20040528Responses of Avista to Potlatch.pdf

Avista Corp.
1411 East Mission PO Box 3727
Spokane, Washington 99220-3727
Telephone [phone]
Toll Free 800-727-9170
f')Nt. . t" .. U
. t t
..', . ".. .
(~1 ~~~'V'STAe
Corp.
May 27 2004
ZUU4 t1fA,28 Ait1 9:
,it; t"'UBL \C
TlL t T \ E g-; C Ot1~11SS1Ut~
Conley E. Ward
GIVENS PURSLEY LLP
601 W. Bannock Street
PO Box 2720
Boise, ill 83701-2720
Re:Production Request of Potlatch Corporation
in Case Nos. A VU-04-01 and A VU-04-
Mr. Ward
I have attached one copy of Avista s response to Potlatch Data Request No.(s) 27, 34
34(C), 38, 46A, 50, and 57.
If you have any questions, please call me at [phone] or Don Falkner at (509) 495-
4326.
Mike Fi
Rate Analyst
Enclosures
Cc:s. Woodbury
D. Peseau
A. Yanke!
(IPUC)
(Utility Resources, Inc.
(Yankel & Assoc, Inc.
JURISDICTION:
CASE NO:
REQUESTER:
TYPE:
REQUEST NO:
REQUEST:
VISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMATION
Idaho
A VU-04-0l / A VU-04-
Potlatch
Data Request
DATE PREPARED:
WITNES S
RESPONDER:
DEP ARTMENT:
TELEPHONE:
5/18/2004
Bill Johnson
Bill Johnson
Power S uppl y
[phone]
Please specify the monthly average energy output of CS2 (Avista share) from July 2003
to January 15 , 2004. Also provide monthly capacity factors of CS2.
RESPONSE:
Please see attached worksheet.
vista Corp.
Coyote Springs 2 Generation, Availability Factor and Capacity Factor
July 2003 through January 15, 2004
Available Availability Capacity
Hours Generation Capacity Factor Factor
MWh
Jul-744 85,654 137.95.100 84%
Aug-744 824 137.100.00%93%
Sep-720 78,589 139.87.290 78%
Oct-745 68,566 142.99.770 65%
Nov-720 24,473 142.64.31 %24%
Dec-744 25,711 144.99.660 240
Jan-360 26,592 144.95.250 51%
CS2 Gen Cap Factor, Potlatch No. 27.xls
Potlatch DR No.
Case No. A VU-04-
5/27/2004 WGJ
VISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMATION
JURISDICTION:
CASE NO:
REQUESTER:
TYPE:
REQUEST NO.
Idaho
A VU-O4-01 / A VU-O4-
Potlatch
Data Request
DATE PREPARED:
WITNES S
RESPONDER:
DEP ARTMENT:
TELEPHONE:
5/25/2004
Lafferty
Lafferty
Energy Resources
[phone]
REQUEST:
Please provide in Excel-usable format details of all hedging activity by transaction conducted by
Avista Utilities in the time frame April 1 , 2000-December 31 2001 , including for each
transaction: the date transactions were entered, the terms and type of hedge, and the broker and
counterparty.
RESPONSE:
The requested materials are being provided with A vista s data response to Potlatch, number
34(C). The materials provided contain TRADE SECRET or CONFIDENTIAL information
and are separately filed under IDAPA 31.01.01, Rule 067, and Section 9-340D, Idaho Code.
Cr
i
t
i
c
a
l

H
y
d
r
o

C
o
n
d
i
t
i
o
n
s

-
-

20
0
3

L
i
g
h
t

L
o
a
d

H
o
u
r

S
u
r
p
l
u
s

(
D
e
f
i
c
i
t
)
Wi
t
h

L
o
a
d

V
a
r
i
a
b
i
l
i
t
y

-
-

90
0
1
0

an
d

95
0
/
0

Co
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
s
Mo
n
t
h
l
v

A
..
.
.
-.
:
:
('
)II.
.
Il.
.
::
J C/)
IU
U
60
0
50
0
:~
~
40
0
30
0
20
0
./
10
0
10
0
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
Se
p
Oc
t
No
v
De
c
AV
E
""
'
-
2
0
0
3

L
L
H

Su
r
p
l
u
s

(
D
e
f
i
c
i
t
)

C
r
i
t
i
c
a
l
4~
6
48
8
50
6
51
1
27
7
17
6
17
3
24
5
+9
0
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
on
e
-
ta
l
l

t
e
s
t
11
9
13
4
11
7
12
6
44
9
52
1
55
7
55
4
29
0
10
1
21
8
22
1
28
4
+9
5
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
.

o
n
e
-
ta
l
l

t
e
s
t
14
0
14
9
12
6
13
9
45
2
53
0
57
2
56
7
29
4
10
7
23
0
23
5
29
5
90
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
.

o
n
e
-
ta
l
l

t
e
s
t
42
3
45
5
45
5
46
8
26
4
13
4
12
5
20
6
95
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
.
o
n
e
-
ta
l
l

t
e
s
t
42
0
44
6
44
0
45
5
26
0
12
2
11
1
19
5
~
~

L

0

Z

0

~
L

L

~

~

~

~

L

0

Z

0

~
L

L

~

~

~

~

L

0

Z

0

~
L

L

~

~

~

~

L

0

Z

0

~
L
~
~

~

~

~

~
~

~

3
~

~

~

~

~

~

~

~
~

~

~

3
~

~

~

~

~

~

~

~
~

~

~

3
~

~

~

~

~

~
~

~
~

~

~
a
a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a
a

a

a

a

a

a

a

a

a
~
~

~

~

~

~

~

~

~

~

~

~

~

~

~

~

~

~

~

~

~

~

~

~

~

~

~

N

N

N

N

N

N

N
N

N

N

N

N

~

~

~

~

~

~
::J
LS
:
~
:
T
Q)
-
c
::
:
:
s

"
"
C
:

.
.
,

I
"
a
a

a

II
)
~
~

~

~
~
~

~

~

~

~

~

~

~

~

~

~

~

~

~

~

~

~

~

~

~

~

~

~

~

~

~

~

~

~

~

~

~

~

~

~
~

~

~

~

~

~

~

~
N
N

~

N

~

ID

I
D

I
D

I
D

I
D

I
D

I
D

N

~
~

N

~

a

a

a

a

~

~

a

N

~

m

m

~

~

~

~

~

~

~

~

00

N

~
~

N

~

~

~
~
~

~

N

a

ID

I
D

I
D

m

~
N

00

a

0
0

a
m

~

~

~

~

a

00

m

N

~
m

~

a

a

ID

0
0

a

I
D

m
~

~

m

N

ID

m

~

~
~

~
a
~

~

~

~

~

~

00

0
0

~

0
0

m

a
~

~

~

~

~

~

00

0
0

~

0
0

mo
m

m

N
~

~

00

~

a
a

~

a

a

a

a

a

a

~

a

a
a
a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a

a
a

a

a

a

a

a

a

a
c
z
en

~
~

~
~
~

:..
.
.

'
3

~
N
~

N
00

.
.
N
N

~
~
c
a
a

a
c
~
en

--

(
"
)
3:

0
en

--

3
3:

I
I
)
en

--

"
s:
:

~
(I)
CY

V
I
s:
:
en

II)
~
5
'
..,..,
.-+..
,
-c

C
::
!
.

g
.
..
,
~
~
(ir
.-+:::
:
s
..
,
""
C
:
Natural Gas Quotes from Avista Energy
Aoril 6. 2001
Sumas Rockies
US/Mmbtu US/Mmbtu
NYMEX AECO
Month/Locatic US/Mmbtu US/Mmbtu
May-01 5.3880
Jun-01 5.4410
Jul-01 5.4840
Aug-01 5.5150
Sep-01 5.4950
Oct-01 5.5020
Nov-01 5.6240
Dec-01 5.7370
Jan-02 5.7720
Feb-02 5.5870
Mar-02 5.2420
Apr-02 4.7120
May-02 4.5800
Jun-02 4.5850
Jul-02 4.6120
Aug-02 4.6190
Sep-02 4.5990
Oct-02 4.5990
Nov-02 4.7140
Dec-02 4.8190
Jan-03 4.8490
Feb-03 4.6760
Mar-03 4.4360
Apr-03 4.1660
May-03 4.1110
Jun-03 4.1240
Jul-03 4.1340
Aug-03 4.1640
Sep-03 4.1640
Oct-03 4.1640
Nov-03 4.2740
Dee-03 4.3940
Jan-04 4.4340
Feb-04 4.3140
Mar-04 4.0320
Apr-04 4.1260
May-04 4.0710
Jun-04 4.0840
Jul-04 4.0940
Aug-04 4.1240
Sep-04 4.1240
Oct-04 4.1240
Nov-04 4.2340
Dec-04 4.3540
Jan-05 4.4640
Feb-05 4.3440
Mar-05 4.0620
Apr-05 4.1560
Malin
US/Mmbtu
Natural Gas Quotes from Avista Energy
April 17, 2001
NYMEX AECO
Month/Locatic US/Mmbtu US/Mmbtu
May-01 5.2480
Jun-01 5.3030
Jul-01 5.3580
Aug-01 5.3980
Sep-01 5.3930
Oct-01 5.4110
Nov-01 5.5460
Dec-01 5.6730
Jan-02 5.7230
Feb-02 5.5450
Mar-02 5.2250
Apr-02 4.7250
May-02 4.5800
Jun-02 4.5970
Jul-02 4.6420
Aug-02 4.655Q-
Sep-02 4.6370
Oet-02 4.6450
Nov-02 4.7650
Dee-02 4.8690
Jan-03 4.9000
Feb-03 4.7240
Mar-03 4.4850
Apr-03 4.1750
May-03 4.1090
Jun-03 4.1290
Jul-03 4.1540
Aug-03 4.1790
Sep-03 4.1690
Oct-03 4.1740
Nov-03 4.2840
Dee-03 4.4040
Jan-04 4.4440
Feb-04 4.3240
Mar-04 4.1840
Apr-04 4.0420
May-04 4.0690
Jun-04 4.0890
Jul-04 4.1140
Aug-04 4.1390
Sep-04 4.1290
Oct-04 4.1340
Nov-04 4.2440
Dec-04 4.3640
Jan-05 4.4740
Feb-05 4.3540
Mar-05 4.2140
Apr-05 4.0720
Sumas
US/Mmbtu
Rockies
US/Mmbtu
Malin
US/Mmbtu
Natural Gas Quotes from Avista Energy
April 24, 2001
NYMEX AECO
Month/Locatic US/Mmbtu US/Mmbtu
May-01 5.0780
Jun-01 5.1140
Jul-01 5.1770
Aug-01 5.2320
Sep-01 5.2450
Oct-01 5.2750
Nov-01 5.4200
Dec-01 5.5620
Jan-02 5.6170
Feb-02 5.4620
Mar-02 5.2050
Apr-02 4.7490
May-02 4.6240
Jun-02 4.6520
Jul-02 4.6960
Aug-02 4.7090
Sep-02 4.6940
Oct-02 4.7040
Nov-02 4.8240
Dee-02 4.9340
Jan-03 4.9650
Feb-03 4.8050
Mar-03 4.5760
Apr-03 4.2760
May-03 4.2100
Jun-03 4.2300
Jul-03 4.2550
Aug-03 4.2800
Sep-03 4.2700
Oct-03 4.2750
Nov-03 4.3850
Dee-03 4.5050
Jan-04 4.5450
Feb-04 4.4250
Mar-04 4.2860
Apr-04 4.1160
May-04 4.1700
Jun-04 4.1900
Jul-04 4.2150
Aug-04 4.2400
Sep-04 4.2300
Oct-04 4.2350
Nov-04 4.3450
Dee-04 4.4650
Jan-05 4.5750
Feb-05 4.4550
Mar-05 4.3160
Apr-05 4.1460
Sumas
US/Mmbtu
Rockies
US/Mmbtu
Malin
US/Mmbtu
Natural Gas Quotes from Avista Energy
May 1, 2001
Sumas Rockies
US/Mmbtu US/Mmbtu
NYMEX AECO
MonthlLocatic US/Mmbtu US/Mmbtu
Jun-01 4.6410
Jul-01 4.7080
Aug-01 4.7730
Sep-01 4.8070
Oct-01 4.8450
Nov-01 5.0110
Dec-01 5.1790
Jan-02 5.2410
Feb-02 5.1160
Mar-02 4.9010
Apr-02 4.5250
May-02 4.4350
Jun-02 4.4770
Jul-02 4.5270
Aug-02 4.5590
Sep-02 4.5540
Oct-02 4.5640
Nov-02 4.6990
Dec-02 4.8240
Jan-03 4.8690
Feb-03 4.7150
Mar-03 4.5000
Apr-03 4.2000
May-03 4.1450
Jun-03 4.1750
Jul-03 4.2150
Aug-03 4.2500
Sep-03 4.2480
Oct-03 4.2550
Nov-03 4.3650
Dec-03 4.5000
Jan-04 4.5600
Feb-04 4.4400
Mar-04 4.3010
Apr-04 4.1310
May-04 4.1050
Jun-04 4.1350
Jul-04 4.1750
Aug-04 4.2100
Sep-04 4.2080
Oct-04 4.2150
Nov-04 4.3250
Dec-04 4.4600
Jan-05 4.5900
Feb-05 4.4700
Mar-05 4.3310
Apr-05 4.1610
May-05 4.1350
Malin
US/Mmbtu
Natural Gas Quotes from Avista Energy
May 8, 2001
NYMEX AECO
Month/Locatic US/Mmbtu US/Mmbtu
Jun-01 4.2790
Jul-01 4.3530
Aug-01 4.4250
Sep-01 4.4550
Oct-01 4.4930
Nov-01 4.6730
Dec-01 4.8530
Jan-02 4.9230
Feb-02 4.8030
Mar-02 4.6130
Apr-02 4.2930
May-02 4.2230
Jun-02 4.2650
Jul-02 4.3150
Aug-02 4.3400
Sep-02 4.3450
Oct-02 4.3650
Nov-02 4.5050
Dec-02 4.6350
Jan-03 4.6850
Feb-03 4.5350
Mar-03 4.3470
Apr-03 4.0550
May-03 4.0200
Jun-03 4.0600
Jul-03 4.1100
Aug-03 4.1480
Sep-03 4.1600
Oct-03 4.1700
Nov-03 4.2800
Dec-03 4.4150
Jan-04 4.4730
Feb-04 4.3530
Mar-04 4.2140
Apr-04 4.0440
May-04 3.9800
Jun-04 4.0200
Jul-04 4.0700
Aug-04 4.1080
Sep-04 4.1200
Oct-04 4.1300
Nov-04 4.2400
Dec-04 4.3750
Jan-05 4.5030
Feb-05 4.3830
Mar-05 4.2440
Apr-05 4.0740
May-05 4.0100
Sumas Rockies
US/Mmbtu US/Mmbtu
Malin
US/Mmbtu
Natural Gas Quotes from Avista Energy
May 15, 2001
NYMEX AECO
Month/Locatic US/Mmbtu US/Mmbtu
Jun-01 4.6530
Jul-01 4.7220
Aug-01 4.7850
Sep-01 4.7980
Oct-01 4.8150
Nov-01 4.9800
Dec-01 5.1350
Jan-02 5.1930
Feb-02 5.0580
Mar-02 4.8630
Apr-02 4.4780
May-02 4.3830
Jun-02 4.4230
Jul-02 4.4680
Aug-4.4880
Sep-02 4.4930
Oct-02 4.5000
Nov-02 4.6370
Dec-02 4.7500
Jan-03 4.7920
Feb-03 4.6320
Mar-03 4.4440
Apr-03 4.1010
May-03 4.0510
Jun-03 4.0710
Jul-03 4.1010
Aug-03 4.1410
Sep-03 4.1510
Oct-03 4.1710
Nov-03 4.2810
Dec-03 4.4110
Jan-04 4.4610
Feb-04 4.3410
Mar-04 4.1910
Apr-04 4.0010
May-04 4.0110
Jun-04 4.0310
Jul-04 4.0610
Aug-04 4.1010
Sep-04 4.1110
Oct-04 4.1310
Nov-04 4.2410
Dec-04 4.3710
Jan-05 4.4910
Feb-05 4.3710
Mar-05 4.2210
Apr-05 4.0310
May-05 4.0410
Sumas Rockies
US/Mmbtu US/Mmbtu
Malin
US/Mmbtu
Mid-C Forward Electric Prices Posted 4-10-2001
4/10/2001 4/1/2001 355.287.
4/10/2001 5/1/2001 345.279.
4/10/2001 6/1/2001 422.342.
4/10/2001 7/1/2001 475.380.
4/10/2001 8/1/2001 51 2.409.
4/10/2001 9/1/2001 475.380.
4/10/2001 10/1/2001 349.307.
4/10/2001 11/1/2001 307.270.
4/10/2001 12/1/2001 311.273.
4/10/2001 1/1/2002 290.255.
4/10/2001 2/1/2002 256.225.
4/10/2001 3/1/2002 235.206.
4/1 0/2001 4/1/2002 159.129.
4/1 0/2001 5/1/2002 155.125.
4/10/2001 6/1/2002 190.154.
4/10/2001 7/1/2002 213.171.
4/10/2001 8/1/2002 230.40 184.
4/10/2001 9/1/2002 213.171.
4/10/2001 1 0/1 /2002 139.122.
4/10/2001 11/1 /2002 122.108.
4/10/2001 12/1/2002 124.109.
4/1 0/2001 1/1/2003 130.114.
4/10/2001 2/1/2003 115.101.
4/10/2001 3/1/2003 105.93.
4/10/2001 4/1 /2003 71.58.
4/1 0/2001 5/1/2003 69.56.
4/10/2001 6/1/2003 85.69.
4/10/2001 7/1 /2003 96.76.
4/10/2001 8/1/2003 103.82.
4/10/2001 9/1/2003 85.68.
4/10/2001 1 0/1 /2003 55.49.
4/10/2001 11/1/2003 49.43.
4/10/2001 12/1 /2003 49.43.
4/10/2001 1/1/2004 04.40 91.
4/10/2001 2/1/2004 92.81.
4/10/2001 3/1/2004 84.74.45
4/10/2001 4/1/2004 57.46.
4/10/2001 5/1/2004 55.45.
4/10/2001 6/1/2004 68.45 55.
4/1 0/2001 7/1/2004 76.61.
4/10/2001 8/1/2004 77.62.
4/1 0/2001 9/1/2004 64.51.
4/10/2001 0/1/2004 41.36.
Jun 02 thru Oct 03 126.1 05.
5/26/2004 RJL-WP-
Mid-C Forward Electric Prices Posted 4-11-2001
4/11/2001 4/1/2001 355.287.
4/11/2001-5/1/2001 349.282.
4/11/2001 6/1/2001 415.336.
4/11/2001 7/1/2001 468.374.
4/11/2001 8/1/2001 504.403.
4/11/2001 9/1/2001 468.374.
4/11/2001 10/1/2001 349.307.
4/11/2001 11/1/2001 307.270.
4/11/2001 12/1/2001 311.273.
4/11/2001 1/1/2002 290.255.
4/11/2001 2/1/2002 256.225.
4/11/2001 3/1/2002 235.206.
4/11/2001 4/1/2002 123.129.
4/11 /2001 5/1/2002 94.127.
4/11/2001 6/1/2002 185.151 .
4/11/2001 7/1/2002 258.168.48
4/11/2001 8/1/2002 294.181.
4/11/2001 9/1/2002 258.168.48
4/11/2001 0/1/2002 139.122.
4/11 /2001 11/1/2002 122.108.
4/11/2001 12/1/2002 124.109.
4/11/2001 1/1/2003 130.114.
4/11/2001 2/1/2003 115.101.
4/11/2001 3/1/2003 105.93.
4/11/2001 4/1/2003 55.58.
4/11/2001 5/1/2003 42.57.
4/11/2001 6/1/2003 83.68.
4/11/2001 7/1/2003 116.75.
4/11/2001 8/1/2003 132.81.
4/11/2001 9/1/2003 103.67.
4/11/2001 0/1/2003 55.49.
4/11/2001 11/1/2003 49.43.
4/11/2001 12/1/2003 49.43.
4/11/2001 1/1/2004 1 04.91.
4/11/2001 2/1/2004 92.81.
4/11 /2001 3/1/2004 84.74.
4/11/2001 4/1/2004 44.46.
4/11/2001 5/1/2004 33.45.
4/11/2001 6/1/2004 66.54.
4/11/2001 7/1/2004 92.60.
4/11/2001 8/1/2004 99.61 .
4/11/2001 9/1/2004 77.40 50.
4/11/2001 1 0/1 /2004 41.36.
Nov-01 thru Dec-O1 309.271.
Nov-01 thru may-230.212.
Jan-02 thru May-199.188.
Jun-02 thru Oct-108.85.
5/26/2004 RJL-WP-
Mid-C Forward Electric Prices Posted 5-2001
02-May-01 01-May-300.243.
02-May-01-Jun-325.260.
02-May-01-Jul-363.290.
02-May-01-Aug-406.324.
02-May-01-Sep-362.289.
02-May-01-0ct-283.249.
02-May-01-Nov-244.214.
02-May-01-Dec-244.214.
02-May-01-Jan-230.166.
02-May-01-Feb-200.145.
02-May-01-Mar-185.134.
02-May-01-Apr-87.63.
02-May-01-May-56.40.
02-May-01-Jun-136.98.
02-May-01-Jul-186.134.
02-May-01-Aug-189.137.
02-May-01-Sep-183.132.
02-May-01-0ct-113.74.
02-May-01-Nov-97.64.42
02-May-01-Dec-85.64.
02-May-01-Jan-103.75.
02-May-01-Feb-90.65.
02-May-01-Mar-83.60.
02-May-01-Apr-39.28.
02-May-01-May-25.18.
02-May-01-Jun-61.44.
02-May-01-Jul-83.60.
02-May-01-Aug-85.61.
02-May-01-Sep-82.59.
02-May-01-0ct-56.44.
02-May-01-Nov-53.38.
02-May-01-Dec-46.38.
02-May-01-Jan-87.63.
02-May-01-Feb-72.52.
02-May-01-Mar-66.48.
02-May-01-Apr-31.22.
02-May-01-May-20.14.
02-May-01-Jun-48.35.
02-May-01-Jul-66.48.
02-May-01-Aug-68.49.
02-May-01-Sep-65.47.
02-May-01-0ct-45.35.
Nov-01 thru Dec-01 244.214.
Nov-01 thru May-178.139.
Jan-02 thru May-02 151.109.
Jun-02 thru Oct-04 81.59.
5/26/2004
RJL-WP-
Revised
Mid-C Forward Electric Prices Posted 5-10-2001
5/10/2001 4/1/2001 313.256.
5/1 0/2001 5/1/2001 300.237.
5/10/2001 6/1/2001 360.226.
5/10/2001 7/1/2001 410.225.
5/10/2001 8/1/2001 420.336.
5/10/2001 9/1/2001 370.296.
5/10/2001 10/1/2001 280.224.
5/10/2001 11/1/2001 250.200.
5/10/2001 12/1/2001 250.200.
5/10/2001 1/1/2002 225.168.
5/10/2001 2/1/2002 200.150.
5/10/2001 3/1/2002 182.136.
5/10/2001 4/1/2002 93.74.40
5/10/2001 5/1/2002 67.53.
5/10/2001 6/1/2002 140.112.
5/10/2001 7/1/2002 204.163.
5/10/2001 8/1 /2002 207.165.
5/1 0/2001 9/1 /2002 204.163.
5/10/2001 0/1/2002 98.67.
5/10/2001 11/1/2002 75.60.
5/10/2001 12/1/2002 75.60.
5/10/2001 1/1 /2003 101.75.
5/10/2001 2/1 /2003 90.67.
5/10/2001 3/1/2003 81.61 .43
5/10/2001 4/1/2003 41.33.48
5/10/2001 5/1/2003 30.24.
5/10/2001 6/1/2003 63.50.
5/10/2001 7/1/2003 91.73.
5/10/2001 8/1/2003 93.74.
5/10/2001 9/1/2003 81.65.
5/10/2001 0/1/2003 39.30.
5/10/2001 11/1/2003 33.27.
5/10/2001 12/1/2003 33.27.
5/10/2001 1/1/2004 81.68.
5/10/2001 2/1/2004 76.65.
5/10/2001 3/1 /2004 69.59.
5/1 0/2001 4/1/2004 35.30.
5/10/2001 5/1 /2004 25.21.
5/10/2001 6/1/2004 53.45.
5/10/2001 7/1/2004 78.66.
5/10/2001 8/1/2004 79.67.
5/10/2001 9/1/2004 69.58.
5/10/2001 0/1/2004 33.28.
Jun-02 thru Oct-100.79.
5/26/2004 RJL-WP-
Gorton, Pat
To:
Cc:
Subject:
Eliassen , Jon; Emerson , John; Gruber, Bob
Norwood, Kelly
RE: 04-19-2001 Position Report
Hi Jon
I agree John is doing a great job on the position reports, I told him so again yesterday when I saw the hydro streamflow
and generation info. John is out today on a trip to tour the Spokane River plants. The gas prices locked in for 2002 are for
000 decatherms/day November 1 , 2001 through October 31 , 2004 ~ $6.0925 and 10 000 decatherms/day June 1
2002 through October 31 , 2003 ~ $6.56. There is another 17 658 decatherms/day at Malin index plus $0., November
, 2001 through October 31 , 2004, and 10 000 decatherms/day at Malin index plus $0., June 2002 through October 312003.
Bob Gruber plans to lock in the additional volumes over the next few weeks. He is watching the market, which has been
coming down and will lock in at $5.50 or if the downward trend reverses.
m not sure you want all this detail, but this is the plan. We won t need all of the 27 658 at Malin November 1 , 2001
through May 31 , 2002 , but we can use it at Rathdrum or sell it at Malin in the day and buy back at Rathdrum daily if the
spread warrants that. Yesterday the price at Malin was $10.545 vs. Stanfield at $5., even after variable costs this is at
least $5.00 of value, by selling the Malin and buying Rathdrum. We still have the price locked in for Rathdrum at $6.9025
and if today held true for a day in January the cost of the gas at Rathdrum would be $6.9025 less the $5.00 spread.
In the position report we are currently long .heavy and light load 01 and 02 so technically we wouldn t need to purchase
any additional gas. We 'iNiIIlock in the above variable pricing and we may still purchase some more gas for Rathdrum
January 2002 through April 2002. Rathdrum will probably have maintenance in May and then Coyote may be available in
June and we have the full amount of gas purchased for Coyote beginning June 2002.
Another interesting point is that 27 658 decatherms at Malin is roughly 28 000 decatherms dropped off at Coyote and
500 decatherms at Rathdrum, because of less fuel loss.
-----Original Message-----
From: Eliassen, JonSent: Friday, April 20, 2001 3:14 AMTo: Emerson, JohnCc: Gorton, Pat; Norwood, KellySubject: RE: 04-19-2001 Position Report
John-
The reports are getting better all the time, since much more comprehensive information is included.
Are the gas prices that are locked in for 2002 for the entire 01 and 02 requirements, or do we still have price
exposure in the next 18 months?
Jon
Jon Eliassen
A VISTA Corp.1i 509-495-4347
509-495-4361
i:8J jeliassen(fj),avistacorp.com
-----
Original Message-----
From: Emerson, JohnSent: Thursday, April 19, 2001 4:35 To: #Util Position Report
Subject: 04-19-2001 Position Report
CONFIDENTIAL: For Internal Use Only.
Thanks!
Purchases and Sales: Today power was pre-scheduled for Friday April 20 and Saturday April 21 , and prices
were about $230 for heavy load , and $175 for light load. We were a net purchaser of 101 aMW heavy load and
net seller of124 aMW light load. Fridays and Saturdays are pre-scheduled as a package (same for both days).
This creates a challenge for us, since our loads on Saturday are lower than Friday loads. In this case, we bought
101 aMW heavy load to meet our Friday needs, and this will leave the real time desk with extra power to sell on
r feedback.
Saturday. Alternatively we could have drafted Noxon to meet Friday loads and left real time basically flat on
Saturday. We chose not to do this because the Noxon forebay is now around 24 feet. We want to leave a
cushion over the 21 foot minimum in case we need this to cover for a plant outage or other special need , and our
license requires that we have the Noxon forebay at 27 feet by May 15. The preference against drafting Noxon
combined with the fact that real time prices have been higher than prescheduled prices for the past few days
contributed to the decision to buy the 101 aMW heavy load for Friday and Saturday. Light load was sold because
we are surplus in light load hours even after we back down as much hydro generation as we can.
The April Mid-Month water supply forecast from the National Weather Service was released today, and estimates
again edged up slightly (see Hydro below).
~~ File: 2001-04-19.xls )-)-
Hydro:
~~ OLE Object: Microsoft Excel Worksheet ~~Colstrip: Colstrip 3 is down for major maintenance, expected back on May 14. Colstrip 4 running 111 aMW.
Kettle Falls: Running ~ 46 aMW.
Northeast Combustion Turbine: Unit A at vendor for repair of cracked case, Unit B running and leased
replacement for Unit A both running - 54 aMW total.Rathdrum: Both units running -- 154 aMW total.
Month to Date Loads through April 18:
Native load month to date: 405 510 MWh (939 aMW)
Month of April budgeted native load: 686 640 MWh (955 aMW)
Month to date native load peak: 1 209 MW, hour 09, Mon Apr 9Prices: Additional prices not shown below:
~~ OLE Object: Microsoft Excel Worksheet ~~
20
0
3

H
e
a
v
y

L
o
a
d

H
o
u
r

S
u
r
p
l
u
s

(D
e
f
i
c
i
t
)
Wi
t
h

H
y
d
r
o

a
n
d

L
o
a
d

V
a
r
i
a
b
i
l
i
t
y

-
-

90
0
;
0

an
d

9
5
0
/0

C
o
n
f
i
d
e
n
c
e

In
t
e
r
v
a
l
s
Mo
n
t
h
l
v

A
:;
:
--
-
IU
U
U
..
.
.
90
0
80
0
70
0

60
0

.'
'1
"
"
50
0
'1
"
"
..
.
o
i
l

40
0
..
.
.
'1
1
1
,.
.
.
.
.
-
30
0
'1
'
"
'
20
0
..
.
10
0
10
0
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
Se
p
Oc
t
No
v
De
c
AV
E
""
"
'
2
0
0
3

H
L
H

Su
r
p
l
u
s
(
D
e
f
l
c
l
t
)
36
1
40
0
39
9
32
3
42
6
44
7
38
9
10
2
17
6
32
4
32
4
31
0
+9
0
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
on
e
-
ta
l
l

t
e
s
t
58
0
61
7
58
7
52
5
56
4
61
6
69
0
15
9
19
6
27
4
45
7
44
9
47
6
+9
5
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
o
n
e
-
ta
l
l

t
e
s
t
64
3
67
9
64
1
58
3
60
4
66
4
77
7
19
0
22
4
30
2
49
6
48
5
52
4
90
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,

o
n
e
-
ta
l
l

t
e
s
t
14
2
18
3
21
1
12
1
28
8
27
8
-5
1
19
1
19
9
14
5
95
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
o
n
e
-
ta
l
l

t
e
s
t
12
1
15
7
24
8
23
0
-8
2
-2
0
15
2
16
3
20
0
3

L
i
g
h
t

L
o
a
d

H
o
u
r

S
u
r
p
l
u
s

(
D
e
f
i
c
i
t
)
Wi
t
h

H
y
d
r
o

a
n
d

L
o
a
d

V
a
r
i
a
b
i
l
i
t
y

-
-

90
%

a
n
d

95
0
/0

Co
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
s
th
l

A
:t
:
10
0
0
ve
r
a
g
e
s
. '
"
"
90
0
.
'
"
"
80
0
-I"
'
"
..
.
70
0
60
0
".
50
0
40
0
--
-
30
0
:~

"'
-
--0
I
I
I
I
20
0
""
I
I
'
"
..
.
..
.
.-
-
10
0
.-
-
..
.
10
0
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
Se
p
Oc
t
No
v
De
c
AV
E
--
-
+
-
2
0
0
3

L
L
H

Su
r
p
l
u
s
(
D
e
f
i
c
l
t
)
16
0
24
6
25
8
19
7
52
9
57
9
63
8
45
8
28
8
19
6
22
2
32
3
+9
0
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
on
e
-
ta
l
l

t
e
s
t
30
3
38
7
36
6
36
7
73
4
79
3
87
3
56
2
33
5
17
2
28
7
34
0
46
0
+9
5
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
o
n
e
-
ta
l
l

t
e
s
t
34
5
42
8
39
8
41
6
79
3
85
5
94
1
59
2
34
9
19
3
31
4
37
4
50
0
90
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,

o
n
e
-
ta
l
l

t
e
s
t
10
5
15
0
32
4
36
5
40
3
35
4
24
1
10
5
10
4
18
5
95
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
o
n
e
-
ta
l
l

t
e
s
t
11
8
26
5
30
3
33
5
32
4
22
7
14
5
a..
.
::
J a..
.
::
J
;;
:
2003 Total Energy Requirements (aMW)RATHDRUM AND NORTHEAST cr.S NOT DISPATCHED
02-02-2001
Resources Dispatched to Emission Limits
2003 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Noy Dee AVE
Net System Load 1191 1136 1003 943 918 923 925 957 901 954 1057 11591 1006(Includes PotialCh 22)
NTRACT REQUIREMENTS
PACIFICORP 94 SALE
PACIFICORP EXCHANGE
PGE CAPACITY
WNP.
NICHOLS PUMPING NET OF PGE
ENTITLEMENT/SUP RETURN
CANADIAN ENTITLEMENT
TOTAL REOUIREMENTS 1294 1240 1106 1045 978 1048 1021 1094 1045 1059 1154 1252\1111
HYDR ESOU CES
System and Mid C Normal Water 512 536 543 595 849 903 597 390 301 330 448 566 548
Black Creek Hydro
Smell Power
Upriver Gross
ERMAL RESOU CES
CoIslrip 196 196 196 196 196 196 196 196 196 196 196 196 196
Rathdrum
Ralhdrum Add SCR
CSII 257 245 240 244 239 235 232 233 236 244 244 248 241
Kettle Falls - Gas
Kettle Falls
KFCT
C.QNI8ACJ"~
BPA ResldenUaI Exchange
ENTITLEMENT & SUPPLE
PGE Cap Rtn
CSPE
PACIFICORP EXCHG RETURN
WNP.103 103 103 103
TRANSAL TA 190 190 190 190 190 190 190 190 190 143
TOTAL RESOURCES 1432 1446 1382 1244 1442 1491 1364 1168 1066 1111 1333 14681 1329
MAINTENANCE
CoIstrip
RCT
CSII
Kettle Falls
KFCT
Clark Fork Hydro
kane River H
NET RESOURCES 1432 1446 1382 1244 1333 1443 1364 1168 1066 1111 1333 14681 1316
Jan-o3 Feb-O3 Mar-o3 Jun-o3 Jul-o3 Oct-o3 Nov-o3 Dec-o3
SURPLUS/(DEACIT)138 206 276 395 343 179 216
OTHER REQUIREMENTS
SURPLUS/(DEFICIT) ON/OFF PEAK
ON PEAK
OFF PEAK
AVERAGE
Jan-o3 Feb-O3 Mar-o3 Apr-o3 May-o3 Jun-o3 Jul-o3 Au~3 Se~3 Oct.Q3 Nov-o3 Dec-o3208 251 253 182 287 315 211 .125 -84 .19 122 173160 246 258 169 390 447 460 279 102 99 196 222187 249 255 171 332 374 321 53 .1 31 157 195
AVE
148
252
'194
c: Groce
Thackston
Lafterty
KaJlch
Siorro
Emerson
Warne
Gorton
Bryan
Winters
Gruber
Norwood
Stockinger
20
0
3

A
v
e
r
a
g
e

S
u
r
p
l
u
s

(D
e
f
i
c
i
t
)

W
i
t
h
o
u
t

R
a
t
h
d
r
u

o
r

NE

C
T
'
Wi
t
h

H
y
d
r
o

a
n
d

L
o
a
d

V
a
r
i
a
b
i
l
i
t
y

-
-

90
0
/0

an
d

95
0
/0

Co
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
s
Mo
n
t
h
l
v

A
:t
:
..
.
.
..
.
.
:i
:Ct
I
lU
U
U
90
0
AC
T

C
a
p
a
c
i
t
y

=

1
6
0

NE
C
T

C
a
p
a
c
i
t
y

=

6
0

M
W
80
0
70
0
60
0
50
0
.~

-1
"
'
8
40
0
""

...
.
IlL
30
0
20
0
'"
"
..
.
.
..
.
.
10
0
L-

L.
.
. r
.
.
..
.
. r
.
.
..
..
.
..
.
10
0
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
Se
p
Oc
t
No
y
De
c
AV
E
-+
-
2
0
0
3

A
v
e

Su
r
p
l
u
s
(
D
e
f
l
c
l
t
)
18
7
24
9
25
5
17
7
33
2
37
4
32
1
15
7
19
5
19
4
+9
0
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
on
e
-
ta
l
l

t
e
s
t
37
1
43
1
40
7
36
4
55
3
61
5
59
8
16
8
10
2
13
5
31
6
37
4
36
9
+9
5
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
o
n
e
-
ta
l
l

t
e
s
t
42
4
48
4
45
1
41
8
61
7
68
5
67
8
20
2
13
2
16
6
36
2
42
6
42
0
90
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,

o
n
e
-
ta
l
l

t
e
s
t
10
3
11
1
13
3
-6
2
10
4
95
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,

o
n
e
-
ta
l
l

t
e
s
t
13
4
10
4
20
0
3

H
e
a
v
y

L
o
a
d

H
o
u
r

S
u
r
p
l
u
s

(D
e
f
i
c
i
t
)

W
i
t
h
o
u
t

R
a
t
h
d
r
u
m

an
d

N
E

C
T
'
Wi
t
h

H
y
d
r
o

a
n
d

L
o
a
d

V
a
r
i
a
b
i
l
i
t
y

-
-

9
0
0
/0

a
n
d

9
5
0
/0

C
o
n
f
i
d
e
n
c
e

In
t
e
r
v
a
l
s
th
l

A
;;
:
--
-
-
10
0
0
ve
r
a
g
e
s
AC
T

C
a
p
a
c
i
t
y

=

1
6
0

M
W
90
0
NE
C
T

C
a
p
a
c
i
t
y

=

6
0

M
W
80
0
70
0
60
0

50
0
'"
"
..
40
0

.-
A
-I
"
"
30
0
..
.
.
.
I"
-
20
0
...
iii
.
.
.
""
"
"
l
1
l
I

10
0
I"
"
'"
"
81
"
"

I"
"
'"
"
."

."

..
.
-1
0
0
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
Se
p
Oc
t
No
v
De
c
AV
E
-+
-
-
2
0
0
3

H
L
H

Su
r
p
l
u
s
(
D
e
f
l
c
l
t
)
20
8
25
1
25
3
18
2
28
7
31
5
21
1
12
5
12
2
17
3
14
8
+9
0
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
on
e
-
ta
i
l

t
e
s
t
42
7
46
8
44
1
38
4
42
5
48
4
51
2
25
5
29
8
31
3
+9
5
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
o
n
e
-
ta
l
l

t
e
s
t
49
0
53
0
49
5
44
2
46
5
53
2
59
9
10
7
29
4
33
4
36
1
90
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
o
n
e
-
ta
l
l

t
e
s
t
14
9
14
6
23
0
17
8
11
7
95
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
o
n
e
-
ta
l
l

t
e
s
t
10
9
17
7
26
1
20
6
14
5
-5
0
(I
)
::J
20
0
3

L
i
g
h
t

L
o
a
d

H
o
u
r

S
u
r
p
l
u
s

(
D
e
f
i
c
i
t
)

W
i
t
h
o
u
t

Ra
t
h
d
r
u
m

o
r

NE

C
T
'
Wi
t
h

H
y
d
r
o

a
n
d

L
o
a
d

V
a
r
i
a
b
i
l
i
t
y

-
-

90
0
/
0

an
d

9
5
0
/0

C
o
n
f
i
d
e
n
c
e

In
t
e
r
v
a
l
s
th
l

A
:t
:
:
:;
:
:
--
-
10
0
0
ve
r
a
g
e
s
90
0
AC
T

C
a
p
a
c
i
t
y

=

1
6
0

NE
C
T

C
a
p
a
c
i
t
y

=

6
0

M
W
80
0
-"
'
"
70
0
-.
.
...
.
p
o
l

60
0
50
0
...
.
.

...
.
-p
o
l
40
0
-p
o
l

-P
"
"
-"
'
"
30
0
...
.
.
.
.
./

20
0

..
.
.-

10
0
..
.
.
..
.
10
0
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
Se
p
Oc
t
No
v
De
e
AV
E
-+
-
2
0
0
3

L
L
H

Su
r
p
l
u
s
(
D
e
f
l
c
l
t
)
16
0
24
6
25
8
16
9
39
0
44
7
46
0
27
9
10
2
19
6
22
2
25
2
+9
0
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
on
e
-
ta
l
l

t
e
s
t
30
3
38
7
36
6
33
9
59
5
66
1
69
5
38
3
14
9
17
2
28
7
34
0
39
0
+9
5
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,

o
n
e
-
t
a
l
l

t
e
s
t
34
5
42
8
39
8
38
8
65
4
72
3
76
3
41
3
16
3
19
3
31
4
37
4
43
0
-9
0
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,

o
n
e
-
ta
l
l

t
e
s
t
10
5
15
0
18
5
23
3
22
5
17
5
10
5
10
4
11
5
95
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
o
n
e
-
ta
l
l

t
e
s
t
11
8
12
6
17
1
15
7
14
5
2003 Total Energy Requirements (aMW)CRITICAL HYDRO CONDITIONS - Oct 1936. Dee 1937
02-10.2001
Resources Dispatched to Emission Umlts
2003 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Noy Dee AVE
Loads
Net System Load 1213 1158 1025 965 940 945 947 979 923 976 1079 11811 1028
(Includes Potlatch 22)
CON REQU
PACIFICORP 94 SALE
PACIFICORP EXCHANGE
PGE CAPACI'TY
WNp.3
NICHOLS PUMPING NET OF PGE
ENTIi1.EMENT/SUP RETURN
CANADIAN ENTJT1.EMENT
TOTAL REQUIREMENTS 1316 1262 1128 1067 1000 1070 1043 1116 1067 10B1 1176 1274 1133
HYDR ESOU CES
CRITICAL System and Mid C Normal Water 310 298 291 337 672 744 369 399 248 264 '345 463 395
Black Creek Hydro 0 '
Small Power
Upriver Gross
iriERMAL RESOURCES
CoIsbip 196 196 196 196 196 196 196 196 196 196 196 196 196
Rathdrum 156 150 139 132 130 131 134 116
Rathdrum Add SCR
0511 257 245 240 244 239 235 232 233 236 244 244 248 241
Kettle Falls - Gas
Kettle Falls
KFCT
CONTRA T RIGHTS
BPA Residential Exchange
ENTITLEMENT & SUPPLE
PGE Cap Rtn 50,
CSPE
PACIFICORP EXCHG RETURN
WNP.3 103 103 103 103
TRANSALTA 190 190 190 190 190 190 190 190 190 143
TOTAL RESOURCES 1386 1358 1212 1079 1404 1464 1314 1356 1199 1158 1338 1449 1310
MAINTENANCE
CoIslrlp
RCT
CSII
Kettle Falls
KFCT
Clark Fork Hydro
kane River Hydr
..:INET RESOURCES 1386 1358 1212 1079 1295 1416 1314 1356 1199 115B 1338 1297
Jan-O3 Feb-O3 Mar.(l3 Jun-O3 Jul.(l3 Oct.(l3 Noy.(l3 Dec.(l3 AVE
SURPLUS/(DEFICtT)346 271 162 175 164
OTHER REQUIREMENTS
Check
SURPLUS/(DEFICtT) ON/OFF PEAK Jan-O3 Feb-O3 Mar.(l3 Apr.(l3 May.(l3 Jun-03 Jul.(l3 Aug.(l3 Sep-03 Oct.Q3 Noy.Q3 Dec.(l3 AVE
ON PEAK 106 -40 184 233 149 17B
OFF PEAK 43B 488 506 511 277 176 173 245
AVERAGE 295 346 271 241 131 162 176 163
c: Groce
Thackston
Lafferty
Kaflch
Storro
Emerson
Warne
Gorton
Bryan
WInters
Gruber
Norwood
Stockinger
Cr
i
t
c
a
l

H
y
d
r
o

C
o
n
d
i
t
i
o
n
s

-
-

20
0
3

S
u
r
p
l
u
s

(
D
e
f
i
c
i
t
)
Wi
t
h

L
o
a
d

V
a
r
i
a
b
i
l
i
t
y

-
-

90
0
10

an
d

95
0
/
0

Co
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
s
Mo
n
t
h
l
v

A
;;
:CI
J
'-
'
fU
U
60
0
50
0
40
0
30
0
~~

-.
.
'
"'"
20
0
-0
0
I
I
I
I

.\
8
-\
8
/"

\o
i
l
\o
i
l
10
0
.~
F
I
\o
i
l
10
0
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
Se
p
Oc
t
No
v
De
c
AV
E
20
0
3

A
v
e

S
u
r
p
l
u
s
(
D
e
f
l
c
l
t
)

C
r
i
t
i
c
a
l
29
5
34
6
27
1
24
1
13
1
16
2
17
6
16
3
11
6
+9
0
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
on
e
-
ta
l
l

t
e
s
t
14
4
14
9
30
8
37
9
32
2
28
4
14
4
20
4
22
4
20
2
+9
5
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
o
n
e
-
ta
l
l

t
e
s
t
16
5
16
4
12
5
31
1
38
8
33
7
29
7
14
8
10
4
21
6
23
8
21
3
90
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
o
n
e
-
ta
l
l

t
e
s
t
-3
1
28
2
31
3
22
0
19
8
11
8
12
0
12
8
12
5
95
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
o
n
e
-
ta
l
l

t
e
s
t
27
9
30
4
20
5
18
5
11
4
10
8
11
4
11
3
..
.
(/
)
Cr
i
t
i
c
a
l

H
y
d
r
o

C
o
n
d
i
t
i
o
n
s

-
-

20
0
3

H
e
a
v
y

L
o
a
d

H
o
u
r

S
u
r
p
l
u
s

(
D
e
f
i
c
i
t
)
Wi
t
h

L
o
a
d

V
a
r
i
a
b
i
l
i
t
y

-
-

90
0
/
0

an
d

9
5
0
/0

C
o
n
f
i
d
e
n
c
e

In
t
e
r
v
a
l
s
70
0

Mo
n
t
h
l

A
v
e
r
a

e
s
60
0
50
0
:t
:
:
;;
:
..
.
.
.
.
.
40
0
J.
.
::J J.
.
::J n:s
30
0
20
0
10
0
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
Se
p
Oc
t
No
v
De
c
AV
E
-"
"
2
0
0
3

H
L
H

Su
r
p
l
u
s
(
D
e
f
i
c
l
t
)

C
r
i
t
i
c
a
l
10
6
18
4
23
3
14
9
17
8
+9
0
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
on
e
-
ta
l
l

t
e
s
t
16
4
16
0
11
6
19
7
26
6
13
6
19
1
22
6
13
8
+9
5
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,

o
n
e
-
ta
l
l

t
e
s
t
18
5
17
5
12
5
20
0
27
5
15
1
10
2
20
3
24
0
14
9
90
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
.

o
n
e
-
ta
l
l

t
e
s
t
17
1
20
0
10
7
13
0
95
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
.
o
n
e
-
ta
i
l

t
e
s
t
16
8
19
1
11
6
10
0
VISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMATION
JURISDICTION:
CASE NO:
REQUESTER:
TYPE:
REQUEST NO.
Idaho
A VU - E-04-0 1 / A VU -04-
Potlatch
Data Request
DATE PREPARED:
WITNESS:
RESPONDER:
D EP AR TMENT:
TELEPHONE:
5/25/2004
Lafferty
Lafferty
Energy Resources
[phone]
REQUEST:
Please provide copies of all analyses, risk evaluations, gas market forecasts, memoranda
and all other documents prepared for or used in the evaluation of and justification of, the timing
and need for Deals A and B.
RESPONSE:
Forecasts of electric and natural gas forward prices along with economic analysis showing the
comparative cost to generate are included in the Pre-filed Direct Testimony and Exhibits of
Robert Lafferty.
Exhibit No., Schedule No. 22 contains Position Reports, transaction records, forward price
data, and economic comparisons of cost to generate versus cost to purchase power in the forward
market. Exhibit No.7, Schedule No. 31 contains Position Reports, including the cover memos
describing market transactions and conditions, for relevant dates in the April-May 2001 period.
Exhibit No.7, Schedule No. 17 shows the 3-21-01 Load & Resource position. The Load &
Resource source document for that Schedule is attached to this response. Exhibit No.
Schedule No. 25 shows weekly load variability amounts for each month. Attached to this
response is a set of analyses labeled "2002-2004 Load & Resource Position Summaries 90%
and 95% Confidence Interval Analysis With Natural Gas Resources Dispatched - 3/30101". This
attachment was the source document for 90% confidence interval load and resource position
summaries contained in Exhibit No.7, Schedule No. 26 that exclude any un-hedged natural gas-
fired generation. Also attached to this response are a February 9,2001 cover memo with subject
entitled "2003 L&R Position Summary" and the accompanying analyses showing 90% and 95%
confidence interval load and resource position analyses for the year 2003 under different
operating conditions.
Page 2
The Company also took into consideration industry publications that provided information
regarding expected forward electricity and natural gas market conditions and prices in the Pacific
Northwest and California. Publications were reporting at that time that federal policy-makers
were firmly opposed to imposing price caps in the Pacific Northwest energy markets. A sample
of just a few of those articles is included in Exhibit No.7, Schedules Nos. 22, 23, and 24 as well
as pages 1 , and 11 of Schedule No. 29.
Natural gas forward price data for Malin is attached to this response for the April-May 2001 time
frame. Electric energy forward price data at the time of the four transactions comprising Deal A
and Deal B are attached as part of this response. Also attached is an e-mail, dated 4-19-
which discusses the purchase of the natural gas hedges.
3/
2
1
/
2
0
0
1
AV
I
S
T
A

C
O
R
P
.
Re
q
u
i
r
e
m
e
n
t
s

a
n
d

R
e
s
o
u
r
c
e
s
fig
u
r
e
s

i
n

M
W

(
c
r
i
t
i
c
a
l

w
a
t
e
r
)
20
0
1
20
0
2
20
0
3
20
0
4
20
0
5
20
0
6
20
0
7
20
0
8
20
0
9
20
1
0
Li
n
e

N
o
.

R
E
Q
U
I
R
E
M
E
N
T
S
Av
g
Av
g
Av
g
Av
g
Av
g
Av
g
Av
g
Av
g
Av
g
Av
g
Sy
s
t
e
m

L
o
a
d
16
1
0
10
2
7
15
5
4
97
4
16
0
5
10
0
6
16
6
2
10
4
6
17
1
3
10
8
4
17
5
5
11
1
1
18
0
6
11
4
2
18
5
9
11
7
6
19
1
5
12
1
0
19
7
3
12
4
7
Pa
c
i
f
i
C
o
r
p

E
x
c
h
a
n
g
e
Pu
g
e
t

#
2
Pa
c
i
f
i
C
o
r
p

1
9
9
4
PG
E

#
1
15
0
15
0
15
0
15
0
15
0
15
0
15
0
15
0
15
0
15
0
Sn
o
h
o
m
i
s
h

1
0

y
r
10
0
Co
g
e
n
t
r
i
x

5
7

m
o
10
0
Ni
c
h
o
l
s

P
u
m
p
i
n
g
PG
E

S
a
l
e
Mo
n
t
a
n
a

S
a
l
e
10
0
Du
k
e

S
a
l
e
10
0
Cl
a
r
k
2

P
U
D
25
0
Ci
t
y

o
f

C
h
e
n
e
y
Re
s
e
r
v
e
s
25
1
24
5
25
6
26
1
26
6
27
1
27
6
28
2
28
7
TO
T
A
L

R
E
Q
U
I
R
E
M
E
N
T
S
27
5
9
14
7
1
19
8
6
10
1
5
20
0
9
10
2
1
20
6
9
10
4
7
21
2
5
10
8
5
21
7
2
11
1
2
22
2
8
11
4
3
22
8
6
11
7
7
23
4
8
12
1
1
24
1
1
12
4
8
RE
S
O
U
R
C
E
S
Sy
s
t
e
m

H
y
d
r
o
94
6
31
6
94
6
31
6
94
6
31
6
94
6
31
6
94
6
31
6
94
6
31
6
94
6
31
6
94
6
31
6
94
6
31
6
94
6
31
6
Co
n
t
r
a
c
t

H
y
d
r
o
19
5
19
5
19
5
19
5
19
5
14
0
14
0
14
0
14
0
Ca
n

E
n
t

R
e
t
u
r
n
Sm
a
l
l

P
o
w
e
r
Co
g
e
n
e
r
a
t
i
o
n
No
r
t
h
e
a
s
t

C
T
s
Ra
t
h
d
r
u
m

C
T
s
17
6
17
6
17
6
17
6
17
6
17
6
17
6
17
6
17
6
17
6
Pa
c
i
f
i
C
o
r
p

E
x
c
h
a
n
g
e
En
t
i
t
l
e
m
e
n
t

&

S
u
p
p
l
e
m
e
n
t
a
l
BP

A

R
e
s
.

Ex
c
h
a
n
g
e
14
9
14
9
14
9
14
9
14
9
14
9
14
9
14
9
BP
A
-
WN
P

#
3
CS
P
E
Tr
a
n
s
A
l
t
a
-
Ce
n
t
r
a
l
i
a
20
0
14
3
20
0
14
3
20
0
14
3
Th
e
r
m
a
l
-
Ke
t
t
l
e

F
a
l
l
s
Co
l
s
t
r
i
p
22
2
19
1
22
2
19
1
22
2
19
1
22
2
19
1
22
2
19
1
22
2
19
1
22
2
19
1
22
2
19
1
22
2
19
1
22
2
19
1
CS

I
I

C
C
C
T
10
1
28
0
24
1
28
0
24
1
28
0
24
1
28
0
24
1
28
0
24
1
28
0
24
1
28
0
24
1
28
0
24
1
SE
M
P
R
A
BP
A

5

y
r
.

P
u
r
c
h
a
s
e
11
5
Id
a
h
o

P
u
r
c
h
a
s
e
Du
k
e

P
u
r
c
h
a
s
e
10
0
MI
E
C
O
Cin
e
r
g
y

S
e
r
v
i
c
e
s
,

I
n
c
.
En
e
r
g
y

S
e
r
v
i
c
e
s
,

I
n
c
.
En
r
o
n
TO
T
A
L

R
E
S
O
U
R
C
E
S
23
5
3
12
1
2
20
5
3
10
1
6
23
3
2
11
4
4
21
1
7
99
9
20
6
6
99
1
20
1
5
10
0
3
21
1
7
10
8
0
21
1
7
10
8
0
21
1
7
10
7
4
20
4
6
10
5
6
SU
R
P
L
U
S

(
D
E
F
I
C
I
T
)
40
6
25
9
32
3
12
3
15
7
10
9
11
1
16
9
23
1
13
7
36
5
19
2
2002 - 2004 Load & Resource Position Summaries
90% and 95% Confidence Interval Analysis
With Natural Gas-Fired Thermal Resources Dispatched
3/30/01
3 \~o \Q IX('-2002 Total Energy Requirements (aMW)
J"~
02-02-2001
Resources Dispatched to Emission Limits
2002 Jan Feb Mar Apr May Jun Jul Aug Sep Oct NaY Dee AVE
Loa cis
Net System Load 1170 1111 976 930 908 898 911 944 883 942 1053 1125 988
(includes Potlatch 22)
CONTRACT REQUIREMENTS
PACIFICORP 94 SALE
PACIFICORP EXCHANGE
PGE CAPACITY
SNOHOMISH 1()-
PUGET2
WNP-
NICHOLS PUMPING NET OF PGE
ENTITLEMENT/SUP RETURN
CANADIAN ENTITLEMENT
TOTAL REQUIREMENTS 1298 1240 1104 1058 994 1049 1033 1106 1054 1072 1181 1249 1120
HYDRO RESOURCES
System and Mid C Normal Water 512 536 542 594 849 903 597 390 301 330 449 566 547
Black Creek Hydro
Small Power
Upriver Gross
THERMAL RESOURCES
Co/strip 202 202 202 202 202 202 202 202 202 202 202 202 202
Rathdrum 126 130 123 118 115 113 116 113 142 148 151 123Rathdrum Add SCR
CSII 233 236 244 252 256 102
Kettle Falls - Gas
Kettle Falls
KFCT
CONTRACT RIGHTS
SEMPRA-50 on-pk last year
BPA Residential Exchange
ENTITLEMENT & SUPPLE
PGE Cap Rtn
CSPE
PACIFICORP EXCHG RETURN
WNP.103 103 103 103
TRANSALTA 190 190 190 190 190 190 190 190 190 143
TOTAL RESOURCES 1337 1368 1260 1135 1287 1385 1306 1347 1245 1298 1531 1640 1345
MAINTENANCE
Colstrip 101
RCT
CSII
Kettle Falls
KFCT
Clark Fork Hydro
Spokane River Hydro
NET RESOURCES 1337 1368 1260 1135 1186 1325 1306 1347 1245 1298 1531 1640 1332
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dee AVESURPLUSI(DEFICIT)108 145 229 225 193 144 177 302 344 164
OTHER REQUIREMENTS
SURPLUSI(DEFICIT) ON/OFF PEAK
ON PEAK
OFF PEAK
AVERAGE
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dee AVE23 88 163 27 95 190 127 33 68 124 274 315 127(49) 70 38 35 208 277 349 415 231 251 337 377 212(9) 80 108 30 145 229 225 193 144 177 302 344 164
a; Groce
Thaokston
LaIl8f1y
Kalloh
StOlT'll
en-""n
Warne
Gonon
Bryan
WlnlllfS
Gruber
No rwood
Stockinger
20
0
2

A
v
e
r
a
g
e

S
u
r
p
l
u
s

(D
e
f
i
c
i
t
)
Wi
t
h

H
y
d
r
o

a
n
d

L
o
a
d

V
a
r
i
a
b
i
l
i
t
y

-
-

90
0
/
0

an
d

95
0
/
0

Co
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
s

Mo
n
t
h
l
v

A
:;
:C1
)
::
s
lU
U
U
90
0
80
0
70
0
60
0
.
I
'
l
l
'"
,
"
50
0
40
0

."
'
"
'"
'
---
I
1
I
1
I
I
30
0
.1
8
20
0
'"
'
..
.
.
...
.
.
.
.
.
...
.
.
.
.
""
l
1
l
I

,.
.

10
0

"'-
..
.
,.
.
.
"I
I
I
"
1"
1
10
0
..
..

20
0
..
.
30
0
40
0
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
Se
p
Oc
t
No
v
De
c
AV
E
20
0
2

A
v
e

S
u
r
p
l
u
s
(
D
e
f
i
c
l
t
)
10
8
14
5
22
9
22
5
19
3
14
4
17
7
30
2
34
4
16
4
+9
0
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
on
e
-
ta
l
l

t
e
s
t
17
5
26
2
26
0
21
7
36
6
47
0
50
2
30
8
24
7
28
1
46
1
52
3
33
9
+9
5
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
o
n
e
-
ta
l
l

t
e
s
t
22
8
31
5
30
4
27
1
43
0
54
0
58
2
34
2
27
7
31
2
50
7
57
5
39
0
90
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
o
n
e
-
t
a
i
l

t
e
s
t
19
3
10
2
15
7
14
3
'
16
5
95
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
o
n
e
-
ta
l
l

t
e
s
t
24
6
15
5
21
1
-1
4
0
13
2
11
3
20
0
2

H
e
a
v
y

L
o
a
d

H
o
u
r

S
u
r
p
l
u
s

(D
e
f
i
c
i
t
)
Wi
t
h

H
y
d
r
o

a
n
d

L
o
a
d

V
a
r
i
a
b
i
l
i
t
y

-
-

90
0
/
0

an
d

9
5
0
/0

C
o
n
f
i
d
e
n
c
e

In
t
e
r
v
a
l
s
th
l

A
:t
:
:
-.
:C1
)
...II)
::
s
..
.
::
s
10
0
0
ve
r
a
g
e
s
90
0
80
0
70
0
60
0
50
0
-I
'
"
'
40
0
..
..
.
.
.
.
.
-I
"
"
30
0
""
'
"
-I
"
"
20
0
"'"
...
.
t

..
.
.
-I
"
"
10
0
,.
.
'"
'
-
.

...
.
.
.
.
,
j
j
'I
I
I

"'"
..
"'"
..
.
10
0
..
..
.
.
20
0
-3
0
0
40
0
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
Se
p
Oc
t
No
v
De
c
AV
E
~2
0
0
2

HL
H

S
u
r
p
l
u
s
(
D
e
f
i
c
i
t
)
16
3
19
0
12
7
12
4
27
4
31
5
12
7
+9
0
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
on
e
-
ta
l
l

t
e
s
t
24
2
30
5
35
1
22
9
23
3
35
9
42
8
13
8
16
2
22
2
40
7
44
0
29
3
+9
5
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,

o
n
e
-
ta
l
l

t
e
s
t
30
5
36
7
40
5
28
7

'
27
3
40
7
51
5
16
9
19
0
25
0
44
6
47
6
34
1
90
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,

o
n
e
-
t
a
l
l

t
e
s
t
19
6
12
9
17
5
17
4
14
1
19
0
-3
8
-9
5
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,

o
n
e
-
t
a
l
l

t
e
s
t
25
9
19
1
23
3
26
1
-1
0
3
10
2
15
4
20
0
2

L
i
g
h
t

L
o
a
d

H
o
u
r

S
u
r
p
l
u
s

(
D
e
f
i
c
i
t
)
Wi
t
h

H
y
d
r
o

a
n
d

L
o
a
d

V
a
r
i
a
b
i
l
i
t
y

-
-

9
0
0
/0

a
n
d

95
0
/
0

Co
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
s
th
l

A
:=
:
:;
:
:
10
0
0
ve
r
a
g
e
s
90
0
80
0
70
0
60
0
',
"
"
50
0
-'"
"
40
0
...
.
.
...
.
.
.
.
.
.
",
30
0
,.
.
.
.1
"
"

..
.
.
.
20
0
'"
"
...

.l1
l
i
"I
I
I

,..
.

.,"
"
'"
"
10
0
'"
"
41

"'
"
:.
/
.
'
"
"
'"
"
.'"
"
10
0
'"
"
20
0
30
0
40
0
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
Se
p
Oc
t
No
v
De
c
AV
E
~2
0
0
2

LL
H

S
u
r
p
l
u
s
(
D
e
f
l
c
i
t
)
-4
9
20
8
27
7
34
9
41
5
23
1
25
1
33
7
37
7
21
2
+9
0
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
on
e
-
ta
l
l

t
e
s
t
21
1
14
6
20
5
41
3
49
1
58
4
51
9
27
8
32
4
42
8
49
5
34
9
+9
5
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,

o
n
e
-
ta
l
l

t
e
s
t
13
6
25
2
17
8
25
4
47
2
55
3
65
2
54
9
29
2
34
5
45
5
52
9
38
9
90
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
o
n
e
-
ta
l
l

t
e
s
t
19
2
-1
3
5
11
4
31
1
18
4
17
8
24
6
25
9
95
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,

o
n
e
-
t
a
l
l

t
e
s
t
-2
3
4
11
2
10
2
18
4
-5
6
28
1
17
0
15
7
21
9
22
5
f/)
::
s
::
s
2003 Total Energy Requirements (aMW)
02.02-2001
Resources Dispatched to Emission Limits
2003 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Noy Dec AVE
Loads
Net System Load 1191 1136 1003 943 918 923 925 957 901 954 1057 11591 1006
(Includes Potlatch 22)
CONTRA T RE UIR
PACIFICORP 94 SALE
PACIFICORP EXCHANGE
PGE CAPACITY
WNP-
NICHOLS PUMPING NET OF PGE
ENTITLEMENT/SUP RETURN
CANADIAN ENTITLEMENT
TOTAL REQUIREMENTS 1294 1240 1106 1045 978 1048 1021 1094 1045 1059 1154 1252 1111
HYDRO RESOURCES
System and Mid C Normal Water 512 536 543 595 849 903 597 390 301 330 448 566 548
Black Creek Hydro
Small Power
Upriver Gross
THERMAL RESOURCES
Colstrlp 196 196 196 196 196 196 196 196 196 196 196 196 196
Rathdrum 156 150 139 132 130 131 134 116
Rathdrum Add SCR
CSII 257 245 240 244 239 235 232 233 236 244 244 248 241
Kettle Falls .. Gas
Kettle Falls
KFCT
CONTRACT RIGHTS
BPA Residential Exchange
ENTITLEMENT & SUPPLE
PGE Cap Rtn
CSPE
PACIFICORP EXCHG RETURN
WNP.103 103 103 103
TRANSAL T A 190 190 190 190 190 190 190 190 190 143
TOTAL RESOURCES 1588 1596 1464 1337 1581 1623 1542 1347 1252 1224 1441 1552 1482
MAINTENANCE
CoIstrlp
RCT
CSII
Kettle Falls
KFCT
Clark Fork Hydro
Spokane River Hydro
NET RESOIJElC.ES 1588 1596 1464 1337 1472 1575 1542 1347 1252 1224 1441 1552 1449
Jan-D3 Feb-03 Mar.o3 Apr.o3 May-Q3 Jun-D3 Jul.o3 Aug-Q3 Sep-O3 Oct.o3 Noy.o3 Dec.o3 AVE
SURPLUSI(DEFICIT)294 356 358 292 494 527 521 253 207 165 287 300 338
OTHER REQUIREMENTS
SURPLUSI(DEFICIT) ON/OFF PEAK
ON PEAK
OFF PEAK
AVERAGE
Jan-D3 Feb-o3 Mar.o3 Apr.o3 May.o3 Jun-D3 Jul-Q3 Aug-O3 Sep-O3 Oct-03 Noy.o3 Dec.o354 m 160 246 258 197 529 579 838 458 288 99 196 222272 334 337 270 471 506 499 232 185 144 264 279
AVE
310
323
316
c: Groce
Thackston
Lafferty
Kalich
Storro
Emerson
Warne
Gorton
Bryan
Winters
Gruber
Norwood
Stockinger
20
0
3

S
u
r
p
l
u
s

(
D
e
f
i
c
i
t
)
Wi
t
h

H
y
d
r
o

a
n
d

L
o
a
d

V
a
r
i
a
b
i
l
i
t
y

-
-

90
0
/
0

an
d

9
5
0
/0

C
o
n
f
i
d
e
n
c
e

In
t
e
r
v
a
l
s
Mo
n
t
h
l
v

A
:t
:
:
0;
:
::
:
:
:
J
::
:
:
:
J
lU
U
U
90
0
80
0
70
0
60
0
..
.,
.
50
0
..
""
"
40
0
30
0
""
"
'
"
-
-
..
..
.
.
.
.
.
.
'f
"
"
II
I
20
0
..
.
..
.
10
0
...
..
.
."

..
.
10
0
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
Se
p
Oc
t
No
v
De
c
AV
E
""
'
2
0
0
3

A
v
e

Su
r
p
l
u
s
(
D
e
f
l
c
l
t
)
27
2
33
4
33
7
27
0
47
1
50
6
49
9
23
2
18
5
14
4
26
4
27
9
31
6
+9
0
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
on
e
-
ta
l
l

t
e
s
t
45
6
51
6
48
9
45
7
69
2
74
7
77
6
34
7
28
8
24
8
42
3
45
8
49
1
+9
5
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
o
n
e
-
t
a
l
l

t
e
s
t
50
9
56
9
53
3
51
1
75
6
81
7
85
6
38
1
31
8
27
9
46
9
51
0
54
2
90
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,

o
n
e
-
t
a
l
l

t
e
s
t
15
2
18
5
25
0
26
5
22
2
11
7
10
5
10
0
14
1
95
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
o
n
e
-
ta
l
l

t
e
s
t
14
1
18
6
19
5
14
2
20
0
3

H
e
a
v
y

L
o
a
d

H
o
u
r

S
u
r
p
l
u
s

(D
e
f
i
c
i
t
)
Wi
t
h

H
y
d
r
o

a
n
d

L
o
a
d

V
a
r
i
a
b
i
l
i
t
y

-
-

9
0
0
/0

a
n
d

95
0
/
0

Co
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
s
th
l

A

:;
:
:
::
:
:
I
::
:
:
I
10
0
0
ve
r
a
g
e
s
90
0
80
0
.,
.
.
70
0

'"
'
.,
.
.
.,
.
.
60
0
.,
.
.
'"
'
50
0
..o
i
l

..
.
40
0
,.
.
,.
.
.
.
.
,
.
.
30
0
..

-
20
0
\"

..
.
..
.
10
0
..
.
..
.
"'"
..
.
10
0
..
.
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
Se
p
Oc
t
No
v
De
e
AV
E
-+
-
2
0
0
3

H
L
H

Su
r
p
l
u
s
(
D
e
f
l
c
l
t
)
36
1
40
0
39
9
32
3
42
6
44
7
38
9
10
2
17
6
32
4
32
4
31
0
+9
0
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
on
e
-
t
a
l
l

t
e
s
t
58
0
61
7
58
7
52
5
56
4
61
6
69
0
15
9
19
6
27
4
45
7
44
9
47
6
+9
5
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,

o
n
e
-
ta
l
l

t
e
s
t
64
3
67
9
64
1
58
3
60
4
66
4
77
7
19
0
22
4
30
2
49
6
48
5
52
4
90
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
o
n
e
-
ta
l
l

t
e
s
t
14
2
18
3
21
1
12
1
28
8
27
8
19
1
19
9
14
5
95
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
o
n
e
-
ta
l
l

t
e
s
t
12
1
15
7
24
8
23
0
15
2
16
3
20
0
3

L
i
g
h
t

L
o
a
d

H
o
u
r

S
u
r
p
l
u
s

(
D
e
f
i
c
i
t
)
Wi
t
h

H
y
d
r
o

a
n
d

L
o
a
d

V
a
r
i
a
b
i
l
i
t
y

-
-

90
0
/
0

an
d

95
0
/0

Co
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
s
th
l

A
:t
:C1
)
10
0
0
ve
r
a
g
e
s
90
0
80
0
70
0
60
0
\.
"
50
0
'1
'
"
"
40
0
..

30
0
'1
'
"
"
..
.
.
.
.
.
.
...
.
.
.
20
0

...
.
\V

,..
.
.

10
0
..
.
..
.
..
.
10
0
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
Se
p
Oc
t
No
v
De
c
AV
E
"'
-
2
0
0
3

L
L
H

Su
r
p
l
u
s
(
D
e
f
i
c
l
t
)
16
0
24
6
25
8
19
7
52
9
57
9
63
8
45
8
28
8
19
6
22
2
32
3
+9
0
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
on
e
-
t
a
l
l

t
e
s
t
30
3
38
7
36
6
36
7
73
4
79
3
87
3
56
2
33
5
17
2
28
7
34
0
46
0
+9
5
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
o
n
e
-
ta
l
l

t
e
s
t
34
5
42
8
39
8
41
6
79
3
85
5
94
1
59
2
34
9
19
3
31
4
37
4
50
0
-9
0
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
o
n
e
-
t
a
l
l

t
e
s
t
10
5
15
0
32
4
36
5
40
3
35
4
24
1
10
5
10
4
18
5
95
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
o
n
e
-
ta
l
l

t
e
s
t
11
8
26
5
30
3
33
5
32
4
22
7
14
5
2004 Total Energy Requirements (aMW)
02-02-2001
Resources Dispatched to Emission Limits
2004 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dee AVE
Loads
Net System Load 1254 1198 1066 1003 983 988 991 1024 960 1015 1115 1221 1068
(Includes Potlatch 22)
CONTRACT REQUIREMENTS
WNP.
PGE CAPACITY
NICHOLS PUMPING NET OF PGE
CANADIAN ENTITLEMENT
PACIFICORP 94 SALE
TOTAL REQUIREMENTS 1351 1294 1163 1100 1038 1100 1074 1140 1094 1114 1212 1314 1166
HYDRO RESOURCES
System and Mid C Normal Water 512 518 543 595 849 903 597 390 302 330 448 566 546
Black Creek Hydro
Small Power
Upriver Gross
THERMAL RESOURCES
CoIstrip 196 196 196 196 196 196 196 196 196 196 196 196 196
Rathdrum 157 140 132 130 131 134 142 148 151 126
Rathdrum Add SCR
CSII 249 253 240 236 231 233 232 233 236 244 252 256 241Kettle Falls - Gas
Kettle Falls
KFCT
CONTRACT RIGHTS
BPA Residential Exchange
ENTITLEMENT & SUPPLE
PGE Cap Rtn
CSPE
PACIFICORP EXCHG RETURN
WNP-103 103 103
TRANSAL T A
TOTAL RESOURCES 1384 1316 1273 1318 1552 1621 1352 1157 1063 1093 1329 1423 1323
MAINTENANCE
CoIslrlp
RCT
CSII
Kettle Falls
KFCT
Clark Fork Hydro
Spokane River Hydro
NET RESOURCES 1384 1316 1273 1318 1399 1575 1352 1157 1063 1093 1329 1423 1307
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dee AVE
SUAPLUSI(DEFICIT)110 218 361 475 278 117 109 141
OTHER REQUIREMENTS
SURPLUSI(DEFICIT) ON/OFF PEAK
ON PEAK
OFF PEAK
AVERAGE
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dee AVE55 55 180 288 377 423 170 (154) (113) (80) 119 66 116(16) 14 123 342 545 416 236 72 53 115 163 17233 23 110 218 361 475 278 18 (31) (21) 117 109 141
c: Groce
Thackston
Lafferty
KaJich
Storro
Emerson
Warne
Gorton
Bryan
Winters
Gruber
Norwood
Stockinger
20
0
4

A
v
e
r
a
g
e

S
u
r
p
l
u
s

(D
e
f
i
c
i
t
)
Wi
t
h

H
y
d
r
o

a
n
d

L
o
a
d

V
a
r
i
a
b
i
l
i
t
y

-
-

9
0
0
/0

a
n
d

9
5
0
/0

Co
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
s
Mo
n
t
h
l
v

A
:t
:
:
:;
:
:C1
)
:::
:
J
:::
:
J
(J
)
lU
U
U
90
0
80
0
70
0
.,
.
.,
.
60
0
50
0
40
0
.,
.
30
0
..
.
20
0
...
.
.
.
1
1
1
1
...
10
0
Jil
l
..
.
.
.
10
0
20
0
-3
0
0
40
0
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
Se
p
Oc
t
No
v
De
c
AV
E
-+
-
2
0
0
4

A
v
e

Su
r
p
l
u
s
(
D
e
f
l
c
l
t
)
11
0
21
8
36
1
47
5
27
8
11
7
10
9
14
1
+9
0
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
on
e
-
t
a
l
l

t
e
s
t
21
7
20
4
26
2
40
5
58
2
71
6
55
5
13
2
27
6
28
8
31
6
+9
5
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
o
n
e
-
ta
l
l

t
e
s
t
27
0
25
7
30
6
45
9
64
6
78
6
63
5
16
6
10
2
11
4
32
2
34
0
36
7
90
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
o
n
e
-
t
a
l
l

t
e
s
t
15
1
16
0
-4
2
14
0
23
4
-9
8
13
4
12
5
-7
0
95
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
o
n
e
-
ta
i
l

t
e
s
t
20
4
21
3
16
4
13
2
16
4
15
6
12
2
20
0
4

H
e
a
v
y

L
o
a
d

H
o
u
r

S
u
r
p
l
u
s

(D
e
f
i
c
i
t
)
Wi
t
h

H
y
d
r
o

a
n
d

L
o
a
d

V
a
r
i
a
b
i
l
i
t
y

-
-

9
0
0
/0

a
n
d

9
5
0
/0

C
o
n
f
i
d
e
n
c
e

In
t
e
r
v
a
l
s
th
l

A
::s ::s
10
0
0
ve
r
a
g
e
s
90
0
80
0
70
0
60
0
..
50
0
40
0
...
.
.
.
.
.
""
"
"

.1
8
30
0
,.

20
0
:/
f
10
0
..
.
.
.
.
...
.
.
.
t
I
l
l
...
.
.
.
.
.
.
.
.
.
""
'
I
I
I

\.
..
.
.
.
.
10
0
'4
1
1

""
'
"
20
0
..
.
30
0
iii

40
0
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
Se
p
Oc
t
No
v
De
c
AV
E
-+
-
2
0
0
4

H
L
H

Su
r
p
l
u
s
(
D
e
f
l
c
l
t
)
18
0
28
8
37
7
42
3
17
0
15
4
11
3
11
9
11
6
+9
0
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
on
e
-
t
a
i
l

t
e
s
t
27
4
27
2
36
8
49
0
51
5
59
2
47
1
-1
9
25
2
19
1
28
1
+9
5
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
o
n
e
-
ta
i
l

t
e
s
t
33
7
33
4
42
2
54
8
55
5
64
0
55
8
29
1
22
7
32
9
90
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,

o
n
e
-
ta
l
l

t
e
s
t
16
4
16
2
23
9
25
4
13
1
25
9
20
7
17
8
95
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,

o
n
e
-
ta
l
l

t
e
s
t
22
7
22
4
19
9
20
6
21
8
29
0
23
5
20
6
20
0
4

L
i
g
h
t

L
o
a
d

H
o
u
r

S
u
r
p
l
u
s

(
D
e
f
i
c
i
t
)
Wi
t
h

H
y
d
r
o

a
n
d

L
o
a
d

V
a
r
i
a
b
i
l
i
t
y

-
-

90
%

a
n
d

95
0
/
0

Co
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
s
th
l

A
C1
)
10
0
0
ve
r
a
g
e
s
90
0
80
0
70
0
60
0
'"
'
"
50
0
40
0
if

'1
"
1
'"
'
"
30
0
.
p
o
l
..
.
"'"
20
0
...
.
p
o
l
'"
"

".

'"
'
"
'"
"
'"
'
"
10
0
...
.
.

..
.
.
.
..
.
"'"
..
0
1
1
.
.
.
...
-1
0
0
20
0
-3
0
0
40
0
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
Se
p
Oc
t
No
v
De
c
AV
E
'-
'
-
2
0
0
4

L
L
H

Su
r
p
l
u
s
(
D
e
f
i
c
l
t
)
12
3
34
2
54
5
41
6
23
6
11
5
16
3
17
2
+9
0
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,

o
n
e
-
ta
l
l

t
e
s
t
14
9
12
5
12
2
29
3
54
7
75
9
65
1
34
0
11
9
12
6
20
6
28
1
31
0
+9
5
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
o
n
e
-
ta
l
l

t
e
s
t
19
1
16
6
15
4
34
2
60
6
82
1
71
9
37
0
13
3
14
7
23
3
31
5
35
0
90
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
o
n
e
-
ta
i
l

t
e
s
t
13
7
15
7
13
7
33
1
18
1
13
2
95
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
o
n
e
-
ta
l
l

t
e
s
t
17
9
19
8
12
6
26
9
11
3
10
2
~~~'iI'ST
Corporation
Interoffice Memorandum
Energy Resources
DATE:February 09,2001
TO:Ed Groce
FROM:Steve Silkworth
SUBJECT:2003 L&R Position Summary
Ed - This memo summarizes Avista s power supply position for the year 2003 under a variety of
conditions. The information includes hydro and load variability statistics to depict potential
impacts to our system due to weather events.
Attached hereto is a summary of the following in spreadsheet and graphical format:
2003 L&R with all machines dispatched to emissions limits, with hydro and load variability
2003 L&R without Rathdrum and NE CT's operating, with hydro and load variability
2003 L&R under critical water conditions, with load variability only
Assumptions
On-off peak load is from Sandee Warne s budget
WNP - 3 Requirements modeled to economics
Hydro and load variability calculated from 50-year statistics
If you have any questions, please call me on extension 8093.
Distribution:
Pat Gorton
John Emerson
Clint Kalich
Jason Thackston
Bob Lafferty
2003 Total Energy Requirements (aMW)
02.02-2001
Resources Dispatched to Emission limits
2003 Jan Feb Mar ADr May Jun Jul Aug SeD Oct Noy Dee AVE
J.Q!Q!
NelSyslem LD8d 1191 1136 1003 943 918 923 925 957 901 954 1057 1159 1006
(Includes Potlatch 22)
ONTRACT REQUIREM
PACIFICORP 94 SALE
PACIFICORP EXCHANGE
PGE CAPACITY
WNP.3
NICHOLS PUMPING NET OF PGE
ENTITLEMENT/SUP RETURN
CANADIAN ENTITLEMENT
TOTAL REQUIREMENTS 1294 1240 1106 1045 978 1048 1021 1094 1045 1059 1154 1252 1111
HYDRO RESOURCES
System and Mid C Normal Water 512 536 543 595 849 903 597 390 301 330 448 566 548
Black Creek Hydro
Small Power
Upriver Gross
THERMAL RESOURCES
CoIslrlp 196 196 196 196 196 196 196 196 196 196 196 196 196
Ralhdrum 156 150 139 132 130 131 134 116
Rathdrum Add SCR
CSII 257 245 240 244 239 235 232 233 236 244 244 248 241
Kettle Falls - Gas
KellJe Falls
KFCT
CONTRACT RIGHTS
BPA Residential Exchange
ENTITLEMENT & SUPPLE
PGE Cap Rtn
CSPE
PACIFICORP EXCHG RETURN
WNP.3 103 103 103 103
TRANSAL TA 190 190 190 190 190 190 190 190 190 143
TOTAL RESOURCES 1588 1596 1464 1337 1581 1623 1542 1347 1252 1224 1441 1552 1462
MAINTENANCE
CoIslrlp
RCT
CSII
KellJe Falls
KFCT
Clark Fork Hydro
Spokane River Hydro
NET RESOURCES 1588 1596 1464 1337 1472 1575 1542 1347 1252 1224 1441 1552 1449
Jan.Q3 Feb-O3 Mar.o3 Apr.o3 May.o3 Jun.Q3 Jul.o3 Auq..()3 Se0-03 Oct-03 Noy.o3 Dec.o3 AVE
SURPLUSI(DEFICIT)294 356 358 292 494 527 521 253 207 165 287 300 338
OTHER REQUIREMENTS
SURPLUSI(DEACIT) ON/OFF PEAK
ON PEAK
OFF PEAK
AVERAGE
Jan.Q3 Feb-O3 Mar.o3 Apr.Q3 May-03 Jun.Q3 Jul.Q3 Aug.O3 Se~3 Dct.Q3 Noy.Q3 Dec-O3361 400 399 323 426 447 389 54 102 176 324 324160 246 258 197 529 579 638 458 2BB 99 196 222272 334 337 270 471 506 499 232 185 144 264 279
AVE
310
323
316
c: Groce
Thackston
Lanerty
Kalich
Storro
Emerson
Warne
Gorton
Bryan
WInters
Gruber
Norwood
Stockinger
20
0
3

S
u
r
p
l
u
s

(D
e
f
i
c
i
t
)
Wi
t
h

H
y
d
r
o

a
n
d

L
o
a
d

V
a
r
i
a
b
i
l
i
t
y

-
-

9
0
0
/0

a
n
d

9
5
0
/0

C
o
n
f
i
d
e
n
c
e

In
t
e
r
v
a
l
s
Mo
n
t
h
l
y

A
:t
:
it
:
:
II
)
(/
)
:s
:CtI
lU
U
U
90
0
80
0
70
0
60
0
.1
"
"

.1
1
-
50
0
.
I
"
"
.-
-
-
"'
"
40
0
30
0
""
-
.
I
I
-
..
.
.
.
.
;
I
~
i"
"
.1
1
-
20
0
..
.
..
.
10
0
..
.
..
.
."

..
..
.
10
0
Ja
n
Fe
b
Ma
r
Ap
r
Ma
y
Ju
n
Ju
l
Au
g
Se
p
Oc
t
No
v
De
c
AV
E
-+
-
2
0
0
3

A
v
e

Su
r
p
l
u
s
(
D
e
f
l
c
l
t
)
27
2
33
4
33
7
27
0
47
1
50
6
49
9
23
2
18
5
14
4
26
4
27
9
31
6
+9
0
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
on
e
-
ta
l
l

t
e
s
t
45
6
51
6
48
9
45
7
69
2
74
7
77
6
34
7
28
8
24
8
42
3
45
8
49
1

+9
5
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,

o
n
e
-
ta
l
l

t
e
s
t
50
9
56
9
53
3
51
1
75
6
81
7
85
6
38
1
31
8
27
9
46
9
51
0
54
2
90
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,

o
n
e
-
ta
l
l

t
e
s
t
15
2
18
5
25
0
26
5
22
2
11
7
10
5
10
0
14
1
95
%

C
o
n
f
i
d
e
n
c
e

I
n
t
e
r
v
a
l
,
o
n
e
-
ta
l
l

t
e
s
t
14
1
18
6
19
5
14
2
VISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMATION
JURISDICTION:
CASE NO:
REQUESTER:
TYPE:
REQUEST NO.
Idaho
A VU-04-01 / A VU-04-
Potlatch
Data Request
46(A)
DATE PREPARED:
WITNESS:
RESPONDER:
DEPARTMENT:
TELEPHONE:
05/25/2004
Bob Lafferty
Pat Gorton
Corporate Risk
[phone]
REQUEST:
Please provide copies of all agreements, memoranda, codes of conduct or other documents that
relate to A vista Energy s duties and obligations when providing brokerage or gas or electric
supply services to A vista Utilities, A vista Corporation, or any of its affiliates.
RESPONSE:
The following documents are attached in response to this question:
1. Code of Conduct filed with the FERC for Avista Corporation.
2, Code of Conduct filed with the FERC for Avista Energy.
3. Agency Agreement filed with the WUTC, IPUC and OPUC as part of the Benchmark
Mechanism for Avista Utilities' natural gas distribution customers.
The following document was provided in Exhibit 7, Schedule 21 , pages 45 through 53 of 70 and
is responsive to this question:
4. Base Contract for Short-Term Sale and Purchase of Natural Gas between Avista Energy
and A vista Corporation dba A vista Utilities (relates to purchase and sale of natural gas
for electric turbine generation).
The following is an excerpt from the Settlement Stipulation filed with the WUTC on May 31
2002 in Docket No. UE-011595, and approved by the Commission in their Fifth Supplemental
Order dated June 18 2002 in that Docket:
5, Transactions with Avista Energy: The Company agrees that it will not enter into any
electric or natural gas commodity transactions with A vista Energy related to A vista
Utilities' electric operations until the Energy Cost Deferral Balance carries a net credit
balance. This provision does not preclude transactions between the two companies
related to A vista Utilities' natural gas distribution business.
STATEMENT OF POLICY AND CODE OF CONDUCT
WITH RESPECT TO THE RELATIONSHIP BETWEEN
A VISTA CORPORATION AND
ITS POWER MARKETING AFFILIATES
To the maximum extent practicable, the operating employees of Avista
Corp~)fation J~ Avista ) shall operate separately from the operating
employees of its power marketing affiliates.
Avista may not, through its policies or procedures or otherwise, give a
power marketing affiliate any preference over non-affiliated customers.
Any transmission service provided by A vista to a power marketing
affiliate shall be provided under Avista s open access transmission
tariff and posted on Avista s Open Access Same-time Information
System, under the same terms and conditions as those applicable to
purchases of transmission by non-affiliated customers.
No Avista employee shall state or imply that favored treatment shall be
available to customers of an affiliated power marketer as a result of
the marketer s affiliation with Avlsta.
Avista shall not provide any power marketing affiliate with market
information including, but not limited to, transaction specific data.
This prohibition does not apply to data or information that is made
available simultaneously 10 the public.
-..--.- ------. ._-_-
5"-u..Avista.shall maintain its books and records separately from those of its
affiliated power marketers.
6. Any non~power goods and services sold by Avista to an affiliated
power marketer will be priced at the higher of cost or market value,
- .-..---..- -- ----... ..-.--. ...----
and-.any..non.pgwar-.goods -BRd-services.pufchased by Avista from an
affiliated power marketer will be priced no higher than market value.
Avista will not engage in any transaction with an affiliated power
marketer for the purchase or sale of electric power unless the
agreement for such transaction has been filed with and accepted by
the Federal Energy Regulatory Commission in a separate filing under
Section 205 of the Federal Power Act.
RIMS Doc ID 1933868
1 of 1
hltp:/Irimsweb l.ferc.fed.uslrimslDynamiclCS51 15U30Khtrn
. .
FILED
'nFFICE Or: THE SECRETARY
...aT~ 1;~ PF POUCY AND CODE OF CONDUCT
99 APR - J r~~SPEcr TO THE RELA.TlONSHJP BETWEEN~~GYfINC~, AND ITS AFFILIATE, A VISTA CORPORA nON
REGULATORY COMHlsstO~
Avistl Energy. Inc. C'Avim Energy ) shan amduct its business to
COO form to the foLLowjng standards:
To Ehe maximum extent practicabl~ the operating employees of
Avista Energy shall opemte sep8tIltely &om the operating empJoyees
of A vista Corpon.tion.
A vista Energy may not, through paUcies or procedures or otherwise,
o~in or ~ive' preference over nonaffiliated customers of Avista.
Corporation. Any transmission service oburned by Ayista Energy
&om A vista Corporation shall be obtained under th~ \.emu ond
conwtions ofAvista, Corpcmdion s open access. transmiSiion ttIrlfT.
No Avista Energy employee shall state or imply 1hat favored
treatment shall be ILvai1ablc tQ customers as a ~9ult of Avista
Energy s affiliation with Avis1a Corporation.
Avista Energy shRU not accept from Avista Corporation nuu1c~
information, including but Dot limited to, 1ranSactlOrl specific data.
This prohibition does not apply CO data or information that is made
available by Avista Corporation simultzweou~ly (0 the public.
AU marketing information given M). employee of Avista Energy in
confidence by a cu5tom~r maU be kept confidential within A vista
Energy. This requlrement prohibits. sharing stU:n data with Avista
Corporation..
A vista Energy shaH ma.intain its books and records separately from
thO$t: of A vista Corporation.
Any non-poWCI' goo(h and services purclwed by Avisla Energy
tram A vist~ Corporation shall be priced Pl. the higher of cost or
mark.el value, and any non.power goods and &e1Vices sold by Avista.
Energy to Avista CO'tpOraUoo shall be priced no higher than market
value.
...
c,.
6/2/99 4:32
RIMS Doc ID 1933868
~ .
1 nf 1
. I
---..
http://rimsweb1.ferc.fed.uslrimslDynamicJCS5115UE7D.hun
. '
AvistaEnergy sha1l not !!.en electric power to A\'istaCotp~tion
un ICBS the agr=mcnt for such we bIB been filed with and actepted
by the Fodera) Enetay Rcgttlutory Commission in a separate filing
WIder Section 2DS of the Federal Power Act.
612199 4:34 PM
A G EN CY AGREEMENT
This Agency Agreement, effective September!, 1999 (the "Effective Date ), by and
between A vista Corporation ("Corp.) and A vista Energy, Inc. ("Energy ). Each of
Corp. and Energy may be refeITed to individually as "Party" or collectively as "Parties
RECIT ALS
\VHEREAS, Corp. desires Energy to provide management services for its natural gas
supply, transportation and natural gas storage; and
\VHEREAS, Energy desires to provide those management services; and
WHEREAS, the Parties are willing to provide infonnation and resources to best meet the
natural gas supply needs of Corp.s Core Customers; and
WHEREAS, the Parties desire hereby to establish an agreement under which guidelines
and requirements of each Party are established.
NOW THEREFORE, in consideration of the covenants and agreements contained herein
the Parties agree as follows:
DEFINITIONS
A. In this Agreement, including the Recitals and this Article, the following words, tenns
and abbreviations shall have the following respective meanings:
1. Billing Month"shall mean the month immediately Jollowing the Delivery
Month.
2. Business Day shall mean any calendar day, exclusive of Saturdays, Sundays,
and statutory or legal holidays.
3. Capacity Releases shall mean any Corp. transportation released or assigned to
Third Parties.
4. City Gate Station shall mean the point of interconnection between Corp.s gas
distribution system and any of its interconnecting pipelines.
5. Core Customers shall mean those customers who take gas service from Corp.
under respective gas sales tariffs.
6. Day shall mean a period of 24 consecutive hours beginning and ending at 0700
hours PCT. The reference date for any day will be the calendar date on which the
24 hour period starts.
7. Delivery Month(s)"shall mean the month or any portion of a month during
which Gas is delivered to Corp.
8. Delivery Point"shall mean the location or locations at which Gas is delivered to
and recei ved by Corp. or Corp.' s Transportation Customer.
9. Force Majeure" shall mean any cause beyond the reasonable control of the
Party affected, including, without limitation, loss of Gas supply or Transportation
Interruption affecting Energy s ability to deliver Gas at the Delivery Point, failure
of or threat of failure of facilities, flood, earthquake, stonn, fire, lightning,
epidemic , war, riot, civil disturbance or disobedience, sabotage, restraint by court
order or public authority, any change in law or regulation under which Energy
continued perfonnance would be unlawful or coptrary to such law or regulation
action or non-action by, or failure to obtain or maintain the necessary
authorizations or approvals from, any governmental agency or authority, which by
exercise of due diligence such Party could not reasonably have been expected to
avoid and which by exercise of due diligence it has been unable to overcome.
10. Gas shall mean the residue remaining after natural Gas produced from wells
has been subjected to any or all of the following permissible processes:
(a) the removal of any constituent parts other than methane, and the removal of
methane to such extent as is necessary in removing other constituents, and
(b) the compression , regulation, cooling, cleaning or any other chemical or
physical process other than the addition of dilqents. such as gir or nitrogen, to
such extent as may be required in its productIon, gathering, transmission,
storage, removal from storage and delivery to Corp.
11. Gas Solutions shall mean the data gas management system developed by Corp.
12. Index Adder shall mean a fixed amount expressed in cents per decathenn that
. will be added to the Weighted Average Index Price.
13. Month"shall mean the period beginning at 0700 hours PCT on the first day of
the calendar month and ending at 0700 hours PCT on the first day of the next
succeeding calendar month.
14. PCT"shall mean Pacific Clock Time, either Daylight or Standard, whichever is
in effect.
15. Primary Transportation and Stora2e Capacity"shall mean the transportation
capaci ty detailed in Exhibit "
16. Purchased Volumes shall mean decatherms received at Receipt Points, in the
same ratio as the Weighted Average Index Price, delivered to Corp.s Core
Customers. The volume of Gas delivered to Corp.s Core Customers will be
grossed up for the appropriate fuel-in-kind in the same ratio as the Weighted
A verage Index Price.
17. Receipt Point"shall mean the initial point at which Gas is received into
transportation capacity held in Corp.' s name , generally these points are Sumas at
the British ColumbialUS Border, various points into Northwest Pipeline in the
Rocky Mountains and AECO C at the Nova Inventory Transfer point.
18. Transportation Interruption" shall mean any inteITUption of the transportation
service required for delivery of Gas under this Agreement which does not result
from either Party failure to use reasonable efforts to obtain the required
transportation. The parties shall not be required to obtain firm transportation for
Interruptible Service.
19. Transportation Customer"shall mean any third party that has entered into a
contract with Corp. to deliver Gas at one of Corp.' s City Gate Stations.
20. Variable Chan!es shall mean pipeline charges that are based on volumetric
flow and relate in this Agency Agreement to volumes of Gas transported on
Corp.' s transportation contracts.
21. Weighted Average Index Price shall mean a weighted average of the
published index price of Gas based on 1) "Inside FERC'" Canadian border into
Northwest Pipeline, 2) "Inside FERC'" Rocky Mountain into Northwest
Pipeline, 3) "Canadian Gas Price Reporter " AECO C/NIT in USlMMBtu. The
weighting of the prices from each of the supply basins shall be as approved by the
state regulatory commissions for the volume of Gas associated with Core
Customers in the respective states.
B. Any word, phrase, abbreviation, or expression that is not defined in this Agency
Agreement and that has a generally accepted meaning in the custom and usage of the
natural Gas industry shall have that meaning in this Agency Agreement.
C. The headings in this Agency Agreement are inserted for reference purposes only, and
shall not be considered or taken into account in construing the terms or provisions of
any Article or section hereof, nor in any way to qualify, modify, or explain any such
term or provision.
II.
TERM OF AGENCY AGREEMENT
Services under this Agency Agreement shall commence on the Effective Date, and shall
continue in full force and effect until March 31 , 2002. Thereafter, this Agency
Agreement shall continue in effect from year to year unless either Party gives s~x (6)
months prior written notice of desire to terminate this Agency Agreement.
III.
APPOINTMENT OF AGENT
A. Corp. hereby authorizes and designates Energy as an authorized representati ve for the
purpose of arranging for Gas purchases by Corp. as directed by, and on behalf of,
Corp. and in accordance with the terms of this Agency Agreement. Energy will act as
agent and manage existing Gas supply, transportation and storage contracts held by
Corp. for the purpose of serving Core Customers in the jurisdictions in which Corp.
has regulatory approval for a Natural Gas Benchmark Mechanism. Any additional
supply contracts deemed necessary by Energy to serve Corp. Core Customers, for the
tenD of this Agency Agreement, would be negotiated by Energy on behalf of Corp.
B. Further Corp. hereby authorizes and designates Energy as an authorized
representative for the purpose of managing its Jackson Prairie Storage (JP) and
Plymouth Liquified Natural Gas Storage (LNG) facilities on behalf of Corp. and in
accordance with the terms of this Agency Agreement.
C. Corp. agrees to use its best efforts in accordance with prudent business practices and
commonly and regularly observed industry standards to furnish necessary infonnation
and direction to Energy and to cooperate with Energy in the perfonnance of this
Agency Agreement.
IV.
SERVICES PROVIDED
During the term of this Agency Agreement Energy shall utilize its best efforts in
accordance with prudent business practices and commonly and regularly observed
industry standards to perform the following services as an authorized representative of
Corp. Corp. shall actively cooperate with Energy in the development and implementation
of the following:
A. Gas Supply
1. Tasks and responsibilities of Energy:
a. Energy will act as agent to manage and pay all of Corp.' S CUITent Gas supply
contracts acquired to serve Corp.' s Core Customers for the tenD of this
Agreement.
b. Energy ~ill provIde for q.aily Gas supplies to. be delivered to meet the seven-d~y
forecast of Core Customer loads Corp. provides in.accordance with Section N.
2(~-
c. Energy will be responsible for any pena1tief' incuITed as a result of not providing.
~ __- ".
Gas supplies in accordance with Corp.s seven-day forecast, including updates
within the Gas Day, with the exception that penalties related to interruptions as a
result of Force Majeure would be governed by supply or transportation contract
provIsIons.
d. Energy will be responsible for the development, negotiation and conclusion of
any additional contracts and agreements necessary to obtain adequate supplies of
Gas.
e. Energy will be responsible for monthly and daily strategies to fulfill the annual
Gas supply plan provided by Corp.
Energy will be responsible for communications with Gas suppliers to identify
market changes and status and minimize operational supply disruptions.
g. Energy will be responsible for management of nominations to facilitate supplye. and purchase commitments. Each day Corp. shall be entitled to request delivery of
the volumes necessary to meet forecasted Core Customer load, and Energy shall
initiate nominations to deliver the required volumes.
11 Energy will act as agent, at its expense, to acquire any replacement supply in the
event of short-term shortage (curtailments) or long-term shortage (supply failure).
1. Energy with the assistance of Corp.s long- and short-tenn forecasts will be
responsible for ongoing supply/demand review and supplementation, including
supplemental market development and management to facilitate supply and
transportation contract cornJ:11jtments and/or minimize penalties.
J. Energy is responsible for re-marketing of supplies and transportation in the event
'-
that Corp. is unable to take delivery of finn commitments.
k. Energy will act as agent and acquire Gas in Corp.' s name only for supplies that
:::- are transported under Corp.' s transportation contracts with the applicable
pipelines.
. Tasks and responsibilities of Corp.
~.
Corp. will take responsibility for providing a seven-day forecast of its Core
Customer loads. The seven-day forecast may be updated by Corp. to Energy
twice during a Gas Day to allow for increases or decreases in actual Core
Customer loads compared to forecasted Core Customer loads. Any updates
would be provided in a timely manner to meet GISB nomination timelines or be
volumetric changes that could be met with Jackson Prairie Storage nominations.
b. Corp. will provide an annual Gas supply plan, based on 30 year average weather":0' patterns , by April 30th for the following two years with updates by July 31st and
September 30th.
s.. Corp. will accept and process all operator nominations to accept supplie~'
managed by Energy for delivery to Corp.' s Core Customers.
B. Transportation of Gas
1. Tasks and responsibilities of Energy:
a. Energy will be responsible for the nominations and flow of Gas supplies on all
transportation contracts held by Corp.
b. Energy will be responsible for review of operational requirements of Corp.s Core
Customers and conformance to changes in pipeline operations to maximize
deliveries of required supply.
d. Energy has the option to optimize transportation capacity, daily and seasonally, as
long as operational constraints of Corp. distribution system and Corp.' s Core
Customer s needs are met.
e. Energy will be responsible for management of pipeline imbalances and
management of day-to-day inventory levels on Corp.s system related to Corp.
Core Customers.
f. Energy will be responsible for any penalties, inteITUptible or overrun charges from
. pipelin~s relating to nominations or as a result of capacity releases.
g. Energy will be responsible for daily dispatching communications with suppliers
pipelines and Corp.
2. Tasks and responsibilities of Corp.
a. Corp. will retain ownership of all transportation contracts and will process and
pay all invoices.
b. Corp. will be responsible for planning for long-term acquisitions of transportation
to meet anticipated customer load growth and will secure transportation capacity
as available to complement increases in demand.
c. Corp. will be responsible for management of Corp. Transportation Customers
pipeline imbalances and for their day-to-day inventory levels on Corp.s system.
d. Corp. will accept and prOcess all operator nominations to accept supplies
managed by Energy for delivery to Corp.s Core Customers.
C. Storage Management
1. Tasks and responsibilities of Energy:
a. Energy will assume operational management of Corp. ' s Jackson Prairie and
Plymouth LNG which will include all nominations for injections and withdrawals
for Corp.' s Core Customers and Corp. ' s two 7 "C" release customers (BC Gas
and Cascade Natural Gas);
b. Energy will meet all operational fill requirements of each project and insure that
each of Corp.' s several accounts are filled to maximize winter operational
flexibility.
c. Energy will use these facilities as available to meet the daily load requirements
Corp.' s Core Customers , however to the extent these requirements are not
compromised Energy may inject and withdraw gas from these facilities.
..\
2. Tasks and responsibilities of Corp.
a. Corp. will continue to handle all responsibilities related to the Jackson Prairie
Management Committee.
b. Corp. will process and pay all invoices.
D. Regulatory Cooperation
Energy will cooperate with Corp. to provide information to regulatory commissions for
audit purposes. Energy will make person~el available to provide timely responses to
regulatory commission inquiries related to services provided pursuant to this Agency
Agreement.
E. Administration
1. Corp. and Energy will cooperate to provide each other with the necessary data in a
timely manner to facilitate this Agency Agreement. Initially the Gas Solutions
software will provide the vehicle for much of the data transfer. Corp. and Energy will
cooperate on any modifications to Gas Solutions and the cost of such modifications
will be paid by the benefiting Party, if benefit accrues to both Parties, then the costs
will be shared under an agreed ratio before modifications are made. Modifications to
Gas Solutions will be under the direction of Corp.
2. Tasks and responsibilities of Energy:
a. Energy will be responsible for data entry and validity of such, into Gas Solutions
related to Core Customer s supply Nominations and Confirmed Nominations to
Corp. City Gate Stations.
b. Energy will be responsible for all reports related to any export and import
requirements.
c. Energy may use Corp.' s existing export licenses up to authorized limits, any
necessary extensions or renewals would be done by Energy on Corp.' s behalf.
3. Tasks and responsibilities of Corp.
a. Corp. will be responsible for data entry and validity of all City Gate Station Gas
daily flows and daily usage for all Transportation Customers and confirmed
operator nominations, into Gas Solutions.
b. Corp. will be responsible for preparation of necessary amendments, except those
that may relate to capacity releases of up to one year, for transportation contracts
and tariffs.
c. Corp. will be responsible for administration of curtailment and/or force majeure
actions as they relate to Corp. Transportation Customers in cooperation with
Energy. Corp. will continue its current practice of passing on any pipeline
. entitlements to Transportation Customers.
d. Corp. will be responsible for all communications with its Transportation
Customers and/or their Agents and will provide reports on usage and deliveries
and prepare billings.
F. Penalties
1. The Parties acknowledge that pipeline and other operating conditions may result in
unintentional fluctuations in the amount of Gas being delivered. The Parties shall:
a. use reasonable efforts to avoid imbalances and maintain the delivery and receipt
of Gas as scheduled with the pipelines delivering and receiving the Gas, and
b. cooperate to rectify any imbalances thatmay occur and avoid the imposition of
penalties.
2. During any ' month , a transportation invoice is received with a penalty, oveffiln or
other incremental charge (the "Penalty Charge ) from a delivering or receiving
pipeline, the Parties shall use their best efforts to detennine the cause of the Penalty
Charge and whether it was validly charged.
3. If any Penalty Charge results from the actions of either Party (the "Responsible
Party ) the Responsible Party shall pay the Penalty Charge. If the Penalty Charge is
billed to the other Party, at its discretion t~e other Party may:
a. charge the Responsible Party the amounts billed for the Penalty Charge, or
b. set off the amounts billed against any amounts owed by the other Party to the
Responsible Party.
NOMINA TIONS
Before 2:30 p.m. each Business Day, Corp. will provide a seven-day forecast of
estimated Core Customer loads. This forecast will include actual loads for the six prior
days. An example of the fonnat for the seven-day forecast is provided in Exhibit "
This estimate will be updated at 10:30 a. m. each Business Day to provide the prior days
actual Core Customer usage. Energy, during the tenn of this Agreement, will initiate all
Shipper nominations to facilitate delivery of required Gas supplies. Corp. will initiate all
Transporter nominations to facilitate delivery of Gas supplies for Core Customers and
Transportation Customers.
VI.
BILLINGS and P ~NTS
A. Each month Energy will bill Corp. for Gas purchased and delivered to Corp.sCore
Customers according to calculations approved by each regulatory jurisdiction
examples in Exhibits C, D, E and F. Except as otherwise provided within this
Agency Agreement, Energy will hold Corp. and its customers hannless for costs
related to Gas purchases that exceed this calculation.
B. Each month Corp. will process and pay invoices for transportation costs. Corp. will
bill Energy (or credit against Energy s bill) for any variable transportation costs not
related to volumes of Gas delivered to Corp.s City Gate for Core Customers. Corp.
agrees to reimburse Avista Energy for upstream transportation costs in the ABC and
Engage long-tenn contracts. Except as otherwise provided within this Agency
Agreement, Energy will hold Corp. and its customers hannless for costs related to
Gas purchases that exceed approved calculations by each regulatory jurisdiction.
C. Energy shall send to Corp. monthly, an invoice for the previous month's purchases
per the calculations mentioned in Section VI A and B, examples Exhibits C, D, E and
F (inclusive of any supporting detail) on or before the 18th of each month.
D. Energy will provide Corp. with infonnation on the release of Corp. pipeline capacity
and any Off-System Sales for interjurisdictional purposes and with pipeline
infonnation to verify Purchased Volumes and Variable Charges.
E. Corp. shan pay to Energy the full amount of the invoice on or before the 25th of each
month. If the 25th is not a Business Day; (a) and the previous day is a Business Day,
Corp. shall pay on that day; or (b) if the previous day is not a Business day, Corp.
shan pay on the next Business Day. Payment shall be by wire transfer to an account
designated by Energy.
F. If Corp. fails to pay the entire amount specified on the invoice when it is due, interest
shan' accrue on the unpaid portion of the invoice, which represents Corp.' s obligation
to Energy. Interest shall accrue at a rate per annum equal to the then current Prime
Rate of interest charged by Bank of America from time to time.
G. If Corp. fails to pay the entire amount specified on the invoice when it is due, Energy
shall provide written notice of default to Corp. demanding payment (the "Demand
Notice
H. If Corp., in good faith, disputes the amount of any bill or part of a bill then , it shall
pay the amounts that it believes are correct in accordance with the procedure set out
in Section VI.
I. Within 30 days of a detennination by Corp. and Energy that Corp. has been
overcharged or undercharged Energy shall refund to Corp. the amount of any
overcharge collected by it, or Corp. shall pay to Energy the amount of any
underc;harge owed by it. If the amount is not so paid, interest shall accrue on the
unpaid portion as provided in Section VI F.
J. Corp. and Energy shall have the right to examine the books , records and charges of
the other, to the extent necessary to verify the accuracy of any statement, chart or
computation made under the provisions of this Agreement, at any reasonable time.
Any review of records relating to any invoice shall be made within 24 months of the
receipt of the invoice.
VII.
SALES TO THIRD PARTIES
Corp. is appointing Energy as agent for the management of Gas ' or transportation rights
purchased or sold to or from a Third Party. Energy shall indemnify and hold harmless
Corp. from all claims of Third Parties. Energy shaH bear the credit risk associated with
non-payment by any party with regard to transactions under this Agency Agreement.
Corp. shaH notify Third Parties that Energy has been designated Corp.' s agent for receipt
transport and sale of Gas.
VIII.
MEASUREMENT AND TITLE
A. Measurement, Testing, Quality and Delivery Pressure
1. Volume and gross heating value of all Gas purchased shall be measured by the
delivery pipelines at the Point(s) of Receipt in accordance with the general tenns
and conditions included in the delivering pipelines' tariff.
2. The Parties agree that they shall require suppliers of Gas to insure that the quality,
heating value, pressure and temperature of Gas sold and delivered at the Point(s)
of Delivery will meet the requirements in the delivering pipelines' General Tenns
and Conditions for its Service Agreements applicable to their systems at the
Point(s) of Delivery, provided, neither Party warrants or guarantees to the other
the quality, heating value, pressure or temperature of Gas delivered to the Point(s)
of Delivery.
B. Title, Warranty and Adverse Claims
1. Title to the Gas shall reside with Corp. Energy warrants that the Gas is free and
clear of any encumbrances or adverse claims of any kind. Corp. warrants that it
has the right to receive the Gas it purchases from Third Party Suppliers.
2. Energy shall indemnify Corp. for all claims, proceedings, losses, costs and
damages arising out of any adverse claim to the Gas procured on Corp.s behalf.
IX.
LA WS and REGULA TORY AUTHORITIES
A. This Agency Agreement shall be interpreted in accordance with the laws of the State
of Washington.
B. This Agency Agreement and the rights and obligations of the parties are subject to all
applicable present and future laws, rules, regulations and orders of any regulatory or
legislative body, or other duly constituted authority having jurisdiction over Corp. or
Energy.
TRANSFER and ASSIGNMENT
The Parties may only assign the rights and obligations under this Agency Agreement with
the written consent of the other Party.
XI.
NON-EXCLUSIVE ARRANGEMENT
Nothing in this Agency Agreement shall prohibit Energy from acting as an agent for
persons other than Corp. or from engaging in the business of selling. and reselling Gas
and other energy products or services to persons other than Corp.
XII.
NOTICES
Any notic~s with respect to this Agency Agreement shall be deemed given or made when
delivered by prepaid registered mail , personal delivery, electronic mail, or facsimile to:
FOR CORP.
For Contract Compliance or Operational Matters
A vista Corporation
1411 E. Mission Avenue
Spokane, Washington 99220
Telephone: [phone]
Facsimile: [phone]
Attention: Natural Gas Administrator
FOR ENERGY:
A vista Energy, Inc.
201 W. North River Drive, Suite 610
Spokane, Washington 99201
Telephone: [phone]
Facsimile: [phone]
Attention: Director, Energy Marketing
Additional Notices for Contract Compliance Matters:
President and Chief Operating Officer
A vista Energy, Inc.
201 W. North River Drive, Suite 610
Spokane, Washington 99201
Telephone: [phone]
Facsimile: [phone]
XIII.
GENERAL PROVISIONS
A. Every notice , statement or bill shall be considered delivered when received by
facsimile or mail. If any notice, statement, bill or other document is delivered by
hand, electronic mail, or facsimile to the other Party, it shall be deemed to have been
received as soon as delivery or transmissfon has been made.
B. Either Party may change its addresses for purpose of receiving notices from time
time by giving written notice of the change to the other Party.
C. Energy has no authority to commit Corp. to obligations that would extend beyond the
tenn of this Agency Agreement without Corp.' s prior written agreement.
D. The parties shall execute and deliver all documents , provide all infonnation, and take
or forebear' from all such action as may be necessary or appropri"ate to achieve the
purposes of this Agency Agreement.
E. This Agency Agreement shall be binding upon and inure to the benefit of the parties
and their heirs, executors, administrators, successors, legal representatives and
assigns. Parties hereto agree that this Agency Agreement shall not be assigned
without prior written approval of the non-assigning Party.
F. None of the provisions of this Agency Agreement shall be for the benefit of or
enforceable by any creditors of the parties hereto.
. G. This Agreement may be executed in counterparts, all of which together shall
constitute one agreement binding on all the parties.
Signed
A vista Corporation A vista Energy, Inc.
2.~.
(Name)
~ 7S-1 1"\'1,,\
(Date (Date)
Attest:
(Name)
Attest: m~~ 2w
(Name)
Th
e

W
a
s
h
i
n
g
t
o
n

Po
w
e
r

C
o
m
p
a
n
y
.
,
I
b
l
t

-
Pr
i
m
a
r
y

P
i
p
e
l
i
n
e

T
r
a
n
s
p
o
r
t
a
t
i
o
n

a
n
d

St
o
t
t
1
g
e

R
e
s
e
r
v
a
t
i
o
n

C
o
n
t
r
a
c
t
s

a
n
d

V
o
l
u
m
e
s
LI
n
e
Wa
s
h
l
n
g
t
o
n
/
l
d
a
h
o
Or
e
g
o
n
To
l
a
l
No
.
PI

e
l
l
n
e
Co
n
t
r
a
c
t
Wi
n
t
e
r
Su
m
m
e
r
Wl
n
l
e
r
Su
m
m
e
r
Wi
n
t
e
r
Su
m
m
e
r
No
r
t
h
w
u
t

PI
p
e
l
i
n
e
Tr
a
n
s
p
o
r
t
a
l
l
o
n

R
e
s
e
r
v
a
l
l
o
n
Se
e

N
o
l
e

t
10
0
0
1
0
13
3
27
0
13
3
27
0
87
1
87
1
16
4
,
14
1
16
4
14
1

D
t
h
Tr
a
n
s
p
o
r
t
a
l
l
o
n

R
e
s
e
r
v
a
l
l
o
n
10
0
0
6
0
86
0
86
0
.
1
4
86
0
14
,
86
0

D
t
h
Tr
a
n
s
p
o
r
t
a
l
l
o
n

R
e
s
e
r
v
a
l
l
o
n
10
0
1
6
4
00
0
00
0
00
0
00
0

D
t
h
Ja
c
k
s
o
n

P
r
a
i
r
i
e

T
F
-
10
0
3
1
4
64
7
64
7
64
7
'
64
7

D
t
h
Ja
c
k
s
o
n

P
r
a
i
r
i
e

T
F
-
2
10
0
3
1
5
25
9
25
9
25
9
25
9

D
t
h
Pl
y
m
o
u
t
h

T
F
-
10
0
3
1
6
42
0
42
0
42
0
42
0

D
t
h
Pl
y
m
o
u
t
h

T
F
-
10
0
3
1
7
47
2
41
2
47
2

D
t
h
Ca
p
a
c
i
t
y

D
e
m
a
n
d
-
S
t
o
r
a
g
e

R
e
s
e
r
v
a
l
l
o
n
10
0
4
0
3
56
5
56
5
56
5
95
,
56
5

D
t
h
Re
s
e
r
v
a
l
l
o
n

-

S
t
o
r
a
g
e

R
e
s
e
r
v
a
l
l
o
n
10
0
4
0
3
62
3
62
3
62
3
62
3

D
t
h
Ca
p
a
c
i
t
y

-

S
t
o
r
a
g
e

R
e
s
e
r
v
a
l
l
o
n
10
0
6
0
2
17
2
,
40
0
17
2
,
40
0
17
2
,
40
0
17
2
,
40
0

D
t
h
Re
s
e
r
v
a
l
l
o
n

-

S
t
o
r
a
g
e

R
e
s
e
r
v
a
l
l
o
n
10
0
6
0
2
20
0
20
0
20
0
20
0

D
t
h
-C
a
p
a
c
i
t
y

-

S
t
o
r
a
g
e

R
e
s
e
r
v
a
t
i
o
n
10
0
6
0
7
15
3
31
5
15
3
31
5
15
3
31
5
15
3
31
5

D
t
h
Re
s
e
r
v
a
l
l
o
n

-

S
t
o
r
a
g
e

R
e
s
e
r
v
a
t
i
o
n
10
0
6
0
7
22
,
00
0
22
,
00
0
22
,
00
0
22
,
00
0

D
t
h
PG
&
E

Gu

Tr
l
f
n
l
m
l
.
.
l
o
n
F-
O
0
1
7
7
42
3
00
0
42
3
00
0

D
t
h
00
1
7
8
78
2
78
2
78
2
78
2

D
t
h
02
5
9
1
00
0
00
0
50
0
50
0
50
0
50
0

D
t
h
02
8
9
2
00
0
00
0
00
0
10
,
00
0

D
t
h
F-
0
2
8
5
7
30
,
00
0
00
0
00
0
00
0

D
t
h
02
8
5
8
40
0
40
0
40
0
40
0

D
t
h
F-
O
0
2
0
4
62
0
62
0
Dt
h
00
1
8
2
14
0
14
0
14
0
14
0

D
t
h
NO
V
A
19
9
4
-
85
9
8
9
-
28
.
28
.
28
.
28
.
2
1
0
0
0

m
3
19
9
4
-
89
3
8
7
-
28
1
.
28
1
.
28
1
.
7
28
1
.
7

1
0
0
0

m
3
19
9
4
-
86
1
4
6
-
30
4
.
30
4
.
30
4
.
30
4
.
8
1
0
0
0

m
3
19
9
5
-
73
7
9
0
-
45
0
.
45
0
.
45
0
.
45
0
.
2
1
0
0
0

m
3
95
-
00
0
0
5
-
29
3
.
29
3
.
45
4
.
45
4
.
74
7
.
4
74
7
.
4
1
0
0
0

m
3
95
-
00
1
2
3
-
73
.
73
.
73
.
73
.
3
1
0
0
0

m
3
IG
l
f
T
e
n
a
s
k
a
28
7
.
28
7
.
28
7
.
28
7
.
6
1
0
0
0

Ne
w

C
o
n
t
r
a
c
t
58
7
.
58
7
.
14
5
.
14
5
.
73
2
.
73
2
.
3
1
0
0
0

m
3
No
v
a

D
e
l
i
v
e
r
y

C
a
p
a
c
i
t
y

u
n
d
e
r

W
e
s
t
c
o
a
s
t
(E
n
g
a
g
e
)

C
o
n
t
r
a
c
t
Se
s

N
o
l
e

43
8
.
43
8
.
43
8
.
43
8
.
7
1
0
0
0

m
3
No
v
a

D
e
l
i
v
e
r
y

C
a
p
a
c
i
t
y

u
n
d
e
r

A
E
C

C
o
n
t
r
a
c
t
Ss
e

N
o
l
s

40
7
.
40
7
.
18
6
.
18
6
.
59
4
.
59
4
.
1
1
0
0
0

m
3
No
v
a

F
i
r
m

S
e
r
v
i
c
e

R
e
c
e
i
p
t

u
n
d
e
r

W
e
s
t

c
o
a
s
t

C
o
n
t
r
a
c
t
Se
e

N
o
l
e
s

3
&

4
.
43
8
.
43
8
.
43
8
.
43
8
.
7
1
0
0
0

AN
a
WW
P
-
54
1
.
9
84
3
.
54
1
.
84
3
.
7
1
0
0
0

m
3
FS
-
1
W
W
P
44
4
.
44
4
.
44
4
.
44
4
.
9
1
0
0
0

m
3
As
s
i
g
n
m
e
n
t

o
f

W
e
s
t
c
o
a
s
t
43
0
.
4
43
0
.
4
60
0
.
60
0
.
03
0
.
4
03
0
.
4

1
0
0
0

IG
t
f
T
e
n
a
s
k
a

A
s
s
i
g
n
m
e
n
t
28
3
.
28
3
.
28
3
.
28
3
.
6
1
0
0
0

m
3
CP
N
C
-
18
9
.
4
18
9
.
4
10
0
0

m
3
AN
G

F
i
r
m

S
e
r
v
i
c
e

D
e
m
a
n
d

u
n
d
e
r

W
e
s
t
c
o
a
s
t

C
o
n
t
r
a
c
t
Se
e

N
o
l
e

43
5
.
43
5
.
43
5
.
43
5
.
2
1
0
0
0

m
3
'"
'
No
t
e

1
.

V
o
l
u
m
e
s

m
a
y

v
a
r
y

J
u
n
e

Ih
r
o
u
g
h

S
e
p
t
e
m
b
e
r

d
u
e

t
o

P
i
p
e
l
i
n
e

m
i
t
i
g
a
t
i
o
n
.
No
l
e

2
.

V
o
l
u
m
e
s

I
n
c
r
e
a
s
e

N
o
v
e
m
b
e
r

1
o
f

e
a
c
h

y
e
a
r
.
No
l
e

3
.

N
o
v
a

F
i
r
m

R
e
c
e
I
p
t

Qu
a
n
t
i
t
y

I
s

t
o

b
e

m
u
l
t
I
p
l
I
e
d

b
y

1
4
0
%

p
e
r

W
e
s
t
c
o
a
s
t

C
o
n
t
r
a
c
t
.
No
t
e

4
.

A
c
t
u
a
l

c
a
p
a
c
i
t
y

q
u
a
n
t
i
t
y

wi
l
l

v
a
r
y

s
l
i
g
h
t
l
y

e
a
c
h

m
o
n
l
h
,

d
u
e

t
o

A
N
G

f
u
e
l

r
a
t
e

c
h
a
n
g
e
s
.
-'
-
-
'
-
'
""
'
-
"
-
~
'
-
-
-
'
-
'
-
'-
"
'
.
~
.
-
"
~
-
.
-
-
"
-
~
~
-
'
-
-
-
-
-
-
-
-
-
-
,-
-
,
-
-
-
-
-
-
'
-
-
~
"
=~
:
"
~"
"
"
-
~-

..,
.
-
-
-
.
-
-
-
.
-
-
.
.
.
,
-
-.
.
-
-
-
-
-
-
-
-
-
-
-
--
-
-
-
-
-
~-
-
-
-
_
.
_
-
-
-
-
_
.
.
.
.
-

_
OM
_
'
--
.
.

.
..
.
-
-
-
-
-
(a
c
l
u
a
l
-
~

We
d
(a
c
l
u
a
l
-
~

T
h
u
(a
c
l
u
a
l
-
~

Fr
t
(a
c
l
u
a
l
-
~

S
a
t
(a
c
t
u
a
l
-
~

S
u
n
(a
c
l
u
a
l
-
~

Ma
n
Tu
e We
d
Th
u
Fr
t Sa
t
Su
n
Ma
n
AV
I
S
T
A

c
o
n
p
O
R
A
T
I
O
N
L.

\
.
\
L"
'
(~
'
C'
~

~

-
.
.
.
,~

jU
m
m
a
r
y

F
o
r
e
c
a
s
t
Fc
s
t
'
d

C
o
r
e

L
o
a
d
Fe
s
l

H
O
D

F
e
s
t
To
t
a
l
Fo
r
e
c
a
s
t
e
d

H
O
D
Fo
r
e
c
a
s
t
e

F
e
s
t

HO
D

F
e
s
t
To
i
a
l
O
R
Co
r
e

L
o
a
d

S
L

T
NO
T
E
:
If

M
e
d

H
D
D

a
r
e

4
0

o
r

h
I
g
h
e
r
ca
l
l

W
i
l
l
a
m
e
t
l
e

t
o

r
e
c
a
l
l

c
a
p
a
c
I
t
y
(R
E
Q
U
I
R
E
S

4
8

h
o
u
r

n
o
l
l
c
e
)
Ma
d
8/
1

8
/
9
9
8/
1
9
/
9
9
8/
2
0
/
9
9
8/
2
1
/
9
9
8/
2
2
/
9
9
8/
2
3
/
9
9
8/
2
4
/
9
9
8/
2
5
/
9
9
8/
2
6
/
9
9
8/
2
7
/
9
9
8/
2
8
/
9
9
8/
2
9
/
9
9
8/
3
0
/
9
9
De
m
a
n
d
:

M
a
n

8/
2
3
/
9
9
Su
p
p
l
y

M
a
n

8/
2
3
/
9
9
Im
b
a
l
a
n
c
e

Y
e
s
t
e
r
d
a
y
Ov
e
r
(
s
h
o
r
t
)
De
m
a
n
d
:

M
o
n

8/
2
3
/
9
9
Su
p
p
l
y

M
o
n

8/
2
3
/
9
9
Im
b
a
l
a
n
c
e

Y
e
s
t
e
r
d
a
y
Ov
e
r
(
s
h
o
r
t
)
SU
P
P
L
Y
:

W
e
d
SU
P
P
L
Y
:

W
e
d
DE
M
A
N
D
:

W
e
d
SU
P
P
L
Y
:

T
h
u
SU
P
P
L
Y
:

T
h
u
DE
M
A
N
D
:

T
h
u
8/
2
5
/
9
9
8/
2
5
/
9
9
8/
2
5
/
9
9
Ov
e
r
(
s
h
o
r
t
)
8/
2
6
/
9
9
8/
2
6
/
9
9
8/
2
6
/
9
9
Ov
e
r
(
s
h
o
r
t
)
79
5
28
1
67
3
74
9
58
4
84
7
33
,
18
0
79
5
28
1
67
3
74
9
50
8
84
7
10
4
79
5
28
1
67
3
74
9
50
8
84
7
10
4
79
5
28
1
67
3
74
9
50
8
84
7
10
4
79
5
28
1
67
3
74
9
50
8
84
7
33
,
1
0
4
79
5
28
1
67
3
74
9
50
8
84
7
33
,
10
4
79
5
29
9
67
3
76
7
54
6
32
9
33
,
64
2
Av
e
r
a
g
e
:
79
5
28
4
67
3
75
2
52
4
91
6
19
2
Ac
t
u
a
l

A
v
e
r
a
g
e
:
lE
I
..
.
-
Pr
I
o
r

3

d
a
y

A
v
e
r
a
g
e
:
NO
T
E
:
If

S
p
o
k
a
n
e

H
O
D

a
r
e

5
0

o
r

h
I
g
h
e
r
co
n
t
a
c
t

g
a
s

e
n
g
I
n
e
e
r
I
n
g

t
o

a
l
e
r
t

t
h
e
m
of

t
h
e

c
o
l
d
e
r

w
e
a
t
h
e
r

f
o
r
e
c
a
s
t
e
d
.
Mi
k
e

F
a
u
l
k
e
n
b
e
r
r
y

8
4
9
9
(
p
a
g
e
r

8
8
9
-
6
2
0
2
)
Jo
d
y

M
o
r
e
h
o
u
s
e

42
5
3
(
p
a
g
e
r

8
8
9
-
62
3
6
)
Ga
r
y

P
a
r
d
u
n
86
4
8
AI

F
i
s
h
e
r

45
9
0
WA
S
H
I
N
G
T
O
N
/
I
D
A
H
O
Co
r
e

S
u
p
p
l
y

v
s
.

C
o
r
e

D
e
m
a
n
d
Wa
l
l
d

P
G
T

W
e
J
l
d

N
W
f

T
o
t
a
l
PA
I
U
T
E
Co
r
e

S
u
p
p
l
y

v
s
.

C
o
r
e

D
e
m
a
n
d
NW
P
PG
T
To
t
a
l
NW
P
PG
T
To
l
a
l
PG
T
M
e
d

n

M
e
d
La
G
PG
T
M
e
d
SL

T

T
o
t
a
l
WN
I
D

C
o
r
e
To
t
a
l
02
5
49
6
52
1
24
3
13
3
89
7
02
9
02
9
80
5
19
,
83
4
(1
5
,
47
1
)
05
4
49
6
55
0
24
3
20
,
93
8
73
1
79
5
28
1
67
3
74
9
50
8
22
,
84
7
33
,
10
4
(1
,
74
1
)
(1
,
28
1
)
(1
7
7
)
19
9
)
(2
6
5
)
90
9
)
(5
,
37
3
)
PG
T
M
e
d

n

M
e
d
La
G
PG
T
M
e
d
SL

T

T
o
t
a
l
WN
I
D

C
o
r
e
To
l
a
l
02
5
49
6
52
1
24
3
13
3
89
7
02
9
02
9
80
5
19
,
83
4
(1
5
,
4
7
1
)
05
4
49
6
55
0
24
3
20
,
93
8
27
,
73
1
79
5
28
1
67
3
74
9
50
8
22
,
84
7
33
,
10
4
74
1
)
(1
,
28
1
)
(1
7
7
)
19
9
)
(2
6
5
)
(1
,
90
9
)
(5
,
37
3
)
- .
AV
I
S
T
A

C
'
t
"
\
Q
P
O
R
A
T
J
O
N
PG
T
M
e
d

n

M
e
d
La
G
PG
T
M
e
d
SL

T

T
o
l
a
l
WA
l
l
O

C
o
r
e
To
l
a
l
SU
P
P
L
Y
:
Fr
l
8/
2
7
/
9
9
NW
P
02
5
49
6
52
1
24
3
13
3
89
7
SU
P
P
L
Y
:
Fr
l
8/
2
7
/
9
9
PG
T
02
9
02
9
1
B
,
80
5
83
4
To
l
a
l
(1
5
,
4
7
1
)
05
4
49
6
55
0
24
3
93
8
73
1
DE
M
A
N
D
:

F
r
l
8/
2
7
/
9
9
79
5
28
1
67
3
74
9
50
8
22
,
84
7
33
.
10
4
Ov
e
r
(
s
h
o
r
t
)
(1
.
74
1
)
28
1
)
(1
7
7
)
19
9
)
(2
6
5
)
90
9
)
37
3
)
PG
T
M
e
d

n

M
a
d
La
G
PG
T
M
a
d
SL

T

T
o
t
a
l
WA
l
l
O

C
o
r
e
To
t
a
l
SU
P
P
L
Y
:

S
a
l
8/
2
8
/
9
9
NW
P
02
5
49
6
52
1
24
3
13
3
89
7
SU
P
P
L
Y
:

S
a
t
8/
2
8
/
9
9
PG
T
02
9
02
9
18
,
80
5
83
4
To
l
a
l
(1
5
,
4
7
1
)
05
4
49
6
55
0
24
3
93
8
73
1
DE
M
A
N
D
:

S
a
l
8/
2
8
/
9
9
79
5
28
1
67
3
74
9
50
8
84
7
33
.
10
4
Ov
e
r
(
s
h
o
r
t
)
74
1
)
28
1
)
(1
7
7
)
(3
,
19
9
)
(2
6
5
)
90
9
)
(5
.
37
3
)
ME
D
F
O
R
D

F
o
r
e
c
a
s
t
To
d
a
y
s
D
a
l
e
8/
2
4
/
9
9
Da
t
e

8/
2
1
/
9
9
8/
2
2
/
9
9
8/
2
3
/
9
9
8/
2
4
/
9
9
8/
2
5
/
9
9
8/
2
6
/
9
9
8/
2
7
/
9
9
8/
2
8
/
9
9
8/
2
9
/
9
9
8/
3
0
/
9
9
Lo
w
HO
D
Fe
s
t

L
o
a
d
'
'
~:
i
~
J
;
;(
.
'
.
I
,
!~
.
~~
:
,
l.
5
I
'
.
(
.
,
;
"
"
:
:
.
.
t
:
"
":L
:"
'
j:
.
,"
.
"
;j
:
~'"
:
:
u
~
.
IQ
J
'
, -
'
'
"
,
!'T
:\
"
'
:;
;

~
~
:
f
.
'
1
,
'"
,
!
=
:
~
~~
~
~
'
.
f
,.

"
"
.
.
.
"
,':
.
,.

.
",
,
10
"
,.

1
,
/.
.
,

,
-
"
:.,

-
.
k',
,
.
;
t.
J
:;
"
~f
I
'
,
..
.
).
.
,
..
.

"
I"
"
"
10
1
10
0
, 5
1
8a
s
e
:
Sa
t
Su
n
Mo
n
57
9
5

T
u
e
57
9
5

W
e
d
57
9
5

T
h
u
57
9
5

F
r
i
57
9
5

S
a
t
57
9
5

S
u
n
57
9
5

M
o
n
49
6
4
8
57
9
5
KL
A
M
A
T
H

F
A
L
L
S

F
o
r
e
c
a
s
l
To
d
a
y
s
D
a
l
e
8/
2
4
/
9
9
Da
t
e

8/
2
1
/
9
9
8/
2
2
/
9
9
8/
2
3
/
9
9
8/
2
4
/
9
9
8/
2
5
/
9
9
8/
2
6
/
9
9
8/
2
7
/
9
9
8/
2
8
/
9
9
8/
2
9
/
9
9
8/
3
0
/
9
9
Lo
w
HO
D
Fe
s
t

L
o
a
d
..

'

-

'
;
~
~
~
:
;~
:

;:
~
;

~
~
:~
:
~
':

.
,
;
~t
:
, i
~
~
.
:~
;
:
:~
J
!
!
~
,
"
'!
~
:"

:
~\
,
;
"
i'
J
"
"
,..
,.,
~
!
~
J
~
,
,
.
.
'
,
.
"
.
:
"
,'

"
..
.

,
.

.

.
"

.

,
0 '
:
J
'
"
/;'
1
:
.
"
'
;J
:
-
.
"
'
":
:
I
~
"
to
V
,

)(
I
"
"
;~
"
I
:
"
:'.
t
'
I:
"
'
-
~.'
:
'
:
"
Ba
s
e
:
Sa
t
Su
n
Mo
n
12
8
1

T
u
e
12
8
1

W
e
d
12
8
1

T
h
u
12
8
1

F
r
i
12
8
1

S
a
t
12
8
1

S
u
n
12
9
9

M
o
n
11
0
5
0
12
8
1
LA
G
R
.

Fo
r
e
c
a
s
t
To
d
a
y
s
-

-
i
e
8/
2
4
/
9
9

Da
t
e

8/
2
1
/
9
9
8/
2
2
/
9
9
8/
2
3
/
9
9
8/
2
4
/
9
9
8/
2
5
/
9
9
8/
2
6
/
9
9
8/
2
7
/
9
9
8/
2
8
/
9
9
8/
2
9
/
9
9
8/
3
0
/
9
9
Lo
w
HO
D
Av
l
S
T
A

r
'
;
"
-'
o
O
R
A
T
t
O
N
Fc
s
t

L
o
a
d
"
.
I
"
"
.
.
.
:.1
!
'
f
i
'
i
.
:.
.
.
.
ti
r
'
0;
,
.1
.
,
1.
CC
'
.
'
f
'
~"
:
'
~~
:
'
:
~
;
;
I
~:~
';
(
;
;
:;"
;iU
;
~
;
~
'
;T
~
:
W
.
:
(
j
i
r

;:"
)~
'
l:
'
:i
.
:\'
,.~
:
.
ft~
'
~f
,
-k
!
,
t
I

.
;i;
~

,
,
;o
'
:
!
"
; !
"
"
~\:
:
'
,;
,
!~
~
:~
1
'
I
'
..
.
~'

~
".
.

'
...
.
t.

~
I
.
",.
:
:
.
,
.
I'

.
,
~'
""
"
:
,
-
r,
,
~
'
"
I
r
~
,
!I
J
"
.
.
t:
V
'
.
'
::
-
. .
'(
'
.
~;-
"!
'
,~

,,'
.
.
.
.
!
'
~i
-
-
.
,

c.

.

.

.
",
-
.
.
.
::,
0\.
Ba
s
e
:

Sa
t
Su
n
Mo
n
67
3

T
u
e
67
3

W
e
d
67
3

T
h
u
67
3

F
r
i
67
3

S
a
t
67
3

S
u
n
67
3

M
o
n
70
6
2
67
3
SO
U
T
H

L
A
K
E

T
A
H
O
E

F
o
r
e
c
a
s
t
To
d
a
y
s
D
a
t
e
8/
2
4
/
9
9
Da
t
e

8/
2
1
/
9
9
8/
2
2
/
9
9
8/
2
3
/
9
9
8/
2
4
/
9
9
8/
2
5
/
9
9
8/
2
6
/
9
9
8/
2
7
/
9
9
8/
2
8
/
9
9
8/
2
9
/
9
9
8/
3
0
/
9
9
Lo
w
HD
D
Fc
s
t

L
o
a
d
,
"
~'
:
:
'
'
.
.,.
,;
t
.~
:
:
,
(#
)
:
u
I
.
;
,
"
.
-
r~
:
.
:I
J
"
I
.
i.
,
'
j
"
,
'!
;
l
'
~
'
r
T
:
"';
1'1
1

.
o:"
'
I.
t
"
r
l
",.
~i
:
'
(;
\
"
!i
"
:~
~
1
.
l
C
.
'
.
:
.
: '
~;
l
i
~
~
;
:;
:
i
U
'
T;
~
t
(
~
.
~'
:
;
:
i
~:
-
;r~
i
;
ii
1
1
i
e
l
1
i
J
~
~
~
#
t
~
,
45

Ba
s
e
:
Sa
t
Su
n
Mo
n
25
8
4

T
u
e
25
0
8

W
e
d
25
0
8

T
h
u
25
0
8

F
r
i
25
0
8

S
a
t
25
0
8

S
u
n
25
4
6

M
o
n
22
8
9
2
25
0
B
SP
O
K
A
N
E

F
o
r
e
c
a
s
t
To
d
a
y
s
D
a
l
e
8/
2
4
/
9
9
Da
t
e

8/
2
1
/
9
9
8/
2
2
/
9
9
8/
2
3
/
9
9
8/
2
4
/
9
9
8/
2
5
/
9
9
8/
2
6
/
9
9
8/
2
7
/
9
9
8/
2
8
/
9
9
8/
2
9
/
9
9
8/
3
0
/
9
9
Lo
w
HD
D
Fe
s
t

L
o
a
d
.
,
"
'
lt

(
"
.
.
"I
~
.
.I
(
.
t
r
,
l
t
'
.
t
"
'
~
.
.
.
..
:
~.
.

,
.
;
;
,
.
.
1;'
:"
.
"
(,,
'
,R
'
"I'
)
;
:
:
I
:
:
'
1:.
'
.
' "
;'

'
;
"
"
:;:
"
':
'
Km
~
~
,.

"
"
"
.
.
.
'
'"

"
"

'
' "
"
.
.
"
""
"
""
"
"
"
1-
,
.
".

;
~
.
~
;
L
:

;
~
;
.
:;
:
;
~
"
,

~::
!
)
~

i
"
'
~
~
:
'
"~
,
~
:
'
:.
'
,

"
,d
"
"
!~
"
"
"
'
'f
;
.
'
,
'
:"
'
!"
"
"

"
,.
~
.
,:

,
'~
~
"
l
"
'
o
"
.
I:
,
Sa
t
Su
n
Mo
n
22
8
4
7

T
u
e
22
8
4
7

W
e
d
22
8
4
7

T
h
u
22
8
4
7

F
r
i
22
8
4
7

S
a
t
22
8
4
7

S
u
n
23
3
2
9

M
a
n
19
9
6
2
1
Ba
s
e
:
22
8
4
7
Exhibit C
Avista Energy Monthly Billing to Avista Corp. For Core Customers
Summary of All Jurisdictions
Washington Net Billing $1,716 712
$618 399Idaho Net Billing
Pipeline Charges from Engage and ABC Supply lnvoices $75,000
Oregon Net Billing $576 114
Total Billing $3,030 225
*Exchange rate for Canadian dollars to US Mid-market noonday rate for first business
day of the month from Bank of Canada.
....
Exhibit D
A vista Energy Monthly Billing to A vista Corp. for Core Customers
Example Washington Jurisdiction
Commodity Billing Dekathenns
Monthly Volumes Deli vered to Citygate for A vista Corp Core Customers 500,000*
Plus Monthly Volume Delivered to Jackson Prairie to Meet Injection Schedule 382 500
Less 1\10nthly Volume from Jackson Prairie to Meet Withdrawal Schedule 000.000
Total Volume Delivered for Avista Corp. Core Customers
Fuel on Nova, ANG and PGT on 64% of Delivered Volume
Fuel on NWP on 360/0 of Delivered Volume
Total Volume Purchased for A vista Corp. Core Customers
AECO CINIT Monthly Index as Reported in Canadian Gas Price Reporter
Canadian Border Monthly Index as Reported in Inside F.
Rocky Mountains Monthly Index as Reported in Inside F.
Weighted Average Index Price (640/0-18%-180/0)
Index Adder
Price per Dekatherm for Volume Purchased
Commodity Billing
Capacity Release/Off System Sales Billing
Calculated Margins over Benchmark 900/0 (Credit) (from below)
Jackson Prairie Monthly Benchmark (Credit)
Variable Pipeline Charges Related to Off System Sales (Credit)
Total Billing to A vista Corp
Calculated Margins on Off System Sales
Off System Sales Volumes Transported on Avista Corp Transportation (W
Revenue (Delivered Volume X Relevant Delivery Point Index)
Less Variable Pipeline Charges Related to Off System Sales
Less Commodity Cost (purchased Volume X Relevant Receipt Point Index)
Calculated Margins on Off System Sales
Plus Monthly Capacity Release Credits from Pipeline Billings
Less Monthly Benchmark (Credit)
Amount Over Benchmark to Apply 90% Customer Share
Calculated Margins over Benchmark 90% (Credit)
882 500
067
669
893,236
$2.0200
$1.9400
$1.9900
$2.0002
$0.0500
$2.0502
831 312
$(3 600)
. $(55 000)
$(12 000)
$1,760 712
300 000*
$500,000
$12 000
$430,000
$58,000
$200,000
$(254.000)
$4,000
$(3 600)
*Needs to be allocated between Washington and Idaho with appropriate allocation
percentage.
Exhibit D
A vista Energy Billing to A vista Corp. for Core Customers
Example Washington Jurisdiction
Annual Calculation of Jackson Prairie Sharing Mechanism (April - March)
Jackson Prairie Off-System Sales Margins (VV A share) over or under $660,000 $30 000
500/0 to be Returned to A vista Corp s W A Customers
Annual Calculation of Trigger Mechanism (April- March)
Benefits to A vista Energy - Conunodity Component
Benefits to A vista Energy - Jackson Prairie
Benefits to A vista Energy - Capacity Release/Off-System Sales
Total
Amount over $2 million to be shared 75% back to Avista Corp s Customers
$15 000
$300 000
$15 000
.$150.000
$465,000
$000,000
Exhi bi t E
A vista Energy Monthly Billing to A vista Corp. for Core Customers
Example Idaho Jurisdiction
Commodity Billing Dekathenns
Monthly Volumes Delivered to Citygate for Avista Corp Core Customers 150 000*
Plus Monthly Volume Delivered to Jackson Prairie to Meetlnjection Schedule 150,000
Less Monthly Volume from Jackson Prairie to Meet Withdrawal Schedule 000.000
Total Volume Delivered for Avista Corp. Core Customers 300,000
Fuel on Nova, ANG and PGT on 50% of Delivered Volume
Fuel on NWP on 500/0 of Delivered Volume
285
520
Total Volume Purchased for Avista Corp. Core Customers 306,805
AECO CfNIT Monthly Index as Reported in Canadian Gas Price Reporter
Canadian Border Monthly Index as Reported in Inside F.
Rocky Mountains Monthly Index as Reported in Inside F.
$2.0200
$1. 9400
$1.9900
Weighted Average Index Price (500/0-25%-250/0)
Index Adder
Price per Dekatherm for Volume Purchased
$1.9925
$0.0500
$2.0425
Commodity Billing $626 649
Capacity Release/Off System Sales Billing
Monthly Capacity Release Credits from Pipeline Billings
Monthly Benchmark (Credit)
$160,000
$(168.250)
$618,399Total Billing to A vista Corp
*Needs to be allocated between Washington and Idaho with appropriate allocation
percentage.
Exhibit F
A vista Energy Monthly Billing to A vista Corp. for Core Customers
Oregon Jurisdiction
Commodity Billing Dekathenns
Monthly Volumes Delivered to Citygate for Avista Corp Core Customers 270 000
Plus Monthly Volume Delivered to Jackson Prairie to Meet Injection Schedule 20 000
Less Monthly Volume from Jackson Prairie to Meet Withdrawal Schedule 00,000
Total Volume Delivered for Avista Corp. Core Customers
Fuel on Nova, ANO and POT on 50% of Delivered Volume
Fuel on NWP on 50% of Delivered Volume
Less any Volumes at Fixed Price or Outside Costless Collar
Total Volume Purchased for A vista Corp. Core Customers
AECO C/NIT Monthly Index as Reported in Canadian Gas Price Reporter
Canadian Border Monthly Index as Reported in Inside F.
Rocky Mountains Monthly Index as Reported in Inside F.
Weighted Average Index Price (500/0-25%-25%)
Index Adder
Price per Dekatherm for Volume Purchased
Commodity Billing Based on Index
Commodity Billing Based on Fixed or Outside Costless Collar
Total Commodity Billing
Capacity Release/Off System Sales Billing
20% of Capacity Release Credits in Excess of Full Pipeline Rate
800/0 of Calculated Margins on Off System Sales (Credit) from below
Capacity ReleaselOff System Sales (Credit)
Variable Pipeline Charges Related to Off System Sales (Credit)
Total Billing to A vista Corp
Calculated Margins on Off System Sales
Off System Sales Volumes Transported on A vista Corp Transportation
Revenue (Delivered Volume X Relevant Delivery Point Index)
Less Variable Pipeline Charges Related to Off System Sales
Less Commodity Cost (purchased Volume X Relevant Receipt Point Index)
Calculated Margins on Off System Sales
800/0 Customer Share
. 290 000
175
2,436
00,000
296,611
$2.0200
$1.9400
$1.9900
$1.9925
$0.0500
$2.0425
$606 644
$00,000
$606,644
$5,500
$(24,000)
$(18 500)
~(12,OOO)
$576 144
250,000
$442 000
$12,000
,$400 ,000
$30 000
$24 000
VISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMATION
JURISDICTION:
CASE NO:
REQUESTER:
TYPE:
REQUEST NO:
Idaho
A VU - E-O4-0 1 I A VU -04-0 1
Potlatch
Data Request
DATE PREPARED:
WITNES S
RESPONDER:
DEPARTMENT:
TELEPHONE:
5/26/2004
Bob Lafferty
Dick Winters
Natural Gas
[phone]
REQUEST:
Please provide monthly index prices in Excel format for each month January 2001
through December 2003 at Sumas, Kingsgate, Malin, Stanfield, AECO, Opal (or Rockies) and
NYMEX. Also, please provide the Enron OnLine or TFS or other sheets that are
contemporaneous with the referenced index prices.
RESPONSE:
Please see attached worksheet "Gas Monthly Index Prices" showing the monthly gas
index prices at various delivery points for the period January 2001 through December 2003.
The U.S. indices listed are from Platts, Inside FERC's Gas Market Report published monthly.
The Canadian index (AECO) is reported monthly on Canadian Gas Price Reporter.
Enron Online (no longer exists) did not report monthly index prices. Avista does not
receive TFS sheets related to gas prices.
A
v
i
s
t
a

Co
r
p
.
Na
t
u
r
a
l

G
a
s

m
o
n
t
h
l
y

I
n
d
e
x

P
r
i
c
e
s
Ba
s
e
d

o
n

G
a
s

D
a
i
l
y

M
o
n
t
h
l
y

I
n
d
e
x

e
x
c
e
p
t

A
E
C
O

w
h
i
c
h

i
s

C
a
n
a
d
i
a
n

P
r
i
c
e

Re
p
o
r
t
e
r
NW
P
Ca
l
i
.

B
o
r
d
e
r
PG
T
NO
V
A
NW
P
NW
P
NY
M
E
X
St
a
n
f
i
e
l
d
Ma
l
i
n
Ki
n
g
s
g
a
t
e
AE
C
O
-
Ke
r
n
/
O
p
a
l
Wy
o
m
i
n
g
Su
m
a
s
He
n
r
y

H
u
b
Ja
n
-
$1
5
.
20
0
$1
3
.
89
0
$1
3
.
90
0
$9
.
10
4
$8
.
76
0
$8
.
84
0
$1
4
.
21
0
$9
.
98
0
Fe
b
-
O
1
$6
.
72
0
$1
0
.
03
0
$7
.
53
0
$7
.
38
7
$6
.
4
2
0
$6
.
4
7
0
$6
.
98
0
$6
.
22
0
Ma
r
-
$5
.
33
0
$8
.
37
0
$6
.
10
0
$5
.
20
8
$4
.
90
0
$4
.
92
0
$5
.
21
0
$5
.
03
0
Ap
r
-
$5
.
38
0
$7
.
4
3
0
$5
.
4
4
0
$5
.
09
3
$4
.
57
0
$4
.
55
0
$5
.
34
0
$5
.
35
0
Ma
y
-
$5
.
24
0
$1
0
.
00
0
$5
.
30
0
$4
.
84
7
$4
.
12
0
$4
.
07
0
$5
.
19
0
$4
.
89
1
Ju
n
-
$3
.
90
0
$6
.
04
0
$4
.
05
0
$3
.
77
0
$2
.
63
0
$2
.
63
0
$3
.
90
0
$3
.
73
0
Ju
l
-
$2
.
76
0
$3
.
24
0
$2
.
74
0
$2
.
96
9
$2
.
04
0
$2
.
04
0
$2
.
67
0
$3
.
11
0
Au
g
-
$2
.
54
0
$3
.
14
0
$2
.
4
5
0
$2
.
4
5
2
$2
.
27
0
$2
.
29
0
$2
.
4
2
0
$3
.
19
0
Se
p
-
$2
.
33
0
$2
.
4
4
0
$2
.
25
0
$2
.
26
9
$2
.
08
0
$2
.
10
0
$2
.
17
0
$2
.
34
0
Oc
t
-
$1

.
50
0
$1
.
54
0
$1
.
55
0
$1
.
66
8
$1

.
23
0
$1

.
27
0
$1

.
37
0
$1
.
86
0
No
v
-
$2
.
84
0
$2
.
91
0
$2
.
80
0
$2
.
22
1
$2
.
63
0
$2
.
58
0
$2
.
76
0
$3
.
15
0
De
c
-
$2
.
59
0
$2
.
66
0
$2
.
37
4
$2
.
13
0
$2
.
20
0
$2
.
67
0
$2
.
31
0
Ja
n
-
$2
.
62
0
$2
.
63
0
$2
.
55
0
$2
.
33
8
$2
.
4
0
0
$2
.
38
0
$2
.
52
0
$2
.
61
0
Fe
b
-
$1
.
77
0
$1

.
99
0
$1
.
88
0
$1
.
88
7
$1
.
73
0
$1

.
73
0
$1
.
87
0
$2
.
04
0
Ma
r
-
$2
.
19
0
$2
.
26
0
$2
.
06
4
$1
.
97
0
$1
.
96
0
$2
.
13
0
$2
.
4
0
0
Ap
r
-
$3
.
20
0
$3
.
30
0
$2
.
79
5
$2
.
83
0
$2
.
86
0
$3
.
15
0
$3
.
4
1
0
Ma
y
-
$2
.
85
0
$2
.
97
0
$2
.
95
0
$2
.
26
0
$2
.
27
0
$2
.
82
0
$3
.
36
0
Ju
n
-
$2
.
57
0
$2
.
60
0
$2
.
75
5
$1
.
62
0
$1
.
61
0
$2
.
4
2
0
$3
.
38
0
Ju
l
-
$2
.
26
0
$2
.
62
0
$2
.
22
9
$1

.
26
0
$1
.
26
0
$1
.
9
0
0
$3
.
26
0
Au
g
-
$2
.
02
0
$2
.
4
7
0
$1
.
7
4
3
$1

.
59
0
$1
.
59
0
$1

.
87
0
$2
.
95
0
Se
p
-
$2
.
63
0
$2
.
93
0
$2
.
31
3
$1

.
20
0
$1
.
20
0
$2
.
54
0
$3
.
27
0
Oc
t
-
$3
.
13
0
$3
.
32
0
$2
.
91
0
$1
.
31
0
$1
.
31
0
$3
.
06
0
$3
.
72
0
No
v
-
$3
.
96
0
$4
.
06
0
$3
.
63
5
$2
.
99
0
$2
.
99
0
$3
.
92
0
$4
.
13
0
De
c
-
$3
.
93
0
$4
.
06
0
$3
.
52
7
$3
.
30
0
$3
.
30
0
$3
.
96
0
$4
.
13
0
Ja
n
-
$4
.
4
4
0
$4
.
10
1
$3
.
08
0
$3
.
07
0
$4
.
4
4
0
$4
.
96
0
Fe
b
-
$4
.
89
0
$4
.
72
4
$3
.
14
0
$3
.
14
0
$4
.
76
0
$5
.
66
0
Ma
r
-
$7
.
53
0
$7
.
53
0
$6
.
82
7
$5
.
01
0
$5
.
02
0
$7
.
32
0
$9
.
11
0
Ap
r
-
$4
.
4
8
0
$4
.
59
0
$4
.
83
2
$3
.
26
0
$3
.
27
0
$4
.
29
0
$5
.
14
0
Ma
y
-
$4
.
77
0
$4
.
82
0
$4
.
83
4
$4
.
28
0
$4
.
28
0
$4
.
58
0
$5
.
12
0
Ju
n
-
$5
.
10
0
$5
.
27
0
$5
.
12
4
$4
.
98
0
$4
.
96
0
$4
.
87
0
$5
.
95
0
Ju
l
-
$4
.
96
0
$4
.
97
0
$5
.
14
1
$4
.
67
0
$4
.
67
0
$4
.
65
0
$5
.
30
0
Au
g
-
$4
.
26
0
$4
.
17
3
$4
.
02
0
$4
.
01
0
$3
.
93
0
$4
.
69
0
Se
p
-
$4
.
66
0
$4
.
4
5
8
$4
.
4
5
0
$4
.
01
0
$4
.
36
0
$4
.
92
7
Oc
t
-
$4
.
26
0
$4
.
30
0
$4
.
24
4
$4
.
13
0
$4
.
12
0
$4
.
14
0
$4
.
4
4
0
No
v
-
$4
.
17
0
$4
.
20
0
$4
.
11
3
$4
.
08
0
$4
.
06
0
$4
.
08
0
$4
.
4
5
0
De
c
-
$4
.
51
0
$4
.
27
8
$4
.
4
0
0
$4
.
39
0
$4
.
50
0
$4
.
86
0
Po
t
l
a
t
c
h

D
R

N
o
.

Ca
s
e

N
o
.

A
V
U
04
-
Ga
s

M
o
n
t
h
l
y

I
n
d
e
x

P
r
i
c
e
s
.

x
I
s

5/
2
7
/
2
0
0
4

W
G
J
AVISTA CORPORATION
RESPONSE TO REQUEST FOR INFORMATION
JURISDICTION:
CASE NO:
REQUESTER:
TYPE:
REQUEST NO.
Idaho
AVU-04-01 / AVU-04-
Potlatch
Data Request
DATE PREP ARED:
WITNES S
RESPONDER:
DEP ARTMENT:
TELEPHONE:
05/25/2004
Bob Lafferty
Pat Gorton
Corporate Risk
[phone]
REQUEST:
Re: Exhibit 7, Schedule 21 , page 1 of 70. Please provide a detailed explanation of the meaning,
under Transmission Alternatives the statement "May be dropped off
(g)
Kingsgate - RGEN
STAN - CO YO or MALIN"
RESPONSE:
These points are all delivery points along Gas Transmission Northwest Corporation from the
Canadian Border at Kingsgate to the Oregon/California Border at Malin. Due to the nature of
the purchase, the counterparty (supplier) provides gas at AECO and A vista Utilities acts as agent
to nominate gas from AECO to any of these delivery points. Therefore Avista Utilities maintains
maximum operational flexibility to deliver the gas to any of its thermal plants or market points
along Gas Transmission Northwest Corporation pipeline. RGEN means Avista Utilities
Rathdrum generation project. STAN means the Stanfield interconnection point with the
Williams Northwest Pipeline. CO YO means the interconnection point with the lateral which
delivers natural gas to the Coyote Springs 2 generating project.
CONFIDENTIAL ATTACHMENTS