable life of the Delivery Facilities, the term of the Cost-of-Service charge
specified in paragraph 3 (c) below. The annual true-up re-determination will also
include any other un-recovered costs associated with repairs, and/or any
modifications that are required to be made to the Delivery Facilities by
Transporter as a result of any laws, rules, regulations and orders of any duly
constituted authority having jurisdiction thereof. Transporter will notify Shipper
of any such true-up re-detenninations and will provide such supporting
infonnation as is reasonably requested by Shipper to verify any adjustment to the
Cost-or-Service Charge.
Tenn of Charge:30- years ITom the in-service date
- Contract 126442 Amendment 3 Nv.Jf ~'fU\-, Page 1 of 3
~f piJl'l-f. J ~ S).-~
AMENDMENT # 3
CONTRACT # 126442
THIS AMENDMENT is entered into this 8th day of April, 2003, by and between NORTHWEST PIPELINE
CORPORATION (Northwest), hereinafter referred to as "Transporter , and IDAHO POWER COMPANY, hereinafter
referred to as "Shipper.
1. Transporter and Shipper are parties to that certain Service Agreement (# 126442) dated March 22, 2001 ("Service
Agreement
The parties agree to amend Exhibit B to remove the non-conforming footnote.
AGREEMENT:
NOW THEREFORE, in consideration of the premises and mutual covenants contained herein, the parties agree as
follows:1. The amended Exhibit B of the Service Agreement established by Amendment#2 to the Service
Agreement shall be replaced in its entirety by the Exhibit B attached to this Amendment effective upon the in-service date of
the facilities proposal in Docket No. CPOI-438-000.
Except as amended herein, the Service Agreement shall remain in full force and effect.3. This Amendment shall be binding upon and inure to the benefit of the parties hereto and any successors or
assigns or such parties.
This Amendment may be executed in any number of counterparts.
IN WITNESS WHEREOF, the parties hereto have executed two duplicate original copies of this Amendment as of
the date and year first written above.
IDAHO POWER COMPANY (Shipper)
By /S/
KARL BOKENKAMP
GENERAL MANAGER, POWER SUPPLY PLANNING
NORTHWEST PIPELINE CORPORATION (Transporter)
By /S/
MIKE RASMUSON
MANAGER, MARKETING SERVICES
, , "...,...
"...r.r.
Contract 126442 Amendment 3
Primary Delivery Point
ELMORE METER STATION
TOTAL:
Page 3 of 3
EXHIBIT B
to the
SERVICE AGREEMENT
DATED March 22, 2001
(As Amended April 8,2003)
between
NORTHWEST PIPELINE CORPORATION
and
IDAHO POWER COl\t1PANY
DELIVERY POINTS
Maximum Daily
Delivery Obligation
MDDO"
for each
MDD
24523
Pressure (psi g)
390
24523
. . uv" "..."" A
Contract 126442 Amendment 2 Page 1 of
AMENDMENT # 2
CONTRACT # 126442
TillS AMENDMENT is entered into this 26th day of November, 2001, by and between NORTHWEST PIPELINE
CORPORATION (Northwest), hereinafter refeITed to as "Transporter , and IDAHO POWER COMPANY, hereinafter
refeITed to as "Shipper.
1. Transporter and Shipper are parties to that certain Transportation Agreement (# 126442) dated March 22, 2001
Transportation Agreement2. The parties agree to amend Exhibit "B" of the Transportation Agreement to change the Kern River Muddy Creek
delivery point to the Elmore delivery point.
AGREEMENT:
NOW THEREFORE, in consideration of the premises and mutual covenants contained herein, the parties agree as
follows:1. Unless precluded by order of the Federal Energy Regulatory Commission, Exhibit "B" of the
Transportation Agreement shall be deleted in its entirety and the attached Exhibit "B" to this Amendment shaIl be added to
and made a part of the Transportation Agreement effective upon the in-service date of the facilities proposal in Docket No.
CPO1-438-000.
Except as amended herein, the Transportation Agreement shall remain in full force and effect.3. This Amendment shall be binding upon and inure to the benefit of the parties hereto and any successors or
assigns or such parties.
This Amendment may be executed in any number of counterparts.
IN WITNESS WHEREOF, the parties hereto have executed two duplicate original copies of this Amendment as of
the date and year first written above.
IDAHO POWER COMPANY (Shipper)
By ISI KARL BOKENKAMP
KARL BOKENKAMP
MANAGER, POWER SUPPLY PLANNING
NORTHWEST PIPELINE CORPORATION (Transporter)
By ISI IAN CALDWELL
IAN CALDWELL
MANAGER, MARKETING SERVICES
1 . "...,., "..."" .
Contract 126442 Amendment 2 Page 2 of 2
EXHIBIT "
to the
TRANSPORTATION AGREEMENT
DATED March 22, 2001
(As Amended November 26 2001)
between
NORTHWEST PIPELINE CORPORATION
and
IDAHO POWER COMPANY
DELIVERY POINTS
Maximum Daily
Delivery Obligation
MDDO"
for each
Primary Delivery Point
ELMORE DELIVERY MIS
MDDO
24523
Pressure (psig)
390**
TOTAL:24523
** In the event the hourly peak volume for deliveries under all agreements at this point exceeds 2 562 Dth's during any 24-
hour period, the delivery pressure of 390 psig cannot be guaranteed for such gas day.
11/,..."",..."".
Contract 126442 Amendment Page 1 of 3
AMENDMENT
TillS AMENDMENT is entered into this 18th day of May, 2001, by and between NORTHWEST
PIPELINE CORPORATION, hereinafter refelTed to as ATransporter(Q), and IDAHO POWER COMPANY
hereinafter refelTed to as AShipper. (Q)1. Transporter and Shipper are parties to those certain service agreements #126442, with a contract demand
of 20,452 Dths per day, and #126443, with a contract demand of 4 071 Dths per day, both dated March 22, 2001(AService Agreements
(g)).
2. Shipper desires to consolidate the Service Agreements and to incorporate unilateral tennination rights
for Shipper.
AGREEMENT:
NOW THEREFORE, in consideration of the premises and mutual covenants contained herein, the parties
agree as follows;
1. The maximum Transportation Contract Demand set forth in Section 1.1 of the Service Agreement
#126442 shall be increased from 20,452 Dth/day to 24 523 Dthlday.
2. Exhibits "A" and "B" of the Service Agreement #126442 shall be deleted in their entirety and the
attached Exhibits "A" and "B" to this Amendment shall be added to and made a part of the Service Agreement
#126442.
3. The second sentence of Section 4.1 of the Service Agreement #126442 is replaced by the
following sentence: "Shipper shall have the sole option to tenninate this Agreement at the expiration of the initial
tenD or upon any anniversary thereafter by giving twelve months prior written notice to Transporter.
This Amendment supercedes, cancels and tenninates Service Agreement #126443.
Except as amended herein, the Service Agreement #126442 shall remain in full force and effect.6. This Amendment shall be binding upon and inure to the benefit of the parties hereto and any
successors or assigns or such parties.
This Amendment may be executed in any number of counterparts. '
IN WITNESS WHEREOF, the parties hereto have executed two duplicate original copies of thisAmendment as of the date and year first written above.
IDAHO POWER COMPANY (Shipper)
By /S/
Karl Bokenkamp
Manager, Power Supply Planning
NORTHWEST PIPELINE CORPORATION
(Transporter)
By /S/
Jan M. Caldwell
Manager, Marketing Services
EXIDBIT "
to the
1 , ".." '~"n .
, Contract 126442 Amendment
SERVICE AGREEMENT
Dated March 22,2001
(As Amended May 18 2001)
between
NORTHWEST PIPELINE CORPORATION
and
IDAHO POWER CONW ANY
RECEIPT POINT
Primary Receipt Point
SUMAS RECEIPT
Page 2 of 3
Maximum Daily Quantity (MDQ)
523
TOTAL:24,523
..,~~,~~~.
. Contract 126442 Amendment
EXIllBIT "
to the
SERVICE AGREEMENT
Dated March 22 2001
(As Amended May 18,2001)
between
NORTHWEST PIPELINE CORPORATION
and
IDAHO POWBR CO~ ANY
DELIVERY POINT
Primary Delivery Point Maximum Daily Delivery
Obligation (MDDO)
523KERN RIVER MUDDY
CREEK DELIVERY
TOTAL:523
ill The total of the MDQ' s must equal total transportation contract demand as set forth in Section 1.1
Page 3 of
Pressure (psi g)
450
-."--"----
Contract 126442 Amendment 0 Page 1 of 7
#126442
JRANSPORT ATION AGREEMENT
(APPLICABLE TO RATE SCHEDULE TF-
THIS AGREEMENT is made and entered into this 22nd day of March, 2001, by and between NORTHWEST
PIPELINE CORPORATION, hereinafter referred to as "Transporter , and IDAHO POWER COMPANY, hereinafter
referred to as "Shipper
RECITALS:
Shipper is an end user of natural gas.
B. Shipper owns certain supplies of natural gas which it desires Transporter to transport for Shipper s account
pursuant to Part 284 of the regulations of the Federal Energy Regulatory Commission ("FERC"
C. Shipper is a prearranged replacement shipper pursuant to the General Terms and Conditions of Transporter s FERC
Gas Tariff ("Tariff') and is acquiring 20,452 Dths per day of Permanently Released Capacity from the Sumas receipt point to
the Kern River Muddy Creek delivery point formerly held under a Transportation Agreement (100108) dated March 9, 1993,
between Transporter and WEI Holdings (U.) Inc..
AGREEMENT:
NOW, THEREFORE, in consideration of the premises and mutual covenants set forth herein, the parties agree as
follows:
ARTICLE I - GAS DELIVERIES AND REDELIVERIES
Subject to the terms, conditions and limitations hereof, Transporter agrees to receive from Shipper at the Receipt
Point(s) specified in Exhibit(s) "A" herein, transport and deliver to Shipper at the Delivery Point(s) specified in Exhibit(s)
B" herein, the following quantities of natural gas, known as Transportation Contract Demand:
Up to 20,452 DthJday provided that Transporter s receipt of gas at any receipt point for Shipper s account
hereunder on any day shall not exceed the maximum daily volume set forth for such receipt point on Exhibit "A" hereto, and
provided that Transporter s daily obligation to deliver gas to Shipper at any delivery point under this Transportation
Agreement shall not exceed the Maximum Daily Delivery Obligation ("MDDO") set forth in Exhibit "B" of this Agreement.
1.2 Fuel gas shall be provided in-kind as specified in Rate Schedule TF - 1 and in the General Terms and Conditions
of this Federal Energy Regulatory Commission ("FERC") Gas Tariff.
1.3 Such transportation shall be on a firm basis.
ARTICLE II - TRANSPORTATION RATES AND CHARGES
Shipper agrees to pay Transporter for all natural gas transportation service rendered under the terms of this
...------.
" Contract 126442 Amendment 0 Page 2 of 7
Agreement in accordance with Transporter s Rate Schedule TF-l (Large Customer) as filed with the Federal Energy
Regulatory Commission ("FERC"), and as such rate schedule may be amended or superseded from time to time;
This Agreement shall be subject to the provisions of such Rate Schedule and the General Terms and Conditions
applicable thereto (and as they may be amended by Article Vill of this Agreement) and effective from time to time, which by
this reference are incorporated herein and made a part hereof.
ARTICLE ill- GOVERNMENTAL REQUIREMENTS
Shipper shall reimburse Transporter for any and all filing fees to be incurred by Transporter in seeking
governmental authorization for the initiation, extension or termination of service under this Agreement.
3.2 The transportation service contemplated herein shall be provided by Transporter pursuant to Section 284.223 of the
FERC regulations.
Upon termination, this Agreement shall cease to have any force or effect, save as to any unsatisfied obligations or
liabilities of either party arising hereunder prior to the date of such termination, or arising thereafter as a result of such
termination. Provided, however that this provision shall not supersede any abandonment authorization which may be
required.
3.4 (Section 3.4 shall be applicable only for the transportation of imported natural gas.) Shipper hereby acknowledges
and agrees that either it or its buyer or seller is the "importer of record" and it will comply with all requirements for reporting
and submitting payment of duties, fees, and taxes to the United States or agencies thereof to be made on imported natural gas
and for making the declaration of entry pursuant to 19 CPR Section 141.19. Shipper agrees to indemnify and hold
Transporter harmless from any and all claims of damage or violation of any applicable laws, ordinances and statutes which
pertain to the importation of the gas transported hereunder and which require reporting and/or filing of fees in connection
with said import.
ARTICLE IV - TERM
This Agreement becomes effective November 1,2002 and shall remain in full force and effect through February
, 2007, and year to year thereafter. Either party may terminate this Agreement at the expiration of the initial term or upon
any anniversary thereafter by giving twelve months prior written notice to the other party.
ARTICLE V - WARRANTYOFELIGmn..ITYFOR TRANSPORTATION
Any shipper under this Rate Schedule warrants for itself, its successors and assigns, that all gas delivered to
Transporter for transportation hereunder shall be eligible for transportation in interstate commerce under applicable rules
regulations or orders of the FERC. Shipper will indemnify Transporter and save it harmless from all suits, actions, damages
costs, losses, expenses (including reasonable attorney fees) and regulatory proceedings, arising from breach of this warranty.
ARTICLE VI - NOTICES
, Contract 126442 Amendment 0 Page 3 of 7
6.1 Unless herein provided to the contrary, any notice called for in this Agreement shall be in writing and shall be
considered as having been given if delivered personally, or by mail or telegraph with all postage and charges prepaid to eitherShipper or Transporter at the place designated. Routine communications shall be considered as duly delivered when mailed
by ordinary mail. Normal operating instructions can be made by telephone. Unless changed, the addresses of the parties are
as follows:
NORTHWEST PIPELINE CORPORATION
O. Box 58900
Salt Lake City, Utah 84158-0900
Statements - Attention: Marketing Services
Payments - Attention: Treasury Services
IDAHO POWER COMPANY
1221 West Idaho Street
O. Box 70
Boise, ill 83707
Attention: Marty Patterson
ARTICLE VII - OTHER OPERATING PROVISIONS
NONE
ARTICLE VIII - ADmSTMENTS TO GENERAL TERMS AND CONDITIONS
NONE
ARTICLE IX - CANCELLATION OF PRIOR AGREEMENT(S)
When this Agreement takes effect, it supersedes, cancels and terminates the following agreement(s):
Transportation Agreement (100108) dated March 9,1993, as amended, between Transporter and WEI Holdings
(U.) Inc..
ARTICLE X - SUCCESSORS AND ASSIGNS
10.This Agreement shall be binding upon and inure to the benefit ofthe parties hereto and their respective successors
and assigns. No Assignment or transfer by either party hereunder shall be made without written approval of the other party.
Such approval shall not be unreasonably withheld. As between the parties hereto, such assignment shall become effective on
the first day of the month following written notice that such assignment has been effectuated.
_"_.0___,
" Contract 126442 Amendment 0 Page 4 of 7
IN WITNESS WHEREOF, the parties hereto have executed this Agreement as of the day and year first above set forth.
IDAHO POWER COMPANY (Shipper)
BY IS!MARTYPATTERSON
NORTHWEST PIPELINE CORPORATION (Transporter)
BY IS! IAN CALDWELL
Manager, Marketing Services
'-'--'-~-'
. Contract 126442 Amendment 0 Page 5 of 7
EXHIBIT "
to the
TRANSPORTATION AGREEMENT
DATED March 22, 2001
between
NORTHWEST PIPELINE CORPORATION
and
IDAHO POWER CORPORATION
RECEIPT POINTS
Primary
Receipt Point
Maximum Daily
Quantity (MDQ)
------------------------------------
SUMAS RECEIPT 20,452
The MDQ must equal total transportation contract demand as set forth in Section 1.1.
, Contract 126442 Amendment 0
Primary
Delivery Point
-------------------
KERN RIVER MUDDY CREEK DELIV.
Page 6 of 7
EXHIBIT "
to the
TRANSPORTATION AGREEMENT
DATED March 22, 2001
between
NORTHWEST PIPELINE CORPORA nON
and
IDAHO POWER CaMP ANY
DELIVERY POINTS
Maximum Daily
Delivery Obligation
MDDO"
for each
MDDO Pressure
(Dth)(psig)
-------------
20,452 450
SPECIAL LANGUAGE
to the
. - .-- 0- - - .
, '..
Contract 126442 Amendment 0 Page 7 of 7
TRANSPORTATION AGREEMENT
DATED March 22, 2001
between
NORTHWEST PIPELINE CORPORATION
and
IDAHO POWER COMPANY
None
__'__0___-
IDAHO POWER COMPANY
CASE NO. IPC-O6-
FIRST PRODUCTION REQUEST
OF COMMISSION STAFF
RESPONSE TO
REQUEST NO. 32
$1
1
.
$1
0
.
$9
.
$8
.
$7
.
$6
.
$5
.
$4
.
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.
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s

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e
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$2
.
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0
6
1
R
P
-2
0
0
4
1
R
P
20
0
2

~2
0
0
0

IR
P
IDAHO POWER COMPANY
GAS PRICE COMPARISON SLIDE
ii';ifY~Jrt%~f~~~~~()(lgJ1BPJ,~0;~~J0!f);l&aqpJ~'8R'\\~;iliti~\~1'!~~i12J).()~J(iR~iti;i)iiJjii'/;?:~:iiil~laQ'.("~I1,;f~~~~:l\
2006
2007
2008
2009
2010
2011
2012
2013 3.45
2014 6.42
2015
2016 4.49
2017
2018 7.49
2019
2020
2021
2022
2023 5.42
2024
2025
IDAHO POWER COMPANY
CASE NO. IPC-O6-
FIRST PRODUCTION REQUEST
OF COMMISSION STAFF
RESPONSE TO
REQUEST NO. 33
Please see Response to Request No. 33
Some of the information requested in Request No. 33
is CONFIDENTIAL only that information which is
not CONFIDENTIAL will be provided to Mountain
View Power
Idaho Power Company
Danskin CT OperationfHedging Guidelines
Draft - June 24, 2002
The purpose of these guidelines is to establish a set of parameters for the Power Supply
Planning group to use in making mid to long-term fuel purchases and power sale
decisions associated with the Danskin Combustion Turbines. These decisions will be
lumped into two categories, (1) IPC system is short and (2) IPC system is long.
IPC System is Lonl!
If we buy gas, we sell power to hedge the gas purchase.
$2/MWh net margin is required to enter into a transaction.
Since the system is long, the net margin must include any third party
transmission charges necessary to complete the sale.
For Example, if transmission to Mid-C is $2.50/MWh and the spark spread for
the CT's is $4.50/MWh or better, we buy gas and sell power.
Power Supply Planning will monitor system positions and spark spreads
regularly & transactions will be executed when the above criteria is satisfied.
If third-party transmission is necessary to actually deliver the energy (to Mid-
C for example), and if we are reasonably confident that this transmission will
be available, then we will not purchase the transmission initially. This
provides us an opportunity to reverse the transaction without actually
purchasing the third-party transmission.
If power can be purchased and gas can be sold to offset the power sale and gas purchase
and preserve the margin, then we will enter into those transactions. The CT will then be
available to repeat the process.
Possible margins
(g)
$2/MWh net margin:Flat sale 730 hours x 90 MW x $2/MWh = $131k
HL sale 730 hours x 90 MW x 0.57 (HL fraction) x $2/MWh = $75k
IPC System is Short
If we buy gas, we do not need to enter into a corresponding power sale. The
system s short position hedges the gas purchase.
Since the system is short, we are purchasing energy and most likely incurring
transmission charges to get that energy to the system. In this instance, we
would not incur those transmission costs if we run the CT.
$O/MWh net margin (breakeven) is required to enter into a transaction.
For example, if we are purchasing (or would expect to be purchasing) from
Mid-C and paying $2.50/MWh transmission and the spark spread is greater
than -$2.50/MWh, then we buy gas and plan to run the CT.
IDAHO POWER COMPANY
CASE NO. IPC-O6-
FIRST PRODUCTION REQUEST
OF COMMISSION STAFF
RESPONSE TO
REQUEST NO. 51
Please see Response to Request No.
The information requested is CONFIDENTIAL and
is not provided to Mountain View Power