20040621Peaseu Exhibits.pdf

DENNIS PESEAU
POTLA TCH
EXHIBITS 202 & 203
FILED
CONFIDENTIAL
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Avista Corporation
Summary of Regression Analysis for Four Factor Test
Administration and General Expense Regressions
(1)
Std. Errors
Statistic
Squared
Statistic
(2)
Std. Errors
Statistic
Squared
Statistic
General Plant Regressions
(3)
Std. Errors
Statistic
Squared
Statistic
(4)
Std, Errors
Statistic
Squared
Statistic
Where:A&G GP
O&M-A&G
O&M-A&G-F&PP =
Exhibit 205
6/17/2004
A&G 383,557,7492 1123
682 185.4004 0217
5422 1709
O&M-A&G
7567
26.7384
A&G 211 873.0773 3576 O&M-A&G-F &PP
966 449.7023 0358
0224 9839
9243
99.6782
233 903 772.3116 +5508
147 363 136.8268 1296
5873 2491
O&M-A&G
6702
18.0552
126 560 631.1678 +8108 O&M-A&G-F &PP
666 699.6567 1753
3583 10.3308
9291
106,7261
Administrative and General Expense
General Plant
Operation and Maintenance Expense less A&G Expense
Operation and Maintenance Expense less A&G Expense
less Fuel and Purchased Power Expense
Exhibit 205, Page
Dennis Peseau
Potlatch Corporation
Page Sumcost AVISTA UTILITIES Idaho Jurisdiction
Scenario: Potlatch Revised Case Cost of Service Basic Summary Electric Utility 06/16/00
Last Idaho Method modified For The Twelve Months Ended December 31 2002 10:10 AM
Common Costs by 4-Factor
(b)(c) (d) (e)
(g)
(h)(i)(k)(I)(m)
Residential General Large Gen Extra Large Potlatch Pumping Street &
System Service Service Service Gen Service Ex Lg Gen Svc Service Area Lights
Description Total Sch 1 Sch 11-Sch 21-Sch 25 Sch 25P Sch 31-Sch 41-49
Plant In Service
Production Plant 300 269 000 103 855 863 871 210 089,462 322 636 527 729 560,417 041,683
Transmission Plant 109 001 000 385 747 848 888 542 216 027 527 404 904 543312 248405
Distribution Plant 257 643 000 124 105 238 736 508 66,750 926 482 458 125 817 003741 438313
Intangible Plant 353 000 000 386 114 160 117,416 854 407 005 725 168954 953
General Plant 524 000 435 682 248 072 866 905 083 349 903 940 531 344 454708
Total Plant In Service 714 790 000 294 782 916 818839 161 366 926 770 376 104 968 116 11,807 767 275061
Accum Depreciation
Production Plant (91 465 000)(31 590 537)260043)(19 529 251)629 804)(22 746 584)390 227)(318 554)
Transmission Plant (36 394000)(14152 043)288414)526 549)348 059)480 703)(515 291)(82 939)
Distribution Plant (75 640 000)(36 577 375)(9,422 128)(18 580 254)668 780)(546 491)458 607)386 364)
Intangible Plant 893 000)(926 541)(204271)(327 132)(124 319)(263 361)(27,793)(19 583)
General Plant (16 434000)745099)911 423)(2,639 818)(937 404)756 581)(239 078)(204 596)
Total Accumulated Depreciation (221 826 000)(91 991 595)(22 086,279)(48,603 005)(16 708 367)(32 793 720)630,997)012 037)
Net Plant 492 964000 202,791 321 732 559 112,763 921 062,010 174396 176 769 263 024
Accumulated Deferred FIT (61 593000)(25 382 122)105 279)(13 942 489)894 116)007 035)019 134)242 825)
Miscellaneous Rate Base 836 000 747 462 654 312 007 561 899 907 364726 136,320 712
Total Rate Base 440,207 000 180 156 661 281 592 100 828 993 067 801 532,087 293 955 045 911
Revenue From Retail Rates 146 248000 648000 212 000 804000 10,475000 696 000 549 000 864000
Other Operating Revenues 677 000 7,754,429 794 442 631 500 012832 055 268 328 065 100 465
Total Revenues 167 925000 402,429 006 442 435500 487 832 751 268 877 065 964465
Operating Expenses
Production Expenses 522 000 179 034 239 677 023454 518503 060 876 215 561 284895
Transmission Expenses 485 000 132878 495 602 134339 504592 127,429 77,660 500
Distribution Expenses 495 000 827 125 875 891 724952 477 108 378 146 280 376 266
Customer Accounting Expenses 296 000 174 073 712 481 196 952 870 200 053 370
Customer Information Expenses 480 000 589 887 129 334 283641 124 152 326 637 592 756
Sales Expenses 421 000 134 538 672 568 311 115 486 659 767
Admin & General Expenses 888 000 120 284 023 839 070960 084 067 080 226 266 645 241 979
Total O&M Expenses 115,587 000 157 819 507 497 525865 804 602 874 232 785451 931 533
Taxes Other Than Income Taxes 438 000 147 224 769 658 734 844 575 212 903 342 125 733 181 987
Other Income Related Items
Depreciation Expense
Production Plant Depreciation 933 000 759 593 634 649 690,789 747,420 953 357 120 107 085
Transmission Plant Depreciation 532 000 984,585 228 781 523 636 232 931 520 447 850 770
Distribution Plant Depreciation 670 000 695 437 696 191 413 966 299 955 654 108 991 406 807
General Plant Depreciation 892 000 071 068 452 675 625 178 222 002 416 004 620 48 , 454
Amortization Expense 367 000 134 357 051 187 215 727 396 068
Total Depreciation Expense 394000 645 038 043347 330 756 536 523 022 189 326 964 489 183
Income Tax 3,794 000 534 490 725,474 524 046 88,478 766 588 917 008
Total Operating Expenses 147 213 000 484 571 045 975 115 512 004 815 566 351 337 065 658 711
Net Income 712 000 917 858 960 467 319 988 483 016 184917 540 000 305 754
Rate of Return 71%1.62%15%25%1.34%39%40%34%
Return Ratio 1.00 1.94
Interest Expense 250 000 287 402 991 000 638 243 659 158 014547 335 530 324120
Exhibit 206
6/17/2004
Exhibit 206, Page 1
Dennis Peseau
Potlatch Corporation
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N
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No
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8

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%
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.
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%
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3
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4

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A

S
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Dir
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t

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d

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2
5

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r
s
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%
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00
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00
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00
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5

D
A

S
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h

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P
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Dir
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t

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s
s
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t
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d
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2
5
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t
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m
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r
s
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0
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00
%
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%
00
%
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k
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%
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0
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00
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00
6

N
C
P
-
Se
c
o
n
d
a
r
y
42
6
,
4
0
0
21
9
37
0
07
9
13
6
,
7
8
9
89
1
27
1
No
n
-
Co
i
n
c
i
d
e
n
t

P
e
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k

S
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c
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n
d
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r
y
1
2

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e

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0

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0
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51
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13
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3
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%
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%
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k
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%
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%
00
%
00
%
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00
7

D
A

S
t
r
e
e
t

an
d

A
r
w

L
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g
h
t
s
10
0
10
0
Di
r
e
c
t

A
s
s
i
g
n
e
d

t
o

S
t
r
e
e
t

&

A
r
e
a

L
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g
h
t
s
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0
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00
%
00
%
00
%
00
%
00
%
00
%
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%
10
0
.
00
%
00
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00
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00
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00
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00
8

N
C
P
-
Pr
i
m
a
r
y
48
9
,
53
8
21
9
37
0
57
,
07
9
15
0
07
8
84
9
89
1
27
1
No
n
-
Co
i
n
c
i
d
e
n
t

P
e
a
k

P
r
i
m
a
r
y

1
2

M
e

A
v
g
10
0
.
00
%
44
.
81
%
11
.
66
%
30
.
66
%
10
.
18
%
00
%
02
%
67
%
00
%
00
%
00
%
00
%
Cu
s
t
o
m
e
r

A
l
b
c
a
t
o
r
s
CO
1

A
v
g

C
u
s
t
o
m
e
r
s
-
All
10
6
51
5
87
,
4
9
4
16
,
05
1
78
9
04
3
12
4
Un
w
e
i
g
h
t
e
d
10
0
.
00
%
82
.
14
%
15
.
07
%
68
%
01
%
00
%
98
%
12
%
00
%
00
%
00
%
00
%
CO
2

A
v
g

C
u
s
t
o
m
e
r
s
-
Se
c
o
n
d
a
r
y
10
6
35
1
87
,
4
9
4
05
1
76
4
04
3
Un
w
e
i
g
h
t
e
d

S
e
c
o
n
d
a
r
y

wl
o

Lig
h
t
i
n
g
1o
o
.
00
0
k
82
.
27
%
15
.
09
%
1.6
6
%
00
%
00
%
98
%
00
%
00
%
00
%
00
%
00
%
CO
3

W
t

C
u
s
t
o
m
e
r
s
-
Me
t
e
r

R
e
a
d
i
n
g
12
7
,
12
2
87
,
4
9
4
10
1
36
7
08
5
Es
t
.

M
e
t
e
r

R
e
a
d
i
n
g

T
i
m
e
10
0
.
00
%
68
.
83
%
25
.
25
%
22
%
06
%
00
%
64
%
00
%
00
%
00
%
00
%
OO
O
k
CO
4

W
t

C
u
s
t
o
m
e
r
s
-
Me
t
e
r
s
20
2
,
26
7
87
,
4
9
4
70
8
25
4
1.6
8
7
14
7
97
7
Pro
p
o
r
t
i
o
n

I
n
s
t
a
l
e
d

M
e
t
e
r

C
o
s
t
s
10
0
.
00
%
43
.
26
%
29
.
52
%
21
.
3
8
%
83
%
07
%
93
%
00
%
00
%
00
%
00
%
00
%
CO
5

D
A

S
t
r
e
e
t

&

A
r
e
a

L
i
g
h
t
s
12
4
12
4
Di
r
e
c
t

A
s
s
i
g
n
e
d

t
o

S
t
r
e
e
t

&

A
r
e
a

L
i
g
h
t
s
10
0
.
00
%
00
%
00
%
00
0
/
.
00
%
00
%
OO
O
k
10
0
.
00
%
00
%
00
%
00
%
00
%
CO
6

D
A

H
a
n
d
b
i
l
e
d
Dir
e
c
t

A
s
s
i
g
n
e
d

t
o

H
a
n
d
b
i
l
e
d

C
u
s
t
o
m
e
r
s
10
0
.
00
%
00
%
00
%
00
0
1
0
73
.
68
%
26
.
32
%
00
%
00
%
00
%
00
%
00
%
00
%
CO
7

O
p
e
n
Op
e
n
No
.

o
f

C
u
s
t
o
m
e
r

B
i
l
l
s
27
8
18
3
04
9
93
1
19
2
60
7
21
,
4
6
6
16
8
51
0
48
9
No
.

o
f

C
u
s
t
o
m
e
r
s

(
A
v
e
r
a
g
e
)
10
6
51
5
87
,
4
9
4
05
1
1,7
8
9
1.0
4
3
12
4
Cu
s
t
o
m
e
r

W
e
i
g
h
t
i
n
g
s
Av
g

C
u
s
t
o
m
e
r
s
-
All
Un
w
e
i
g
h
t
e
d
Av
g

C
u
s
t
o
m
e
r
s
-
Se
c
o
n
d
a
r
y
Un
w
e
i
g
h
t
e
d

S
e
c
o
n
d
a
r
y

wlo

Li
g
h
t
i
n
g
Wt

C
u
s
t
o
m
e
r
s
-
Me
t
e
r

R
e
a
d
i
n
g
Es
t
.

M
e
t
e
r

R
e
a
d
i
n
g

T
i
m
e
Wt

C
u
s
t
o
m
e
r
s
-
Me
t
e
r
s
24
.
12
0
.
14
6
.
95
7
Pr
o
p
o
r
t
i
o
n

I
n
s
t
a
l
e
d

M
e
t
e
r

C
o
s
t
s
DA

S
t
r
e
e
t

&

A
r
e
a

L
i
g
h
t
s
Dir
e
c
t

A
s
s
i
g
n
e
d

t
o

S
t
r
e
e
t

&

A
r
e
a

L
i
g
h
t
s
DA

H
a
n
d
b
i
l
e
d
Di
r
e
c
t

A
s
s
i
g
n
e
d

t
o

H
a
n
d
b
i
l
e
d

C
u
s
t
o
m
e
r
s
Op
e
n
Op
e
n
Ex
h
i
b
i
t

2
0
6
6/1
7
1
2
0
0
4
Ex
h
i
b
i
t

2
0
6
, P
a
g
e
3
0
De
n
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P
e
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a
u
Po
t
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c
h

C
o
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p
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t
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n
As
s
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AV
I
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A

U
T
I
L
I
T
I
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S
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c
t
r
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c

U
t
i
i
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y
Id
a
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o

J
u
r
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s
d
i
c
t
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n
Sc
e
n
a
r
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o
:

P
o
t
l
a
t
c
h

R
e
v
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s
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d

C
a
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e
Cla
s
s

A
l
b
c
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W
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s
h
e
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t
16
-
Ju
n
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La
s
t

I
d
a
h
o

M
e
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h
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d

m
o
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f
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d
Fo
r

t
h
e

Y
e
a
r

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n
d
e
d

D
e
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h
SCHEDULE 7
Long-Te~ Fi~ and Short-Te~ Fi~ Point-To-Point
Transmission Service
The Transmission Customer shall compensate the Transmission Provider each
month for Reserved Capacity up to the sum of the applicable charges set forth
below:
1) Yearly delivery: one-twelfth of the demand charge of $ 16.79/kW of
Reserved Capacity per year.
2) Monthly delivery: $1.40/kW of Reserved Capacity per month.
3) Weekly delivery: $3230/kW of Reserved Capacity per week.
4) Daily delivery: $O646/kW of Reserved Capacity per day.
The total demand charge in any week, pursuant to a reservation for Daily delivery,
shall not exceed the rate specified in section (3) above times the highest amount
kilowatts of Reserved Capacity in any day during such week.
5) Discounts: Three principal requirements apply to discounts for
transmission service as follows (1) any offer of a discount made by the
Transmission Provider must be announced to all Eligible Customers
solely by posting on the OASIS, (2) any customer-initiated requests
for discounts (including requests for use by one s wholesale merchant
or an affiliate s use) must occur solely by posting on the OASIS, and
(3) once a discount is negotiated, details must be immediately posted
on the OASIS. For any discount agreed upon for service on a path,
from the Point(s) of Receipt to the Point(s) of Delivery, the
Transmission Provider must offer the same discounted transmission
service rate for the same time period to all Eligible Customers on all
unconstrained transmission paths that go to the same Point(s) of
Delivery on the Transmission System.If the Transmission Provider
offers an affiliate a rate discount or attributes a discounted
transmission rate to its own transactions, the Transmission Provider
must offer at the same time the same discounted Firm Point-To-Point
Transmission Service rate to all Eligible Customers on the same path
and on all unconstrained transmission paths. Information regarding
any firm transmission discounts must be posted on the OASIS
EXHIBIT NO. 207
Case Nos. A VU-E-O4-1 and A VU-04-
D. Peseau, Potlatch
June 21 , 2004 Page 1 of 10
pursuant to Part 37 of the Commission s regulations. In addition,
discounts to non-affiliates must be offered in a not unduly
discriminatory manner.
SCHEDULE 8
Non-Firm Point-To-Point Transmission Service
The Transmission Customer shall compensate the Transmission Provider for Non-
Firm Point- To-Point Transmission Service up to the sum of the applicable charges
set forth below:
1) Monthly delivery: $1.40/kW of Reserved Capacity per month.
2) Weekly delivery: $3230/kW of Reserved Capacity per week.
3) Daily delivery: $O646/kW of Reserved Capacity per day.
The total demand charge in any week, pursuant to a reservation for Daily delivery,
shall not exceed the rate specified in section (2) above times the highest amount in
kilowatts of Reserved Capacity in any day during such week.
4) Hourly delivery: The basic charge shall be that agreed upon by the
Parties at the time this service is reserved and in no event shall exceed
O/MWH. The total demand charge in any day, pursuant to a
reservation for Hourly delivery, shall not exceed the rate specified in
section (3) above times the highest amount in kilowatts of Reserved
Capacity in any hour during such day. In addition, the total demand
charge in any week, pursuant to a reservation for Hourly or Daily
delivery, shall not exceed the rate specified in section (2) above times
the highest amount in kilowatts of Reserved Capacity in any hour
during such week.
5) Discounts: Three principal requirements apply to discounts for
transmission service as follows (1) any offer of a discount made by the
Transmission Provider must be announced to all Eligible Customers
solely by posting on the OASIS, (2) any customer-initiated requests
for discounts (including requests for use by one s wholesale merchant
or an affiliate s use) must occur solely by posting on the OASIS, and
(3) once a discount is negotiated, details must be immediately posted
on the OASIS. For any discount agreed upon for service on a path,
from the Point(s) of Receipt to the Point(s) of Delivery, the
EXHIBIT NO. 207
Case Nos. AVU-04-1 and AVU-G-04-
D. Peseau, Potlatch
June 21 , 2004 Page 2 of 10
Transmission Provider must offer the same discounted transmission
service rate for the same time period to all Eligible Customers on all
unconstrained transmission paths that go to the same Point(s) of
Delivery on the Transmission System.If the Transmission Provider
offers an affiliate a rate discount or attributes a discounted
transmission rate to its own transactions, the Transmission Provider
must offer at the same time the same discounted Non-Firm Point-To-
Point Transmission Service rate to all Eligible Customers on the same
path and on all unconstrained transmission paths. Information
regarding any non-firm transmission discounts must be posted on the
OASIS pursuant to Part 37 of the Commission s regulations. In
addition, discounts to non-affiliates must be offered in a not unduly
discriminatory manner.
EXHIBIT NO. 207
Case Nos. AVU-E-O4-1 and AVU-04-
D. Peseau, PotlatchJune 21, 2004 Page 3 of 10
III. NETWORK INTEGRATION TRANSMISSION SERVICE
Preamble
The Transmission Provider will provide Network Integration Transmission Service
pursuant to the applicable terms and conditions contained in the Tariff and Service
Agreement. Network Integration Transmission Service allows the Network
Customer to integrate, economically dispatch and regulate its current and planned
Network Resources to serve its Network Load in a manner comparable to that in
which the Transmission Provider utilizes its Transmission System to serve its Native
Load Customers. Network Integration Transmission Service also may be used by
the Network Customer to deliver economy energy purchases to its Network Load
from non-designated resources on an as-available basis without additional charge.
Transmission service for sales to non-designated loads will be provided pursuant to
the applicable terms and conditions of Part n of the Tariff.
28 Nature of Network Integration Transmission Service
28.1 Scope of Service: Network Integration
Transmission Service is a transmission service that
allows Network Customers to efficiently and
economically utilize their Network Resources (as well
other non-designated generation resources) to serve
their Network Load located in the Transmission
Provider s Control Area and any additional load that
may be designated pursuant to Section 31.3 of the
Tariff. The Network Customer taking Network
Integration Transmission Service must obtain or
provide Ancillary Services pursuant to Section 3.
28.2 Transmission Provider Responsibilities: The
Transmission Provider will plan, construct, operate and
maintain its Transmission System in accordance with
Good Utility Practice in order to provide the Network
Customer with Network Integration Transmission
Service over the Transmission Provider s Transmission
System. The Transmission Provider, on behalf of its
Native Load Customers, shall be required to designate
resources and loads in the same manner as any Network
Customer under Part m of this Tariff. This
information must be consistent with the information
used by the Transmission Provider to calculate
available transmission capability. The Transmission
EXHIBIT NO. 207
Case Nos. AVU-04-1 and AVU-04-
D. Peseau, Potlatch
June 21 , 2004 Page 4 of 10
Provider shall include the Network Customer
Network Load in its Transmission System planning and
shall, consistent with Good Utility Practice, endeavor to
construct and place into service sufficient transmission
capacity to deliver the Network Customer s Network
Resources to serve its Network Load on a basis
comparable to the Transmission Provider s delivery of
its own generating and purchased resources to its
Native Load Customers.
28.3 Network Integration Transmission Service: The
Transmission Provider will provide firm transmission
service over its Transmission System to the Network
Customer for the delivery of capacity and energy from
its designated Network Resources to service its Network
Loads on a basis that is comparable to the Transmission
Provider s use of the Transmission System to reliably
serve its Native Load Customers.
28.4 Secondary Service: The Network Customer may
use the Transmission Provider s Transmission System
to deliver energy to its Network Loads from resources
that have not been designated as Network Resources.
Such energy shall be transmitted, on an as-available
basis, at no additional charge. Deliveries from resources
other than Network Resources will have a higher
priority than any Non-Firm Point-To-Point
Transmission Service under Part n of the Tariff.
28.5 Real Power Losses: Real power losses are
associated with all transmission service. The
Transmission Provider is not obligated to provide real
power losses. The Network Customer is responsible for
replacing losses associated with all transmission service
as calculated by the Transmission Provider. The
applicable real power loss factors are as follows: For all
transmission facilities included in the transmission
plant investment base used to calculate Network
Integration Transmission Service rates, the applicable
real power loss factor is 3.00%. For any other facilities,
including Direct Assignment Facilities, the applicable
real power loss factor shall be determined on a case by
case basis.
28.6 Restrictions on Use of Service: The Network
Customer shall not use Network Integration
EXHIBIT NO. 207
Case Nos. AVU-E-O4-1 and AVU-G-O4-
D. Peseau, Potlatch
June 21 , 2004 Page 5 of 10
Transmission Service for (i) sales of capacity and energy
to non-designated loads, or (ii) direct or indirect
provision of transmission service by the Network
Customer to third parties. All Network Customers
taking Network Integration Transmission Service shall
use Point-To-Point Transmission Service under Part
of the Tariff for any Third-Party Sale which requires
use of the Transmission Provider s Transmission
System.
cont.
31 Designation of Network Load
31.1 Network Load: The Network Customer must
designate the individual Network Loads on whose
behalf the Transmission Provider will provide Network
Integration Transmission Service. The Network Loads
shall be specified in the Service Agreement.
31.2 New Network Loads Connected With the
Transmission Provider: The Network Customer shall
provide the Transmission Provider with as much
advance notice as reasonably practicable of the
designation of new Network Load that will be added to
its Transmission System. A designation of new Network
Load must be made through a modification of service
pursuant to a new Application. The Transmission
Provider will use due diligence to install any
transmission facilities required to interconnect a new
Network Load designated by the Network Customer.
The costs of new facilities required to interconnect a
new Network Load shall be determined in accordance
with the procedures provided in Section 32.4 and shall
be charged to the Network Customer in accordance
with Commission policies.
31.3 Network Load Not Physically Interconnected with
the Transmission Provider: This section applies to both
initial designation pursuant to Section 31.1 and the
subsequent addition of new Network Load not
physically interconnected with the Transmission
EXHIBIT NO. 207
Case Nos. AVU-04-1 and AVU-G-O4-
D. Peseau, Potlatch
June 21 , 2004 Page 6 of 10
Provider. To the extent that the Network Customer
desires to obtain transmis~ion service for a load outside
the Transmission Provider s Transmission System, the
Network Customer shall have the option of (i) electing
to include the entire load as Network Load for all
purposes under Part ill of the Tariff and designating
Network Resources in connection with such additional
Network Load, or (ii) excluding that entire load from its
Network Load and purchasing Point-To-Point
Transmission Service under Part n of the Tariff. To the
extent that the Network Customer gives notice of its
intent to add a new Network Load as part of its
Network Load pursuant to this section the request must
be made through a modification of service pursuant to a
new Application.
31.4 New Interconnection Points: To the extent the
Network Customer desires to add a new Point of
Delivery or interconnection point between the
Transmission Provider s Transmission System and a
Network Load, the Network Customer shall provide the
Transmission Provider with as much advance notice as
reasonably practicable.
31.5 Changes in Service Requests: Under no
circumstances shall the Network Customer s decision to
cancel or delay a requested change in Network
Integration Transmission Service ~.g. the addition of a
new Network Resource or designation of a new Network
Load) in any way relieve the Network Customer of its
obligation to pay the costs of transmission facilities
constructed by the Transmission Provider and charged
to the Network Customer as reflected in the Service
Agreement. However, the Transmission Provider must
treat any requested change in Network Integration
Transmission Service in a non-discriminatory manner.
31.6 Annual Load and Resource Information Updates:
The Network Customer shall provide the Transmission
Provider with annual updates of Network Load and
Network Resource forecasts consistent with those
included in its Application for Network Integration
Transmission Service under Part ill of the Tariff. The
Network Customer also shall provide the Transmission
Provider with timely written notice of material changes
in any other information provided in its Application
EXHIBIT NO. 207
Case Nos. AVU-04-1 and AVU-G-O4-
D. Peseau, Potlatch
June 21 , 2004 Page 7 of 10
relating to the Network Customer s Network Load,
Network Resources, its transmission system or other
aspects of its facilities or operations affecting the
Transmission Provider s ability to provide reliable
service.
cont.
34 Rates and Charges
The Network Customer shall pay the Transmission Provider for any Direct
Assignment Facilities, Ancillary Services, and applicable study costs, consistent with
Commission policy, along with the following:
34.1 Monthly Demand Charge: The Network Customer
shall pay a monthly Demand Charge, which shall be
determined by multiplying its Load Ratio Share times
one twelfth (1/12) of the Transmission Provider
Annual Transmission Revenue Requirement specified
in Attachment H.
34.2 Determination of Network Customer s Monthly
Network Load: The Network Customer s monthly
Network Load is its hourly load (including its
designated Network Load not physically interconnected
with the Transmission Provider under Section 31.
coincident with the Transmission Provider s Monthly
Transmission System Peak.
34.3 Determination of Transmission Provider s Monthly
Transmission System Load: The Transmission
Provider s monthly Transmission System load is the
Transmission Provider s Monthly Transmission System
Peak minus the coincident peak usage of all Firm Point-
To-Point Transmission Service customers pursuant to
Part n of this Tariff plus the Reserved Capacity of all
Firm Point- To-Point Transmission Service customers.
34.4 Redispatch Charge: The Network Customer shall
pay a Load Ratio Share of any redispatch costs
allocated between the Network Customer and the
EXHIBIT NO. 207
Case Nos. AVU-E-O4-1 and AVU-G-O4-
D. Peseau, Potlatch
June 21 , 2004 Page 8 of 10
Transmission Provider pursuant to Section 33. To the
extent that the Transmission Provider incurs an
obligation to the Network Customer for redispatch costs
in accordance with Section 33, such amounts shall be
credited against the Network Customer s bill for the
applicable month.
34.5 Stranded Cost Recovery: The Transmission
Provider may seek to recover stranded costs from the
Network Customer pursuant to this Tariff in
accordance with the terms, conditions and procedures
set forth in FERC Order No. 888. However, the
Transmission Provider must separately file any
proposal to recover stranded costs under Section 205 of
the Federal Power Act.
EXHIBIT NO. 207
Case Nos. AVU-04-1 and AVU-G-O4-
D. Peseau, Potlatch
June 21 , 2004 Page 9 of 10
1.18 Load Ratio Share: Ratio of a Transmission Customer s Network Load to the
Transmission Provider s total load computed in accordance with Sections 34.2 and
34.3 of the Network Integration Transmission Service under Part ill the Tariff and
calculated on a rolling twelve month basis
EXHIBIT NO. 207
Case Nos. AVU-E-O4-1 and AVU-G-O4-
D. Peseau, Potlatch
June 21 , 2004 Page 10 of 10
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1
Exhibit No.
Page 2 of 2
Revised Computation of Dr. Avera s Schedule WEA-4
Based on Baa-rated Public Utility Bond Rates
Baa-rated
Allowed Public Utility Risk
Year ROE Bond Yield Premium
1974 13.10%84%26%
1975 13.20%10.96%24%
1976 13.10%82%28%
1977 13.30%06%24%
1978 13.20%62%58%
1979 13.50%10.96%54%
1980 14.23%13.95%28%
1981 15.22%16.60%38%
1982 15.78%16.45%67%
1983 15.36%14.20%16%
1984 15.32%14.53%79%
1985 15.20%12.96%24%
1986 13.93%10.00%93%
1987 12.99%10.53%2.46%
1988 12,79%11 .00%79%
1989 12.97%97%00%
1990 12.70%1 0.06%64%
1991 12.55%55%00%
1992 12.09%86%23%
1993 11.41%91%50%
1994 11.34%63%71%
1995 11.55%29%26%
1996 11.39%17%22%
1997 11.40%95%3.45%
1998 11.66%26%4.40%
1999 10.77%88%89%
2000 11 .43%36%07%
2001 11,08%02%06%
2002 11. 16%02%14%
Average 10.32%56%
Regr~ssion Output Current Equity Risk Premium
Constant
Std Err of Y Est
R Squared
No. of Observations
Degrees of Freedom
0747
0057
8306
Average Yield over Study Period
June 2004 Baa-rated utility bond yield
Change in Yield
10.32%
56%
76%
X Coefficient(s:
Std Err of Coef
t-statistic
-0.4755
0413
11.
Risk premiumlinterest rate relationship
Adjustment to Average Risk Premium
-47.55%
79%
Average risk premium over Study Peria(
Adjusted risk premium
Current Equit~ Cost Estimate
56%
35%
10.
6/10/04
EXHIBIT NO. 209
Case Nos. AVU-04-1 and AVU-G-04-
D. Peseau, PotlatchJune 21, 2004 Page 2 of 2
Revised Computation of Dr. Avera s Schedule WEA-
5&P Electric companies
Year Retum Index
1945 000
1946 0.49%0995
1947 12.17%0874
1948 47%887
1949 2449%104
1950 27%162
1951 17.25%363
1952 19.66%631
1953 919%780
1954 2346%198
1955 12.33%469
1956 83%539
1957 10.29%800
1958 38.35%874
1959 77%059
1960 21.84%946
1961 28.89%374
1962 70%483
1963 10.29%150
1964 15.36%8248
1965 99%495
1966 34%126
1967 67%909
1968 66%594
1969 13.42%7.441
1970 12.59%377
1971 26%567
1972 19%926
1973 1871%256
1974 25.36%416
1975 50 . 39%145
1976 23.53%10.061
1977 21%10.988
1978 78%10.572
1979 51%10.626
1980 86%11.355
1981 20.45%13.677
1982 35.59%18.545
1983 13.36%21.023
1984 24.72%26.219
1985 25.34%32.863
1986 28.06%42.085
1987 31%39.008
1988 17.16%45.702
1989 31.48%60.089
1990 06%61.327
1991 28.91%79.057
1992 45%83.365
1993 12.56%93.836
1994 1317%81.478
1995 30.15%106.043
1996 32%105.704
1997 25.03%132.161
1998 15.04%152.038
1999 18.93%123.258
2000 51.67%188.945
2001 14.78%159.314
2002 14.41%136.357
Averages 10.28%01%
Premiums
Current A-rated utility bond
Equity cost
6/10104
Exhibit No
Rated Utility bondsReturn Inaex
000
028
004
033
125
1134
077
124
145
216
209
112
194
151
158
240
292
414
439
513
500
432
364
374
276
383
607
725
794
747
850
261
353
2361
268
222
210
3135
349
922
026
228
266
937
056
634
10.016
11.195
12.054
13.179
15.287
17.157
19.408
20.931
19.757
21.093
22.738
26.185
91%
41%
86%
93%
75%
03%
37%
93%
618%
61%
01%
39%
61%
60%
06%
25%
939%
82%
10%
82%
55%
-4.78%
75%
11%
34%
16.22%
37%
98%
63%
89%
22.21%
08%
36%
94%
05%
54%
41.86%
83%
17.11%
28.16%
23.90%
61%
10.71%
16.13%
18%
16.01%
11.77%
67%
33%
16.00%
12.23%
13.12%
85%
61%
76%
80%
15.16%
27%90%
Arithmetic Geometric01% 3.11%1% 6.
10.1% 9.
EXHIBIT NO. 210
Case Nos. AVU-E-O4-1 and AVU-04-
D. Peseau, Potlatch
June 21 , 2004
Summary of Dr. Avera s Estimates and Updated and Correc~
Equity Cost Estimates for Dr. Avera s Samples of Electric Util
'----.
Dr. Avera Updated
with and
Flotation Costs Corrected
DCF 10.40/0 9, 3 %1 "
Risk premium WEA-4 11.40/0 10.80/0 10.90/0 50/0
Risk premium WEA-10.80/0 20/0 10,10/0 20/0
CAPM 11.90/0 10,90/0 00/0
verage-11.10/0 10,10/0
Recommended 11.50/0
Difference between Dr. Avera s recommended
ROE and average of updated equity cost estimates
40/0
Note: Average of 10.1 % is simple average of the results of the three methods,
6/1 0/04
EXHIBIT NO. 211
Case Nos. AVU-04-1 and AVU-04-
D. Peseau, Potlatch
June 21 , 2004
Baa Bond Rates October 2001 to April 2004
October 2001
November 2001
December 2001
January 2002
February 2002March 2002
Apri I 2002May 2002June 2002July 2002August 2002
September 2002
October 2002
November 2002
December 2002January 2003
February 2003March 2003
Apri I 2003May 2003June 2003July 2003August 2003
September 2003
October 2003
November 2003
December 2003
January 2004
February 2004March 2004
Apri I 2004
Baa Bond
Yields (010)
Decrease since October 2001
6/10/04
EXHIBIT NO. 212
Case Nos. AVU-E-O4-1 and AVU-04-
D. Peseau, Potlatch
June 21 , 2004
CERTIFICATE OF SERVICE
I HEREBY CERTIFY that on this 21 st day of June 2004, I caused to be served a
true and correct copy of the foregoing document by the method indicated below, and
addressed to the following:
Jean Jewell
Idaho Public Utilities Commission
472 W. Washington Street
O, Box 83720
Boise, ID 83720-0074
) U.S. Mail
( ~
Hand Delivered
) Overnight Mail
) Facsimile
Scott Woodbury
John Hammond
Idaho Public Utilities Commission
472 W, Washington Street
O. Box 83720
Boise, ID 83720-0074
swoodbu~puc.state.id. us
jhammon~puc.state.id. us
) U.S. Mail
(JHand Delivered
) Overnight Mail
) Facsimile
) E-Mail
David J. Meyer
Senior Vice President and General Counsel
A vista Corporation
O. Box 3727
1411 E. Mission Ave" MSC-
Spokane, W A 99220-3727
david.meyer~avistacorp, com
) U.S, Mail
) Hand Delivered
( yIJ Overnight Mail
) Facsimile
) E-Mail
Kelly Norwood
Vice President, State and Federal Regulation
A vista Utilities
O. Box 3727
1411 E. Mission Ave., MSC- 7
Spokane, WA 99220-3727
kelly ,norwood~avistacorp ,com
) U.S. Mail
) Hand Delivered
( v1 Overnight Mail
) Facsimile
) E-Mail
Dennis E, Peseau, Ph.
Utility Resources, Inc.
1500 Liberty Street SE, Ste. 250
Salem, OR 97302
dpeseau~excite.com
(v1 U,S. Mail
) Hand Delivered
) Overnight Mail
) Facsimile
) E-Mail
Charles L.A. Cox
EV ANS, KEANE
111 Main Street
P ,0. Box 659
Kellogg, ID 83837
ccox~usamedia.
J U.S. Mail
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Michael Karp
147 Appaloosa Lane
Bellingham, W A 98229
michael~awish.net
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J Facsimile
J E-Mail
J U.S. Mail
( 1 Hand Delivered
( v1 Overnight Mail
J Facsimile
J E-Mail
Brad M. Purdy
Attorney at Law
2019 N. ih Street
Boise, ID 83702
bmpurdy~hotmail,com
Anthony J. Yankel
29814 Lake Road
Bay Village, OH 44140
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J E-Mail
Jbdi(!;.tMuW hv
Conley E. Ward