20040506Application.pdf

RECEIVEIl
FILED
lon4HAY PH3:St.
INTERMOUNTAIN, G COM"P.Ik\tN"M
' '
OTIlmE:S"tOMHISSION
CASE NO. INT-(;.;.O4~ 0)...,
APPLICATION,
, EXHIBITS,
AND
WORKPAPERS
I '
In tbel\1atter oftbe ApplicationofINTERMOUNTA:iNGASCOMPANY
, ', '
forAutbority to Increase Its Prices oriJuly 1~2004
. (July 1 2004'PurcbasedGas CostAdju,stmentFiling)
Morgan W. Richards, Jr.
MOFFATT, THOMAS , BARRETT, ROCK & FIELDS, CHARTERED
PO Box 829, Boise, Idaho 83701
Telephone [phone]
MTBR&F 11-500.324
Attorneys for illtermountain Gas Company
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
ill the Matter of the Application of
INTERMOUNTAIN GAS COMPANY
for Authority to illcrease Its Prices
Case No. INT -04- ()
APPLICATION
illtermountain Gas Company ("illtermountain ), an Idaho corporation with general offices
located at 555 South Cole Road, Boise, Idaho, hereby requests authority, pursuant to Idaho Code
Sections 61-307 and 61-622, to place in effect July 1 , 2004 new rate schedules which will increase
its annualized revenues by $22.1 million, pursuant to the Rules of Procedure of the Idaho Public
Utilities Commission ("Commission ). Because of changes in illtermountain s gas related costs, as
described more fully in this Application, illtermountain s earnings will not be increased as a result
of the proposed changes in prices and revenues. illtermountain s current rate schedules showing
proposed changes are attached hereto as Exhibit No.1 and are incorporated herein by reference.
illtermountain s proposed rate schedules are attached hereto as Exhibit No.2 and are incorporated
herein by reference.
Communications in reference to this Application should be addressed to:
Michael E. Huntington
Vice President - Marketing & External Affairs
illtermountain Gas Company, Post Office Box 7608, Boise, ID 83707
and
Morgan W. Richards, Jr.
Moffatt, Thomas, Barrett, Rock & Fields, Chartered
Post Office Box 829, Boise, ID 83701
ill support of this Application, illtermountain does allege and state as follows:
APPLICATION - 2
mtermountain is a gas utility, subject to the jurisdiction of the Idaho Public Utilities
Commission, engaged in the sale of and distribution of natural gas within the State of Idaho under
authority of Commission Certificate No. 219 issued December 2, 1955, as amended and
supplemented by Order No. 6564, dated October 3 , 1962.
mtermountain provides natural gas service to the following Idaho communities and counties
and adjoining areas:
Ada County - Boise, Eagle, Garden City, Kuna, Meridian, and Star;
Bannock County - Chubbuck, fukom, Lava Hot Springs, McCammon, and Pocatello;
Bear Lake County - Georgetown, and Montpelier;
Bingham County - Aberdeen, Basalt, Blackfoot, Firth, Fort Hall, Moreland/Riverside, and Shelly;
Blaine County - Bellevue, Hailey, Ketchum, and Sun Valley;
Bonneville County - Ammon, Idaho Falls, Iona, and Ucon;
Canyon County - Caldwell, Greenleaf, Middleton, Nampa, Parma, and Wilder;
Caribou County - Bancroft, Conda, Grace, and Soda Springs;
Cassia County - Burley, Declo, Malta, and Raft River;
Elmore County - Glenns Ferry, Hammett, and Mountain Home;
Fremont County - Parker, and St. Anthony;
Gem County - Emmett;
Gooding County - Gooding, and Wendell;
Jefferson County - Lewisville, Menan, Rigby, and Ririe;
Jerome County - Jerome;
Lincoln County - Shoshone;
Madison County - Rexburg, and Sugar City;
Minidoka County - Heyburn, Paul, and Rupert;
Owyhee County - Bruneau, Homedale;
Payette County - Fruitland, New Plymouth, and Payette;
Power County - American Falls;
Twin Falls County - Buhl, Filer, Hansen, Kimberly, Murtaugh, and Twin Falls;
Washington County - Weiser.
mtermountain s properties in these locations consist of transmission pipelines, a compressor
station, a liquefied natural gas storage facility, distribution mains, services, meters and regulators
and general plant and equipment.
II.
mtermountain seeks with this Application to pass through to each of its customer classes a
change in gas related costs resulting from: 1) changes in mtermountain s firm transportation and
storage costs resulting from Intermountain s management of its storage and firm capacity rights on
pipeline systems including the Williams Northwest Pipeline ("Williams" or "Northwest"), 2) an
APPLICATION - 3
increase in mtermountain s Weighted Average Cost of Gas ("W ACOG"), 3) an updated customer
allocation of gas related costs pursuant to the Company s Purchased Gas Cost Adjustment
provision, and 4) the inclusion of temporary surcharges and credits for one year relating to gas and
interstate transportation costs from mtermountain s deferred gas cost account. Exhibit No.
contains pertinent excerpts from pipeline and related facilities tariffs. mtermountain also seeks with
this Application to eliminate the temporary surcharges and credits included in its current prices
during the past 12 months, pursuant to Case No. INT-03-Ol. The aforementioned changes would
result in an overall price increase to Intermountain s RS-, RS-, GS-, LV-, T-1 and T-
customers.
These price changes are applicable to service rendered under rate schedules affected by and
subject to mtermountain s Purchased Gas Cost Adjustment ("PGA"), initially approved by this
Commission in Order No. 26109, Case No. INT-95-, and additionally approved through
subsequent proceedings.
Exhibit No.4 summarizes the price changes in: 1) mtermountain s base rate gas costs and its
rate class allocation, and 2) adjusting temporary surcharges or credits flowing through to
mtermountain s direct sales and transportation customers. Exhibit No.'s 3 and 4 are attached hereto
and incorporated herein by reference.
III.
The current prices of mtermountain are those approved by this Commission in Order
No. 29277, Case No. INT-03-01.
IV.
Intermountain s proposed prices incorporate all price changes impacting Intermountain
mterstate Capacity including, but not limited to, prices charged by Northwest which have
transpired since Intermountain s last PGA filing in Case No. INT-03-01. Exhibit No., Lines
through 19 details the proposed changes in Intermountain prices resulting from
Intermountain s natural gas interstate and upstream transportation and storage costs.
Intermountain s review of the adequacy of its interstate transportation and storage
services is performed on an annual basis under design weather and certain load growth
assumptions. A summary of the methodology incorporated within this annual review was
included in the Company s Integrated Resource Plan, which is currently on file with this
APPLICATION - 4
Commission. Intermountain s interstate pipeline capacity was forecast to be in a deficit position
thereby jeopardizing the Company s ability to deliver an uninterrupted supply of natural gas to its
firm sales customers during the coming winter heating seasons. mtermountain continues to take
the necessary steps to manage its interstate and upstream pipeline capacity and storage in order to
insure an uninterrupted flow of natural gas to its firm sales customers and has procured an
incremental amount of economically priced interstate and upstream transportation to ensure such.
Exhibit No.Rows 3-, include the costs for this incremental interstate and upstream
transportation.
The W ACOG reflected in mtermountain s proposed prices is $0.55492 per therm, as shown
on Exhibit No., Lines 25 through 28, Column (f). This compares to $0.47500 per therm currently
included in the Company s tariffs. Natural gas is a commodity traded in the open market and, as
with all other commodities, is subject to the same laws of supply and demand. The supply of natural
gas seeks equilibrium with demand without ever actually achieving it. Natural gas prices become
volatile, within a range of volatility, as available supplies seek symmetry with demand or visa versa.
As was again played out in the marketplace over the last several months, high natural gas prices
indicative of weakening supplies have spurred on additional exploration and production and, as
natural gas supplies become more plentiful, market prices should decline. Exhibit No.
demonstrates the relationship between natural gas prices and drilling activity in North America.
Exhibit No.5 is attached hereto and incorporated herein by reference.
mtermountain believes that current futures prices, subject to the laws of supply and demand
are poised for further softening. However, liquidity in the market is sustained by contrary opinions
and natural gas prices could indeed realize the levels included in this Application, which are the
forward prices currently available through the use of financial derivatives as of April 30, 2004.
Although current commodity futures prices dictate the use of this $0.55492 per therm W ACOG
mtermountain continues to remain vigilant in monitoring natural gas prices and is committed to
come before this Commission prior to this winters heating season with an Application to further
amend these proposed prices, should these forward prices materially deviate from the $0.55492 per
thermo Timely natural gas price signals and the accounting for any cost differences brought about by
these volatile markets, facilitated through the use of the PGA mechanism, enhances our customers
APPLICATION - 5
ability to make timely and informed energy use decisions and ensures they only pay the actual cost
of such supplies. It is important to continue to alert our customers in a timely manner to these
impending increases before their higher natural gas usage is before them.
VI.
Pursuant to Case No. INT-03-, mtermountain has included temporary surcharges and
credits in its July 1 , 2003 prices for the principal reason of collecting or passing back to its
customers deferred gas cost charges and benefits, as outlined in Case No. INT-03-01. Line 33 of
Exhibit No.4 reflects the elimination of these temporary surcharges and credits.
VII.
mtermountain s PGA tariff includes provisions whereby Intermountain s proposed prices
will be adjusted for updated customer class sales volumes and purchased gas cost allocations
pursuant to the Company s approved cost of service methodology. mtermountain s proposed prices
include a fixed cost collection adjustment pursuant to these PGA provisions, as outlined on Exhibit
No., Line 24. The price impact of this adjustment is included on Exhibit No., Line No. 34.
Exhibit No.6 is attached hereto and incorporated herein by reference.
VIII.
mtermountain is party to certain agreements whereby mtermountain has released segmented
portions of its firm capacity rights when not needed to meet its customer needs. mtermountain
proposes to pass back to its customers the benefits generated from the capacity release agreements
totaling $2.4 million. Exhibit No., Line 1 , reflects the inclusion of the $2.4 million credit.
mtermountain proposes to pass back this amount via the per therm credit as detailed on Exhibit
No.8. Exhibit No.'s 7 and 8 are attached hereto and incorporated herein by reference.
IX.
mtermountain proposes to allocate deferred gas costs from its Account No. 186 balance to
its customers through temporary price adjustments to be effective during the 12-month period
ending June 30, 2005 , as follows:
1) mtermountain has been deferring in its Account No. 186 fixed gas costs. The
debit amount shown on Exhibit No., Line 9, Co!. (b) of$2.7 million is predominantly attributable
to the collection of interstate pipeline capacity costs and the true-up of expense issues previously
ruled on by this Commission. mtermountain proposes to collect or pass back these balances via the
APPLICATION - 6
per therm surcharges and credits, as detailed on Exhibit No.9 and included on Exhibit No., Line
2. Exhibit No.9 is attached hereto and incorporated herein by reference.
2) mtermountain has been deferring in its Account No. 186 deferred gas cost credits
of $1.1 million, as shown on Exhibit No. 10, Line 2, Co!. (b), attributable to mtermountain
management of variable gas costs since July 1 , 2003. mtermountain proposes to pass back this
credit balance via a per therm credit, as shown on Exhibit No.1 0, Line 4, Co!. (b) and included on
Exhibit No., Line 3. Exhibit No. 10 is attached hereto and incorporated herein by reference.
mtermountain has allocated the proposed price changes to each of its customer classes
based upon mtermountain s PGA provision. A straight cents per therm price decrease was not
utilized for the T -1 tariff. No fixed costs are currently recovered in the tail block of mtermountain
I tariff. Absent Williams' firm transportation TF-1 Commodity Charge, the proposed decrease
in the T -1 tariff is fixed cost related, and therefore, a cents per therm decrease was made only to the
first two blocks of the tariff for these fixed costs.
XI.
The proposed decrease in the T-2 tariffis fixed cost related, and therefore, a cents per therm
decrease was made only to the T-2 demand charge for these fixed costs.
XII.
Exhibit No. 11 is an analysis of the overall price changes by class of customer. Exhibit No.
11 is attached hereto and incorporated herein by reference.
XIII.
The proposed overall price change herein requested among the classes of service of
mtermountain will not affect mtermountain s earnings, and is just, fair, and equitable.
XIV.
This Application is filed pursuant to the applicable statutes and the Rules and Regulations
of the Commission.This Application has been brought to the attention of mtermountain
customers through a Customer Notice and by a Press Release sent to daily and weekly newspapers
and major radio and television stations in mtermountain s service area. The Press Release and
Customer Notice are attached hereto and incorporated herein by reference. Copies of this
Application, its Exhibits, and Workpapers have been provided to those parties regularly intervening
APPLICATION - 7
in mtermountain s rate proceedings.
xv.
mtermountain requests that this matter be handled under modified procedure pursuant to
Rules 201-204 of the Commission s Rules of Procedure. mtermountain stands ready for immediate
consideration of this matter.
APPLICATION - 8
WHEREFORE, futermountain respectfully petitions the Idaho Public Utilities Commission
as follows:
a. That the proposed rate schedules herewith submitted as Exhibit No.2 be approved
without suspension and made effective as of July 1 , 2004 in the manner shown on Exhibit No.
That this Application be heard and acted upon without hearing under modified
procedure, and
c. For such other relief as this Commission may determine proper herein.
DATED at Boise, Idaho, this 5th day of May, 2004.
INTERMOUNTAIN GAS COMPANY MOFFATT, THOMAS, BARRETT, ROCK
& FIELDS, CHARTERED
)'
Michael E. Huntington
Vice President
Marketing & External Affairs
By
~--
l)'Mor~hards, Jr.
Of the Firm
Attorneys for Intermountain Gas Company
APPLICATION - 9
CERTIFICATE OF MAILING
I HEREBY CERTIFY that on this 5th day of May, 2004, I served a copy of the
foregoing Case No. INT-04- upon:
Lisa Nordstrom
Deputy Attorney General
Idaho Public Utilities Commission
472 W. Washington St., PO Box 83720
Boise, ID 83720-0074
Edward A. Finklea
Paula E. Pyron
Energy Advocates LLP
526 NW 18th Avenue
Portland, OR 97209
R. Scott Pasley
1. R. Simplot Company
PO Box 27
Boise, ID 83707
David Hawk
J. R. Simplot Company
PO Box 27
Boise, ID 83707
Conley E. Ward, Jr.
Givens, Pursley, Webb & Huntley
277 N. 6th St., Suite 200
PO Box 2720
Boise, ID 83701
Paula Pyron
Northwest fudustrial Gas Users
4113 Wolf Berry Court
Lake Oswego, OR 97035
Wendell M. Phillips
615 South Phillippi Street
Boise, ID 83705
by depositing true copies thereof in the United States Mail, postage prepaid, in envelopes addressed
to said persons at the above addresses.
;;;f.:f7 DIrector
Market Services and Regulatory Affairs
APPLICATION - 10
EXHIBIT NO.
CASE NO. INT-O4-
INTERMOUNTAIN GAS COMPANY
CURRENT TARIFFS
Showing Proposed Price Changes
(8 pages)
Exhibit No.
Case No. INT-O4-
Intermountain Gas Company
Page 1 of 8
COMPARISON OF PROPOSED JULY 1 2004 PRICES
TO JULY 1, 2003 PRICES
July 1,2003 Proposed
Line Prices per Proposed July 1, 2004
No.Rate Class INT-03-Adjustment Prices
(a)(b)(c)(d)
RS-
April - November 91883 08046 99929
December - March 80627 08046 88673
RS-
April - November 78022 08083 86105
December - March 74659 08083 82742
GS-
April - November
Block 1 81164 08128 89292
Block 2 78991 08128 87119
Block 3 76889 08128 85017
December - March
Block 1 76079 08128 84207
Block 2 73959 08128 82087
Block 3 71913 08128 80041
CNG Fuel 71913 08128 80041
LV-l (1)
Block 1 60189 07422 (2)67611
Block 2 56340 07422 (3)63762
Block 3 0.49862 05882 (4)0.55744
Block 1 11398 01540 (2)12938
Block 2 07549 01540 (3)09089
Block 3 01071 00000 (4)01071
Demand Block 1 1.53018 16628 69646
Demand Block 2 72860 16628 89488
Commodity Charge 00656 00000 00656
Over-Run Service 04915 00000 04915
(I) The LV -1 Adjustment is calculated by taking Line 22 - 24, Col ( c), plus the change in the
W ACOG, plus removal of the temporary variable surcharge from INT -03-
of $0.01701 , plus the temporary variable debit on Exhibit 10, Line 4, Col (b)
(2) See Workpaper No., Line 13, Col (e)
(3) See Workpaper No., Line 20, Col (e)
(4) See Workpaper No., Line 21, Col (e)
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.Thirty- FoortR Fifth Revised Sheet No. 01 (Page 1 of 1)
Name
of Utility
Exhibit No.
Case No. INT-O4-
Intermountain Gas Company
Page 2 of 8
Intermountain Gas Company leN Ie PI:IBll9 ~ILFI"IES OOMMISSI9- Al'PR9'ItB ErrEs:R'1E
..'U113G'83 cM..'93-e 7l:n='l '
Rate Schedule RS-
RESIDENTIAL SERVICE
AVAILABILITY:
, Available to individually metered consumers not otherwise specifically provided for, usingnatural gas for residential purposes.
RATE:
Monthly minimum charge is the customer charge.
For billinq periods endinq April throuqh November
Customer Charge - $2.50 per bill
$0.99929
Commodity Charge - $91883 per therm
For billinq periods endinq December throuqh March
Customer Charge - $6.50 per bill
$0.88673
Commodity Charge - $80627 per therm
Includes:
Temporary purchased gas cost adjustment of $01590 $(0.00099)
Weighted average cost of gas of $0.47500 $0.55492
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in theCompanys Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of theCompanys Tariff, of which this rate schedule is a part.
Issued by: Intermountain Gas Company
By: Michael E. Huntington Title:
Effective: July 1 , 2OOJ 2004
Vice President - Marketing and External Affairs
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.Thirty-FooftR Fifth Revised Sheet No. 02
Name
of Utility
Exhibit No.
Case No. INT-O4-
Intermountain Gas Company
Page 3 of 8
(Page 1 of 1)
Intermountain Gas Company IElAI16P\;1BLICUfllffIEseOMMI3SIONAPPRO"E!) EFfEeTt'I'L
J8N3G'63 ..'11.1 '93'
o.:.tI. B'\:I.,i
Rate Schedule RS-
MULTIPLE USE RESIDENTIAL SERVICE
AVAILABILITY:
Available to individually metered consumers using gas for several residential purposes
including both water heating and space heating.
RATE:
Monthly minimum charge is the customer charge.
For billina periods endina April throuah November
Customer Charge - $2.50 per bill
$0.86105
Commodity Charge - $78022 per therm
For billina periods endina December throuah March
Customer Charge - $6.50 per bill
$0.82742
Commodity Charge $74659 per therm
Includes:
Temporary purchased gas cost adjustment of $01217 $(0.00417)
Weighted average cost of gas of $0.47500 $0.55492
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the
Company s Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the
Company s Tariff, of which this rate schedule is a part.
Issued by: Intermountain Gas Company
By: Michael E. Huntington Title: Vice President - Marketing and External Affairs
Effective: July 1 2004
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.
Thirty-SOOA Seventh Revised Sheet No. 03 (Page 1 of 2)
Name
of Utility
Exhibit No.
Case No. INT-O4-
Intermountain Gas Company
Page 4 of 8
Intermountain Gas Company
. 11:1."19 PI:IBLIe UflLR"lt:3 ceMMISSIOH
APPRO"ED 'E:rff:cnve
JJN30'93 'R 1 '8J
o. 1:'- .::;1'1;0-
Rate Schedule GS-
GENERAL SERVICE
AVAILABILITY:
Available to individually metered customers whose requirements for natural gas do not exceed000 therms per day, at any point on Company s distribution system. Requirements in excess of000 therms per day may be served under this rate schedule upon execution of a one-year writtenservice contract.
RATE:
Monthly minimum charge is the customer charge.
For billina periods endina April throuah November
Customer Charge - $2.00 per bill
Commodity Charge - First 200 therms per bill $0.81164*$0.89292*
Next 1,800 therms per bill $0.78991*$0.87119*
Over 2 000 therms per bill $0.76889*$0.85017*
For billina periods endina December throuah March
Customer Charge - $9.50 per bill
Commodity Charge - First 200 therms per bill $Q.76079*$0.84207*
Next 1,800 therms per bill $0.73959*$0.82087*
Over 2,000 therms per bill $0.71913*$0.80041*
Includes:
Temporary purchased gas cost adjustment of $0.01700 $(0.00179)
Weighted average cost of gas of $0.47500 $0.55492
Issued by: Intermountain Gas Company
By: Michael E. Huntington Title:
Effective: July 1 2004
Vice President - Marketing and External Affairs
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.
Thirty-SOOA Seventh Revised Sheet No. 03 (Page 2 of 2)
Name
of Utility
Exhibit No.
Case No. INT-O4-
Intermountain Gas Company
Page 5 of 8
Intermountain Gas Company 19.'\119 P\;IBLIO IffILR'II:S CO MMlsSlOK-'AI'PRO\;'ED 'm:SiIVt
JJN30't1S ,.JIll 'Q;3
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Rate Schedule GS-
GENERAL SERVICE (Continued)
For separately metered deliveries of gas utilized solely as Compressed Natural Gas Fuel invehicular internal combustion engines.
Customer Charge - $9.50 per bill
$0.80041
Commodity Charge - $0.71913 per therm
Includes:
Temporary purchased gas cost adjustment of $0.01700 $(0.00179)
Weighted average cost of gas of $0.47500 $0.55492
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in theCompanys Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
1. Any GS-1 customer who leaves the GS-1 service will pay to Intermountain Gas Company,
upon exiting the GS-1 service, all gas and transportation related costs incurred to serve
the customer during the GS-1 service period not borne by the customer during the time the
customer was using GS-1 service. Any GS-1 customer who leaves the GS-1 service willhave refunded to them, upon exiting the GS-1 service, any excess gas commodity ortransportation payments made by the customer during the time they were a GS-
customer.
2. All natural gas service hereunder is subject to the General Service Provisions of the
Company s Tariff, of which this rate schedule is a part.
Issued by: Intermountain Gas Company
By: Michael E. Huntington Title:
Effective: July 1 , 2OOd 2004
Vice President - Marketing and External Affairs
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.Fort -FooftR Fifth Revised Sheet No. 04 (Page 1 of
Exhibit No.
Case No. INT-O4-
Intermountain Gas Company
Page 6 of 8
Name
of Utili Intermountain Gas Com pan 15AH6 pl:!BLle l:1fILfTICS OOMMIG619t1APPROVCS CrFt:~
.M( 3 9 '03 J..'q '01-
\!e.'-.llI, .7190-,-; . '
SEe!1EWf(
Rate Schedule LV-
LARGE VOLUME FIRM SALES SERVICE
AVAILABILITY:
Available at any mutually agreeable delivery point on the Company s distribution system to any
existing customer receiving service under the Company s rate schedules LV-1, T-1, or T-2, or any new
customer whose usage does not exceed 500 000 therms annually, upon execution of a one-year
minimum written service contract for firm sales service in excess of 200,000 therms per year.
MONTHLY RATE:
Commodity Charge:
First 250,000 therms per bill $0.60189*$0.67611*Next 500,000 therms per bill $0.56340*$0.63762*
Amount Over 750,000 therms per bill $0.49862**$0.55744**
The above prices include weighted average cost of gas of $0.47500 $0.55492
Includes temporary purchased gas cost adjustment of $0.01475 $(0.00372)
**
Includes temporary purchased gas cost adjustment of $0.01701 $(0.00409)
PURCHASED GAS COST ADJUSTMENT (PGA):
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company
Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
1. All natural gas service hereunder is subject to the General Service Provisions of the
Company s Tariff, of which this Rate Schedule is a part.2. Any LV-1 customer who exits the LV-1 service at any time (including, but not limited to, the
expiration of the contract term) will pay to Intermountain Gas Company, upon exiting the LV-1 service,
all gas and/or interstate transportation related costs to serve the customer during the LV-1 contractperiod not borne by the customer during the LV-1 contract period. Any LV-1 customer will have
refunded to them, upon exiting the LV-1 service, any excess gas and/or interstate transportation related
payments made by the customer during the LV-1 contract period.3. In the event that total deliveries to any customer within the last three contract periods met or
exceeded the 200,000 therm threshold, but the customer during the current contract period used less
than the contract minimum of 200,000 therms, an additional amount shall be billed. The additional
amount shall be calculated by billing the deficit usage below 200,000 therms at the T -1 Block 1 rate. Thecustomers future eligibility for the LV-1 Rate Schedule will be renegotiated with the Company.
Issued by: Intermountain Gas Company
By: Michael E. Huntington Title: Vice President - Marketing and External AffairsEffective: July 1, 2OOd 2004
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.
Thirtieth Thirty-First Revised Sheet No. 05
Name
of Utility
(Page 1 of
Intermountain Gas Company
Exhibit No.
Case No. INT-04-
Intermountain Gas Company
Page 7 of 8
IDId 16 F'l;IBLIC lfI'lLITICS COMMISSIO
APPRG'..ED crrccmt:
JtJN:;O '03 .JJL 1 'BJ
Ro.,.o" .?'1;;'/,
~~
ealfIE'IMV
Rate Schedule T-
FIRM TRANSPORTATION SERVICE
AVAilABILITY:
Available at any mutually agreeable delivery point on the Company s distribution system to any existing
customer receiving service under the Company s rate schedules lV-, T-, or T-, upon execution of a one
year minimum written service contract for firm transportation service in excess of 200,000 therms per year.
MONTHLY RATE:
Commodity Charge:
Block One:
Block Two:
Block Three:
First 250 000 therms transported $0.11398*$0.12938*
Next 500 000 therms transported $0.07549*$0.09089*
Amount over 750 000 therms transported ~ $0.01071
Includes temporary purchased gas cost adjustment of $(0.00226)$0.00037
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company
Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
1. All natural gas service hereunder is subject to the General Service Provisions of the Company s Tariff, of
which this Rate Schedule is a part.
2. The customer shall negotiate a Maximum Daily Firm Quantity (MDFQ) amount, which will be stated in and
will be in effect throughout the term of the service contract. The MDFQ shall not exceed the customer
historical maximum daily usage, as agreed to by the Company.
In the event the Customer requires daily usage in excess of the MDFQ, and subject to the availability of
firm interstate transportation to service Intermountain s system, all such usage may be transported and
billed under either secondary rate schedule T-3 or T -4. The secondary rate schedule to be used shall be
predetermined by negotiation between the Customer and Company, and shall be included in the service
contract. All volumes transported under the secondary rate schedule are subject to the provisions of the
applicable rate schedule T -3 or T -4.
Issued by: Intermountain Gas Company
By: Michael E. Huntington Title: Vice President - Marketing and External Affairs
Effective: July 1 2004
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.
Eleventh Twelfth Revised Sheet No.
Exhibit No.
Case No. INT-04-
Intermountain Gas Company
Page 8 of 8
10 (Page 1 of 2)
Name
of Utility Intermountain Gas Company 19.110 rustlS bJ:rllR'IE& OOMMISSIONAl'PRaVtB Emc:R'JE
Jllln e '63 JIlL 1 '83
. ~.- ~.
oa. .Jqa ,
Rate Schedule T-
FIRM TRANSPORTATION SERVICE WITH MAXIMUM DAILY DEMANDS
AVAilABILITY:
Available at any mutually agreeable delivery point on the Company s distribution system to anyexisting T -2 customer whose daily contract demand for nonammonia therms on any given day meets orexceeds a predetermined level agreed to by the customer and the Company upon execution of a one-yearminimum written service contract for firm transportation service in excess of 200 000 therms per year.
MONTHLY RATE:
Firm Service
Demand Charge:
Firm Daily Demand -
First 15 000 therms
Amount over 15,000 therms
Commodity Charge:
For Firm Therms Transported
Over-Run Service
Rate Per Therm
$1.53018*$1.69646*
$0.72860*$0.89488*
$0.00656
Commodity Charge:
For Therms Transported In Excess Of MDFQ:$0.04915
Includes temporary purchased gas cost adjustment of $(0.09117)$(0.04162)
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the CompanyPurchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the Company
Tariff, of which this Rate Schedule is a part.
The customer shall nominate a Maximum Daily Firm Quantity (MDFQ), which will be stated in and willbe in effect throughout the term of the service contract.
The monthly Demand Charge will be equal to the MDFQ times the Firm Daily Demand rate. Firmdemand relief will be afforded to those T -2 customers paying both demand and commodity chargesfor gas when , in the Company s judgment, such relief is warranted.
The actual therm usage for the month or the MDFQ times the number of days in the billing month,whichever is less, will be billed at the applicable commodity charge for firm the~ms.
Issued by: Intermountain Gas Company
By: Michael E. Huntington
Effective: July 1 2004
Title: Vice President - Marketing and External Affairs
EXHIBIT NO.
CASE NO. INT-O4-
INTERMOUNT AIN GAS COMPANY
PROPOSED TARIFFS
(7 pages)
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.
Thirty-Fifth Revised Sheet No. 01 (Page 1 of 1)
Name
of Utility
Exhibit No.
Case No. INT-O4-
Intermountain Gas Company
Page 1 of 7
Intermountain Gas Company
Rate Schedule RS-
RESIDENTIAL SERVICE
AVAilABILITY:
Available to individually metered consumers not otherwise specifically provided for, using
natural gas for residential purposes.
RATE:
Monthly minimum charge is the customer charge.
For billinQ periods endinQ April throuQh November
Customer Charge - $2.50 per bill
Commodity Charge - $0.99929 per therm
For billinQ periods endinQ December throuQh March
Customer Charge - $6.50 per bill
Commodity Charge - $0.88673 per therm
Includes:
Temporary purchased gas cost adjustment of $(0.00099)
Weighted average cost of gas of $0.55492
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the
Company s Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the
Company s Tariff, of which this rate schedule is a part.
Issued by: Intermountain Gas Company
By: Michael E. Huntington Title:
Effective: July 1 , 2004
Vice President - Marketing and External Affairs
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.
Thirty-Fifth Revised Sheet No. 02
Name
of Utility
Exhibit No.
Case No. INT-O4-
Intermountain Gas Company
Page 2 of 7
(Page 1 of 1)
Intermountain Gas Company
Rate Schedule RS-
MULTIPLE USE RESIDENTIAL SERVICE
AVAilABILITY:
Available to individually metered consumers using gas for several residential purposes
including both water heating and space heating.
RATE:
Monthly minimum charge is the customer charge.
For billinQ periods endinQ April throuQh November
Customer Charge - $2.50 per bill
Commodity Charge - $0.86105 per therm
For billinQ periods endinQ December throuQh March
Customer Charge - $6.50 per bill
Commodity Charge $0.82742 per therm
Includes:
Temporary purchased gas cost adjustment of $(0.00417)
Weighted average cost of gas of $0.55492
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the
Company s Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the
Company s Tariff, of which this rate schedule is a part.
Issued by: Intermountain Gas Company
By: Michael E. Huntington Title:
Effective: July 1 , 2004
Vice President - Marketing and External Affairs
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.Thirty- Seventh Revised Sheet No. 03
Name
of Utility
(Page 1 of 2)
Intermountain Gas Company
Exhibit No.
Case No. INT-O4-
Intermountain Gas Company
Page 3 of 7
Rate Schedule GS-
GENERAL SERVICE
AVAilABILITY:
Available to individually metered customers whose requirements for natural gas do not exceed
000 therms per day, at any point on Company s distribution system. Requirements in excess of
000 therms per day may be served under this rate schedule upon execution of a one-year written
service contract.
RATE:
Monthly minimum charge is the customer charge.
For billina periods endina April throuah November
Customer Charge - $2.00 per bill
Commodity Charge - First 200 therms per bill em $0.89292*
Next 1 800 therms per bill em $0.87119*
Over 2 000 therms per bill em $0.85017*
For billina periods endina December throuah March
Customer Charge - $9.50 per bill
Commodity Charge - First 200 therms per bill em $0.84207*
Next 1,800 therms per bill em $0.82087*
Over 2 000 therms per bill em $0.80041*
Includes:
Temporary purchased gas cost adjustment of $(0.00179)
Weighted average cost of gas of $0.55492
Issued by: Intermountain Gas Company
By: Michael E. Huntington Title:
Effective: July 1 , 2004
Vice President - Marketing and External Affairs
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.Thirty- Seventh Revised Sheet No. 03 (Page 2 of 2)
Name
of Utility
Exhibit No.
Case No. INT-O4-
Intermountain Gas Company
Page 4 of 7
Intermountain Gas Company
Rate Schedule GS-
GENERAL SERVICE (Continued)
For separately metered deliveries of gas utilized solely as Compressed Natural Gas Fuel in
vehicular internal combustion engines.
Customer Charge - $9.50 per bill
Commodity Charge - $0.80041 per therm
Includes:
Temporary purchased gas cost adjustment of $(0.00179)
Weighted average cost of gas of $0.55492
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the
Company s Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
1. Any GS-1 customer who leaves the GS-1 service will pay to Intermountain Gas Company,
upon exiting the GS-1 service, all gas and transportation related costs incurred to serve
the customer during the GS-1 service period not borne by the customer during the time the
customer was using GS-1 service. Any GS-1 customer who leaves the GS-1 service will
have refunded to them, upon exiting the GS-1 service, any excess gas commodity or
transportation payments made by the customer during the time they were a GS-
customer.
2. All natural gas service hereunder is subject to the General Service Provisions of the
Company s Tariff, of which this rate schedule is a part.
Issued by: Intermountain Gas Company
By: Michael E. Huntington Title:
Effective: July 1 , 2004
Vice President - Marketing and External Affairs
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.
Forty-Fifth Revised Sheet No. 04 (Page 1 of 2)
Exhibit No.
Case No. INT-O4-
Intermountain Gas Company
Page 5 of 7
Name
of Utility Intermountain Gas Company
Rate Schedule LV-
LARGE VOLUME FIRM SALES SERVICE
AVAILABILITY:
Available at any mutually agreeable delivery point on the Company s distribution system to any
existing customer receiving service under the Company s rate schedules LV-, T-1, or T-2, or any new
customer whose usage does not exceed 500,000 therms annually, upon execution of a one-year
minimum written service contract for firm sales service in excess of 200,000 therms per year.
MONTHLY RATE:
Commodity Charge:
First 250,000 therms per bill ~ $0.67611*
Next 500 000 therms per bill ~ $0.63762*
Amount Over 750 000 therms per bill ~ $0.55744**
The above prices include weighted average cost of gas of $0.55492
Includes temporary purchased gas cost adjustment of $(0.00372)
**
Includes temporary purchased gas cost adjustment of $(0.00409)
PURCHASED GAS COST ADJUSTMENT (PGA):
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company
Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
1. All natural gas service hereunder is subject to the General Service Provisions of the
Company s Tariff, of which this Rate Schedule is a part.2. Any LV-1 customer who exits the LV-1 service at any time (including, but not limited to, the
expiration of the contract term) will pay to Intermountain Gas Company, upon exiting the LV-1 service
all gas and/or interstate transportation related costs to serve the customer during the LV-1 contract
period not borne by the customer during the LV-1 contract period. Any LV-1 customer will have
refunded to them, upon exiting the LV-1 service, any excess gas and/or interstate transportation related
payments made by the customer during the LV-1 contract period.3. In the event that total deliveries to any customer within the last three contract periods met or
exceeded the 200,000 therm threshold, but the customer during the current contract period used less
than the contract minimum of 200 000 therms, an additional amount shall be billed. The additional
amount shall be calculated by billing the deficit usage below 200 000 therms at the T -1 Block 1 rate. The
customer s future eligibility for the LV-1 Rate Schedule will be renegotiated with the Company.
Issued by: Intermountain Gas Company
By: Michael E. Huntington Title:
Effective: July 1 , 2004
Vice President - Marketing and External Affairs
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.
Thirty-First Revised Sheet No. 05 (Page 1 of 2)
Name
of Utili
Exhibit No.
Case No. INT-04-
Intermountain Gas Company
Page 6 of
Intermountain Gas Com pan
Rate Schedule T-
FIRM TRANSPORTATION SERVICE
AVAilABILITY:
Available at any mutually agreeable delivery point on the Company s distribution system to any existing
customer receiving service under the Company s rate schedules lV-, T-, or T-2, upon execution of a one
year minimum written service contract for firm transportation service in excess of 200,000 therms per year.
MONTHLY RATE:
Commodity Charge:
Block One:
Block Two:
Block Three:
First 250,000 therms transported CID $0.12938*
Next 500 000 therms transported CID $0.09089*
Amount over 750 000 therms transported CID $0.01071
Includes temporary purchased gas cost adjustment of $0.00037
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company
Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
1. All natural gas service hereunder is subject to the General Service Provisions of the Company s Tariff
which this Rate Schedule is a part.
2. The customer shall negotiate a Maximum Daily Firm Quantity (MDFQ) amount, which will be stated in and
will be in effect throughout the term of the service contract. The MDFQ shall not exceed the customer
historical maximum daily usage, as agreed to by the Company.
In the event the Customer requires daily usage in excess of the MDFQ, and subject to the availability
firm interstate transportation to service Intermountain s system, all such usage may be transported and
billed under either secondary rate schedule T -3 or T -4. The secondary rate schedule to be used shall be
predetermined by negotiation between the Customer and Company, and shall be included in the service
contract. All volumes transported under the secondary rate schedule are subject to the provisions of the
applicable rate schedule T -3 or T -4.
Issued by: Intermountain Gas Company
By: Michael E. Huntington Title: Vice President - Marketing and External Affairs
Effective: July 1 , 2004
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.Twelfth Revised Sheet No.
Exhibit No.
Case No. INT-O4-
Intermountain Gas Company
Page 7 of 7
10 (Page 1 of 2)
Name
of Utility Intermountain Gas Company
Rate Schedule T-
FIRM TRANSPORTATION SERVICE WITH MAXIMUM DAILY DEMANDS
AVAilABILITY:
Available at any mutually agreeable delivery point on the Company s distribution system to any
existing T -2 customer whose daily contract demand for nonammonia therms on any given day meets or
exceeds a predetermined level agreed to by the customer and the Company upon execution of a one-year
minimum written service contract for firm transportation service in excess of 200 000 therms per year.
MONTHLY RATE:
Firm Service
Demand Charge:
Firm Daily Demand -
First 15,000 therms
Amount over 15 000 therms
Commodity Charge:
For Firm Therms Transported
Over-Run Service
Rate Per Therm
$1.69646*
$0.89488*
$0.00656
Commodity Charge:
For Therms Transported In Excess Of MDFQ:$0.04915
Includes temporary purchased gas cost adjustment of $(0.04162)
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company
. Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the Company
Tariff, of which this Rate Schedule is a part.
The customershall nominate a Maximum Daily Firm Quantity (MDFQ), which will be stated in and will
be in effect throughout the term of the service contract.
The monthly Demand Charge will be equal to the MDFQ times the Firm Daily Demand rate. Firm
demand relief will be afforded to those T -2 customers paying both demand and commodity charges
for gas when , in the Company s judgment, such relief is warranted.
The actual therm usage for the month or the MDFQ times the number of days in the billing month
whichever is less, will be billed at the applicable commodity charge for firm therms.
Issued by: Intermountain Gas Company
I By: Michael E. Huntington
Effective: July 1 , 2004
Title: Vice President - Marketing and External Affairs
EXHIBIT NO.
CASE NO. INT-O4-
INTERMOUNTAIN GAS COMPANY
PERTINENT EXCERPTS FROM INTERSTATE PIPELINES AND RELATED
FACILITIES
(26 pages)
,u --..n___
.._..
Exhibit No.
Case No. INT-O4-
Intermountain Gas Company
Page 1 of 26
IIII,'III I M",,1. IiamS
NORTNWEST PIPELINE
O. So" 58900
Salt ~ke aty, UT 84158-0900
pnone: [phone]FAX: [phone]
December 18 2003
TO: All HOLDERS OF NORTHWEST PIPELINE CORPORATION'
FERC GAS TARIFF, THIRD REVISED VOLUME NO. ,
Please insert the enclosed tariff sheets listed below into your copy of Northwesfs FERC
Gas Tariff.1 Also, enclosed is a list of Northwest's currently effective tariff sheets as of
January 1 , 2004.
Docket No. RP02-116-O01
On January 23, 2002, Northwest filed the following tariff sheets to address the issues
raised by the Commission in its order dated January 2, 2002 pertaining to Northwesfs
Rate Schedule DEX-1. On November 18, 2003, the Commission issued an order
accepting the tariff sheets, subject to conditions, effective January 1 , 2002.
Substitute Eighth Revised Sheet No.
Substitute Fifteenth Revised Sheet No. 14"
Substitute Second Revised Sheet No. 115"'-
Substitute Second Revised Sheet No. 116**
Substitute Third Revised Sheet No. 11
Substitute Second Revised Sheet No. 118"'-
Substitute Eighth Revised Sheet No. 231~
Seventh Revised Sheet No. 231-
Third Revised Sheet No. 231-
Substitute Original Sheet No. 359-
Substitute Third Revised Sheet No. 360-
- Indicates tariff sheet was distributed in the All-Holders letter dated January 23, 2002
with "Pending Commission Acceptance" on the bottom of the sheet. These sheets can
now be replaced with the enclosed sheets which remove the "Pending Commission
Acceptance" notation.
Docket No. CP02-004
On June 27, 2003, Northwest filed the following tariff sheets containing a provision to
make a one time, pro rata credit to each evergreen Expansion Project shipper for all
base tariff reservation charge revenues received by Northwest for marketing the
expanded compression-only capacity in the Sumas-Chehalis corridor during July
through September 2003. On September 3, 2003, the Commission issued an order
accepting the tariff sheets, effective July 1 , 2003.
Original Sheet No. 26 Sheet Nos. 27 through 29
1 An asterisk (~) following the tariff sheet indicates the tariff sheet has been superseded and is
not included with the enclosed tariff sheets.2 As explained below, proposed Substitute Twenty-First Revised Sheet No. 14 is included in this
list
Exhibit No.
Case No. INT -O4-
Intermountain Gas Company
Page 2 of 26
All-Holders
December 18, 2003
Page 2 of 4
Docket No. AP03-506-00B
On August 1, 2003 in compliance with an order issued July 29, 2003, Northwest filed
the following tariff sheets to remove previously proposed restrictions on reductions of
maximum daily quantities and maximum daily delivery obligations at individual receipt
and delivery points in the event of a partial capacity tumback. On September 3, 2003,
the Commission issued an order accepting the tariff sheets, effective as indicated.
Effective February 25, 2001
Third Substitute Eighth Revised Sheet No. 24
Third Substitute Fifth Revised Sheet No. 259
Third Substitute First Aevised Sheet No. 278-
Effective October 26. 2001
FIrst Revised Sheet No. 278-
Docket No. RP03-577-000
On August 26, 2003, Northwest filed the following tariff sheet to decrease from 2.11 %
to 1.58% the fuel reimbursement factor applicable to Northwesfs transportation service
rate schedules. On September 23, 2003, the Commission issued an order accepting
this tariff sheet, effective October 1 , 2003.
Twentieth Revised Sheet No. 14~
Dj)cket No. RP03-597 -000
On August 28, 2003, Northwest filed the fallowing tariff sheets to reflect incremental
transportation rates, incremental fuel rate provisions and an initial incremental fuel
surcharge in conjunction with the completion of the Evergreen Expansion Project. On
September 30, 2003, the Commission issued an order accepting the tariff sheets
subject to conditions, effective as indicated.
Effective October 1. 2003
Twenty-Fourth Revised Sheet No.
Second Revised Sheet No. 5-
Original Sheet No. 5-
Twenty-First Revised Sheet No. 14'"
Sixth Revised Sheet No. 231-
Original Sheet No. 231-C
Effective November 1 . 2003
Twenty-Fifth Revised Sheet No. 5*
Third Revised Sheet No.
Exhibit No" 3
Case No. INT-O4-
Intermountain Gas Company
ge 3 of 26
All-Holders
, December 18, 2003
Page 3 of 4
On October 3, 2003, Northwest filed the following tariff sheets to correct typographical
errors including the fuel reimbursement factor for Rate Schedules LS-1, LS-2F and LS-
21. These tariff sheets are currently pending acceptanc~ but Substitute Twenty-FIrst
Revised Sheet No. 14 is included with the enclosed tariff sheets since it correctly states
the fuel reimbursement factor for Rate Schedules LS-1, LS-2F and LS-21.
Effective October 1. 2003
Substitute Second Revised Sheet No. 5-
Substitute Twenty-Arst Revised Sheet No. 14
Effective November 1. 2003
Substitute Third Revised Sheet No. 5-
Docket No. RP03-60o-000
On September 8, 2003, Northwest filed the following tariff sheets to provide additional
nomination flexibility after the intraday 2 nomination cycle for certain services.
October 2, 2003, the Commission issued an order accepting the tariff sheets, effective
October 9, 2003.
Third Revised Sheet No. 53
Fifth Revised Sheet No. 54
Afth Revised Sheet No. 55
Arst Revised Sheet No. 56
Fourth Revised Sheet No.1 09
Third Revised Sheet No. 110
First Revised Sheet No. 129
Seventh Revised Sheet No. 228
Docket No. RP04-85-DOO
On November 26, 2003, Northwest filed the following tariff sheets to change its daily
reservation and demand rates to reflect 2004 leap year rates computed on the basis of
366 days. On December 11 , 2003, the Commission issued an order accepting the tariff
sheets, effective January 1 , 2004.
Twenty-Sixth Revised Sheet No.FIfteenth Revised Sheet No.
Fourth Revised Sheet No. 5-C Thirteenth Revised Sheet No. 8.
Thirteenth Revised Sheet No.
Docket No. RPO4-86-D00
On November 26 , 2003, Northwest filed two Rate Schedule TF-1 non--conforming service
agreements containing contract-specific operational flow order provisions, and the following
tariff sheet to add these agreements to the list of non-conforming service agreements in
Northwest's tariff. On December 12, 2003, the Commission issued an order accepting
Exhibit No.
Case No. (NT -O4-
Intermountain Gas Company
Page 4 of 26
All-Holders
December 18, 2003
Page 4 of 4
these two non-conforming service agreements. Concurrently, the Commission accepted
the filed tariff sheet, effective December 27,2003.
Rrst Revised Sheet No. 372
Other Information
If you have questions concerning Northwesfs regulatory issues, please call me or any of
the other individuals listed below:
John Woolf
Gary Kotter
Jan Caldwell
Barbara Odland
Sr. Regulatory Analyst
Manager, Certificates and Tariffs
Manager, Cost of Service and Rate Design
Office Administrator
[phone]
[phone]
[phone]
[phone]
Northwest publishes FERCWatch to provide customers with information on Northwest's
current and pending filings. It may be viewed on Northwesfs Intemet web site at
www.1Iine.williams.comlwebbVebblindex.jsp. You may also view Northwesfs tariff on its
Internet web site. To view FERCWatch, place your mouse on "Customer Info" at the top of
the main portal page and click on FERCWatch. To view the tariff, place your mouse on
lnformational Postings" on the left side of the main portal page and dick on Northwest.
Sincerely,
cr:~OOf
Enclosures
Exhibit No.
Case No.INT-O4-
Intermountain Gas CompanyPage 5 of 26
Northwest ripeline Corporation
FERC Gas Tariff
Tbird Revised Volume No.. 1.
Twenty-S1dh Revised Sheet No. 5
Supededjng
Twenty-F'd'tb. Revised Sheet No.
STATEMENT OF RATES
Effective Rates Applicable to Rate Schedules TF-1, TF-2 and T!-!
(Dollars per Dth)
Currently
Base Effective
Rate Schedule and Tariff Rate Tariff Rate(3)
Type of Rate Minimum Maximum GRI (1)ACA(2)Min :i1num Maximun1
Rate Schedule TF-l (4) (5)
Reservation
(Large Customer)
System-Wide
High Load Factor 00000 27685 00164 00000 27849
Low Load Fac1:or 00000 27685 00102 00000 27787
15 Year Evergreen Exp.
High Load Factor . 00000 39439 00164 00000 39603
Low Load Factor 00000 39439 00102 00000 39541
25 Year Evergreen Exp.
High Load Factor 00000 37790 00164,00000 37954
Low Load Factor 00000 37790 00102 00000 37892
Volumetric
(Large CU5tOIller). 01225 03000 00400 00210 01435 - 03610
(Small Customer)(6)01225 58521 00600 00210 01435 59331
Scheduled OVerrun 01225 30760 00400 00210 01435 31370
Rate Schedule TF-(4) (5)
Reservation 00000 27685
...
00000 27685
Volumetric 01225 03000 01225 . 03000
Scheduled Daily Overrun 01225 30760 01225 30760
Annual Overrun 01225 30760 01225 30760
Rate Schedule '1'I-1
Volumetric (7)01225 30760 00400 00210 01435 31370
Scheduled OVerrun - 01225 30760 00400 00210 01435 31370
by: Lam1 M..Gertsch. Diredor
Issued on: NoveD1ber 26. 2003 EffectM: Jaal1afY ~ 2004
Northwest Pipeline Corporatioa
FERC Gas Tariff
Tbird Revised VobnDe No. 1
Exhibit No.
Case No. INT-O4-
Intermountain Gas Company
Page 6 of 26
Fourth Revised Sheet No.
Sapenediag
Sub Third Revised Sheet No. S-C
STATEMENT OF AATES (Continued)
Effective Rates Applicable to Rate Sche~ules TF-, TF-2 and TI-l (Continued)
(Dollars per Dth)
~ootnotes (Continue~)
(4)All reservation ra~es are daily rates cOltlputed on the basis of 365 days
per year. except that such ra~es for leap years are computed on the
basis of 366 days.
For Rate Schedule TP-the lS-Year and 25-Year Evergreen Expansion
reservation rates apply to Shippers receiving service under Rate
Schedule TF-! Evergreen Expansion service agreements. orhe System-Wide
reservation rates apply ~o Shippers receiv~g service under all other
Rate Schedule TF-l service agreements. The Rate Schedule TF-l (Large
Customer) volumetric rateS apply to all Rate Schedule TF-1 service
agreements, including ~he Evergreen Expansion service agreements.
For Rate Schedule TF-l, the 15-Year and 25-Year Evergreen Expansion
maximum base tariff reservation rates are comprised of $0.38933 and$0.37284 for transmission costs and $0.00506 and $0.00506 for storage
costs, respectively. The System-Wide maximum base tariff reservation
rates for Rate Schedule TF-l and the maximum base tariff reservation
rates for Rate Schedule 1'F-2 are comprised of $0.21120 for traJ:1smission
costs and $0 - 00565 for storage costs-
For Rate Schedule TF-I (Large CUStomer). the maximum base tariffvolumetric rates awlicable to Shippers receiving service under Rate
Schedule TF-l EVergreen Expansion service agreements are comprised of
$0.02969 for transmission costs and $0.00031 for storage costs. The
maximum base tariff volumetric rates for all other services under Rate
Schedule TF-l (Large CUstomer) and for services under Rate Schedule TF~2
are comprised of $0.02966 for transmission costs and $0.00034 forstorage costs.
(5 J Rates for Rate Schedules TF-l and TF-2 are also applicable to capacityrelease service- (Section 22 of the General Terms and Condit~ons
describes how bids for capacity release will be evaluated.) The
reservation rate is the comparable volumetric bid reservation charge
applicable to Replacement Shippers bidding for capacity released on a
- one-part volumetric bid basis.
Issued by: I..an:n M.Ger1sch, Director
hsued on: November 26. 2003 Effective: January 1. 2004
Northwest PIpeline Corporation
FERC Gas Tariff
Third Revised Vo1nme No.
Exhibit No.
Case No. INT-O4-
Intermountain Gas Company
Page 7 of 26
Original Sheet No. S-D
STATEMENT OF RATES (Continued)
Effec~ive Rates ~pplicable to Rate Schedules TF-l, TF-2 and TI-l (Continued)
(Dollars per Dth)
~ootnotes (Continued)
(6)Rate Schedule TF-l (Small Customer) one-part volumetric rate is based
upon a 50ft load factor, and the ma.ximum base tariff rate is comprised of$0.57353 for transmission costs and $0.01168 for storage costs-
Transporter will not transport gas for delive%y for Small Customers
subject to this Rate Schedule TF-l under any interruptible Service
Agreement or under any capacity release Service Agreement unless such
Small Cust:omer has exhausted its daily levels of firm service
entitlement for that day.
(7)Rate Schedule TI-l maximum base tariff volumetric rate is comprised of
$0.30159 for transmission costs and $0.00601 for storage costs.
(8)Applicable to Rate Schedules 1'F-l, TF-2 and TI-1 pursuant to Section15.5 of the General Terms and Conditions.
Issued by: I.ann M.Gertsch, Director
Issued on: August 28., 2003
FDed to CODIpIy with order of the Fedenl Energy ReguhllOry Cnm'1Ji~oo.
Doclcet No. CPO2-4-002 . Issued May 7. 2003
Effective-. Octnber 1, 2003
103 FERC '161.149 (2003)
Nortbwest Pipeline Corporation
FERC Gas Taritf
Third Reme.i Volume No. 1
Exhibit No.
Case No. INT-O4-
Intermountain Gas Company
Page 8 of 26
Thirieenth Revised Sheet No. 7'
SupersOOiugTwelfth Revised Sheet No. 7
STATEMENT OF RATES (Continued)
Effective Rates Applicable to Rate Schedules SGS-2F and SGS-
(Dollars per Dth)
Rate Schedule and
'type of Rate
CUrrently Effective
Tariff Rate (1)Minimum Maximum
Rate Schedule SGS-2F (2)
Demand Charge
Capacity Demand Charge 00000
00000
01685
00061
Volumetric Bid Rates
Withdrawal Charge
Storage Charge
00000
0 - 00000
01685
00061
Rate Schedule SGS-2I
Volumetric 00000 00134
Footnotes
(1)Shippers receiving service under these rate schedules are required to
furnish fuel reimbursement in-kind at the rates specified On Sheet No.14 .
(2)Rates are daily rates c~uted On the basis of 365 days per year, except
that rates for leap years are computed on the basis of 366 days-
Rates are also applicable to capacity release service. (Section 22 ofthe General Terms and Conditions describes how bids for capacity release
will. be evaluated.The Withdrawal Charge and Storage Charge are
applicable to Replacement Shippers bidding for capacity rele~sed on a
one-part volumetric bid basis.
Issued by; Laren M.Gertsch, DiRctor
Issued 00. Nowmber 26, 2003
Effective: .J8DWUJ' 42004
Northwest Pipeline cOrpo...won
FERC Gas Tariff
Third Rewised Volome No.
Exhibit No.
Case No. INT-O4-
Intermountain Gas Company
Page 9 of 26
Fd'teeuth RevN!d Sheet No. 8
SupenediDg
Fourteenth Rmsed Sheet No. 8
STATEMENT OF RATES (Continued)
Effective Rates Applicable to Rate Schedule LS-
(Dollars per Dth)
Type of Rate
Currently Effective
Tariff Rate (1)
Demand Charge ( 2 )Capacity Charge (2)02593
00331
Liquefaction
Vaporization 55685
03030
h:-ootnotes
(1)Shippers receiving set:Vice under this rate schedule are required to
furnish fuel reimbursement in-kind at the rate specified on Sheet No.
14.
(2 )Rates are daily rates compuced on the basis of 365 days per year. except
that rates for leap years are camputed on the basis of 366 days.
Issued by: L3ren M.Gensch, Director
Issued OD: NoveJDber 20, 2003 Effective: January 1, 2004
Northwest PipeIiue Corporation
FERC Gas Tariff
Third Revised Vo1ume No. 1
Exhibit No.
Case No. INT-O4-
Intermountain Gas Company
Page 10 of 26
'l'birteeatb. Revised Sheet No.. 8.1
Supersediug
Twelfth ReW;ed Shed: No.. 8.1
STA't'EMENT OF RATES (Continued)
Effective ~tes Appl~cable to Rate Schedules LS-2F and LS-2I
(Dollars per Dth)
Rate Schedule and'
Type of Rate
CUrrently Effec~i
Tar~ff Rate (1)w.nimum Maximum
Rate Schedule LS-2F (3)
Demand Charge (2)
Capacity Demand- Charge (2)00000 a - 02593
00000 0 . 00331
o. 00000 O. 02593
o. 00000 0 . 00331
55685 55685
03030 03030
Volumetric Bid Rates
vaporization Demand-Related Charge (2)
Storage Capacity Charge (2)
Liquefaction
Vaporiza tion
Rate Schedule LS-2r
Volumetric:0 - 00161 00826
lFootnot:es
(1)Shippers receiving service under these rate schedules are required to
furnish fuel rei1l1bursement in-kind at the rates speeif.ied on Sheet No.l4.
(2)Rates are daily rates Computed on the basis of 365 days per year, except
tha~ rates for leap years are computed on the basis of 366 days.
(3 )Rates are also applicable to capacity release service. (Section 22 ofthe General Terms and Conditions describes how bids for capacity release
will be evaluated.The Vaporization Demand-Related Charge and Storage
capaci ty Charge are applicable to Replacement Shippers bidding for
capaci ty released on a one-part volumetric bid basis.
Issued by: Laren M..~ Director~ed on: November 26,. 2003 Effectige.\ January 1. 2004
Exhibit No.
Case No. INT-O4-
Intermountain Gas Company
Page 11 of 26
'1I1.11f11.""I,ilamS
GAS PIPEUNE
295 O1lpetr Wj'j (84108)
O. Box 58900
Salt Lake Oty, ur 84158..0900
Phone: (801) :;8+7117FAX: [phone]
February 27, 2004
Ms. Magalie R. Salas, Secretary
Federal Energy Regulatory Commission
888 First Street, N.
Washington, D.C. 20426
Re:Northwest Pipeline Corporation
Docket No. RP04-
Dear Ms. Salas:
Pursuant to Part 154 of the regulations of the Federal Energy Regulatory Commission
(Commission), Northwest Pipeline Corporation (Northwest) tenders for filing and
acceptance the following tariff sheets as part of its FERC Gas Tariff (Tariff):
Third Revised Volume No.
Twenty-Second Revised Sheet No. 14
Original Volume No.
Thirty-Seventh Revised Sheet No. 2.
Purpose
The purpose of this filing is to (1) propose a decrease from 1.58% to 1.34% in the fuel
reimbursement factor (Factor) applicable to Northwests transportation service rate
schedules 1 (2) to propose a decrease from 0.83% to 0.80% in the Evergreen Expansion
incremental surcharge Factor applicable to certain service under Rate Schedule TF-1 for
shippers under Evergreen Expansion service agreements, (3) propose an increase from
1.42% to 4.97% in the Factor applicable to Northwest's Plymouth LNG Facility storage
- service rate schedules,2 and (4) propose no change in the current 0% Factor applicable to
Northwesfs Jackson Prairie storage project service rate schedules.3 The Factors allow
Northwest to be reimbursed in-kind for the fuel used during the transmission and storage of
gas and for the volumes of gas lost and unaccounted-for (L&U) that occur as a normal part
of operating the transmission system.
1 Rate Schedules TF-, TF-, TI-1, DEX-1 and all applicable transportation service rate schedules
contained in Original Volume No.2 of Northwesfs Tariff.
2 Rate Schedules LS-1 , LS-2F and LS-21.
- --,
"'i 3 Rate Schedules SGS-2F and SGS-21.
Exhibit No.
Case No. INT-O4-
Intermountain Gas Company
Page 12 of 26
,.-
Ms. Magalie R. Salas
February 27, 2004
Page 2 of 5
'---.-/
Statement of Nature, Reasons and Basis for the Filing
Northwest is submitting this filing to comply with Section 14.12 of the General Terms and
Conditions contained in Northwest's Tariff which requires the Factor for the transportation
rate schedules to be determined semi-annually to become effective on April 1 and October1 of each year, and requires the Factor for the storage rate schedules to be determined
annually to become effective April 1 of each year.
Exhibits A and 8 show the data and formulas used to derive the proposed Factors.
Transportation Rate Schedules. Northwest proposes a Factor of 1.34% to be applicableduring the upcoming April through September (Summer) period for transportation service
Rate Schedules TF-1, TF-, TI-, DEX-1 and all applicable transportation service rate
schedules contained in Original Volume No.2 of Northwest's Tariff.
'-..J
Northwest's currently effective Factor applicable to transportation service is 1.58%.Northwest's semi-annual fuel filing procedures are designed to more closely match
seasonal differences in fuel usage with the responsible shippers. Under such procedures,
the October through March (Winter) Factor normally should be expected to be lower than
the Summer period Factor. Northwesfs displacement dependent system tends to operate
more efficiently when total system market demands are greatest, resulting in lower
compressor fuel usage per unit of throughput during the Winter period than during the
Summer period.
However, the true-up adjustment can have a significant impact on the Factor. The
projections used to derive the current 1.58% F=actor included the recovery of a true-up
adjustment of 506,770 Dth. The projections used to derive the proposed 1.34% Factorinclude the refund of a true-up adjustment of 953j261 Dth. If these true-up adjustmentswere excluded in the calculation of the Factor, the current Factor of 1.58% would havebeen 1.45% and the proposed Factor of 1.34% would have been 1.62%. This fits the
pattern of the Summer Factor being higher than the Winter Factor.
The L&U remains a relatively small component of the Factor. Including the true-upadjustments, the L&U component of the 1.34% Factor is 0.10%. Using historical averages,
the forecast for L&U is 940 949 Dth before the true-up adjustment.
Although Northwest's Tariff does not dictate any specific forecast methodology, Northwest
typically bases its projected transportation volumes, fuel usage and L&U on historical
averages. Northwest has continued to use that methodology in making the current
projections.
Evergreen Expansion Incremental Surcharge On August 28. 2003 in Docket No. RP03-
597-000, Northwest filed, among other things, an initial incremental fuel surcharge of
83% in conjunction with the anticipated completion of the Evergreen Expansion project.
This surcharge was accepted in a letter order dated September 30, 2003, effective
Exhibit No.
Case No. INT-O4-
Intermountain Gas Company
Page 13 of 26
...--
Ms. Magalie R. Salas
February 27, 2004
Page 3 of 5
---
October 1, 2003. The initial incremental fuel surcharge of 0.83% equals the difference
between the initial Evergreen shipper incremental fuel rate of 2.04% and the 1.21% fuel
usage component of the system-wide Factor for Rate Schedule TF-1 that became effective
October 1 , 2003. The derivation of the initial Evergreen Expansion incremental fuel rate of
04% was set forth in Exhibit P of Northwest's January 8 2003 amended Evergreen
Expansion certificate application in Docket No. CP02-002.
Although the Evergreen Expansion went into effect on October 1 , 2003, Northwest only has
two months of accounting data concerning the Evergreen Expansion in 2003 since
Northwest books its data on a month lag. The accounting data from November and
December 2003 (which is activity that occurred during October and November 2003), is not
sufficient experience to justify altering the originally forecasted 2.04% Evergreen
Expansion incremental fuel rate. Further, the true-up adjustment for the Ev~rgreen
Expansion incremental fuel component, as shown on page 5 of Exhibit B, is only 1 268 Dth
for the last two accounting months of the year.
'-...-/
Due to the de minimis amount of the true-up adjustment and the lack of sufficient
experience to forecast a different Evergreen Expansion incremental fuel rate, Northwest
proposes to continue to use the initial projected Evergreen Expansion incremental fuel rate
of 2.04% for determining the incremental fuel surcharge applicable to Evergreen shippers.
Thus, Northwest proposes to revise the incremental fuel surcharge from 0.83% to 0.80%
effective April 1 . 2004. The 0.80% equals the difference between the initial ,Evergreen
shipper incremental fuel rate of 2.04% and the 1.24% fuel usage component of the system-
wide Factor for Rate Schedule TF-1 that is proposed to become effective April 1 . 2004.
Northwest seeks waiver of Section 14.12(h) of the General Terms and Conditions of its
Tariff to allow Northwest to defer the recovery of the 1 268 Dth true-up adjustment
discussed above until it is reflected in the incremental fuel surcharge that will become
effective October 1 , 2004.
Plymouth LNG FaciliW StoraQe Service Rate Schedules. Northwest proposes an increase
from 1.42% to 4.97% for the Factor applicable to Rate Schedules LS-, LS-2F and LS-
which pertain to the Plymouth LNG Facility storage service. This increase is primarily due
to a large underrecovery of 37,363 Dth in the proposed true-up adjustment versus a small
overrecovery of 2,974 Dth in the true-up adjustment used to calculate the current 1.42%
Factor. Fuel usage and injection (liquefaction) volumes at the Plymouth LNG Facility are
relatively small so any true-up adjustment can potentially cause a large swing in the Factor.
During 2003, fuel usage at the Plymouth LNG Facility was greater than fuel usage during
2002 in part because the Plymouth LNG Facility experienced more liquefaction than the
previous year, requiring more fuel gas to heat the gas stream to remove water from the gas
prior to liquefaction. Further, 16,495 Dth of volumes used to derime the cold box prior to
liquefaction were booked in April 2003 to the Plymouth LNG Facility fuel usage account.
Since no derime volumes were booked to the Plymouth LNG Facility fuel usage account in
2002. including these volumes in 2003 has a material impact on the Factor applicable to
Plymouth LNG Facility storage service rate schedules.
Exhibit No.
Case No. INT-O4-
Intermountain Gas Company
Page 14 of 26
,.---
Ms. Magalie R. Salas
February 27 2004
Page 4 of 5
, "-.-/
Rate Schedules SGS-2F and SGS-21.The traditional methodology for deriving the Factor
for Rate Schedules SGS-2F and SGS-21 results in a very small Factor of 0.05%. The
projected fuel usage of 40,555 Dth is largely offset by a true-up adjustment of 29,455 Dth
resulting in projected net fuel usage of 11 100 Dth. Northwest proposes to continue to
keep the Factor for Rate Schedules SGS-2F and SGS-21 at 0% due to the de minimis
nature of the calculated Factor. Northwest requests waiver of the procedure set forth
Section 14.12 (g) of the General Terms and Conditions of its Tariff to allow the Factor to
remain at 0%.
Northwest sought similar waivers in the February 29, 2003 and March 1 , 2002 fuel filings
that went into effect April 1 , 2003 and April 1, 2002, respectively. Pursuant to an order
dated March 28, 2003 in Docket No. RP03-272-0004 and a letter order issued March 29,
2002 in Docket No. RP02-169-000, Northwest was granted its requests for a waiver of its
Tariff to allow the Factor to be 0% effective April 1, 2003 and April 1 , 2002, respectively. In
an order dated May 23, 2002, the Commission clarified that Northwest must flow through
the remaining Jackson Prairie overrecovery in its future annual fuel filiogs.5 This
requirement was repeated in the Commission s order dated March 28, 2003. The currently
remaining overrecovery of 29,455 Dth is projected to flow through to customers in the
Summer period.
'---./
Pending Filings
On October 3 2003 in Docket No. RP03-597-o01 , Northwest made a compliance Tariff
filing including Substitute Twenty-First Revised Sheet No. 14 which was filed to correct a
typographical error for the Factor applicable to Rate Schedules LS-, LS-2F and LS-21.
Northwest requested an effective date of October 1 , 2003 for this tariff sheet and the filing
is currently pending before the Commission.
Effective Date and Waiver Request
Northwest hereby moves that the proposed tariff sheets be made effective April 1, 2004, or
at the end of any suspension period which may be imposed by the Commission.
Northwest requests that the Commission grant any waivers it may deem necessary for the
acceptance of this filing, including waivers of the procedures set forth in Sections 14.12(g)
and 14.12(h) of the General Terms and Conditions of Northwesfs Tariff as discussed
above.
--./
4 102 FERC ~ 61,342 (2003)-
5 99 FERC 11 61,218 (2002).
Exhibit No.
Case No. INT -O4-
Intermountain Gas Company
Page 15 of 26
",.--'
Ms. Magalie R. Salas
February 27, 2004
Page 5 of 5
Procedural Matters
Pursuant to the applicable provisions in Section 154 of the Commission s regulationsNorthwest submits the following materials in connection with this filing:
. The proposed tariff sheets listed above.
. A red lined version of the proposed tariff sheets.
. A form of notice suitable for publication in the Federal Register.
. A diskette containing the Volume No.1 proposed tariff sheet in electronic form, and
a separate diskette containing the form of FederaJ Register notice.
Service and Communications
An original and five copies of this filing are being provided to the Commission. Copies ofthis filing have been served upon Northwesfs customers and upon interested state
regulatory commissions.
All communications regarding this filing should be served upon:
,---
Gary K. Kotter
Manager, Certificates and T aritts
[phone]
Northwest Pipeline Corporation
O. Box 58900
Salt lake City, Utah 84158-0900
Steven W. Snarr
General Counsel
[phone]
Northwest Pipeline Corporation
O. Box 58900
Salt Lake City, Utah 84158-0900
To the best of my knowledge and belief, the tariff sheets are true and correct and the
Volume No.1 tariff sheet contains the same information as the diskette.
Respectfully submitted
NORTHWEST PIPEUNE CORPORATION
6.,~
Gary K. Kotter
Manager, Certificates and Tariffs
Enclosures
0404FuelLetter .doc
UNITED STATES OF AMERICA
FEDERAL ENERGY REGULATORY COMMISSION
Exhibit No, 3
Case No. INT-O4-
Intermountain Gas Company
Page 16 of 26
'--'"
Northwest Pipeline Corporation Docket No. RP04-
NOTICE OF PROPOSED CHANGES IN FERC GAS TARIFF
Take notice that on February 27, 2004, Northwest Pipeline Corporation (Northwest)
tendered for filing as part of its FERC Gas Tariff the following tariff sheets, to be
effective April 1, 2004.
Third Revised Volume No.
Twenty-Second Revised Sheet No. 14
Original Volume No.
Thirty-Seventh Revised Sheet No. 2.
Northwest states that the purpose of this filing is to (1) propose a decrease from 1.58%
to 1.34% in the fuel reimbursement factor (Factor) applicable to Northwest'
transportation service rate schedules, (2) to propose a decrease from 0.83% to 0.80%in the Evergreen Expansion incremental surcharge Factor applicable to certain service
under Rate Schedule TF-1 for shippers under Evergreen Expansion service
agreements, (3) propose an increase from 1.42% to 4.97% in the Factor applicable toNorthwest's Plymouth LNG Facility storage service rate schedules, and (4) propose nochange in the current 0% Factor applicable to Northwest1s Jackson Prairie storage
project service rate schedules. Northwest states that the Factors allow Northwest to be
reimbursed in-kind for the fuel used during the transmission and storage of gas and for
the volumes of gas lost and unaccounted-for that occur as a normal part of operating
the transmission system.
Northwest states that a copy of this filing has been served upon Northwest1s customersand interested state regulatory commissions.
Any person desiring to be heard or to protest said filing should file a motion to intervene
or a protest with the Federal Energy Regulatory Commission I 888 First Street, N.Washington, D.C. 20426, in accordance with Sections 385.214 or 385.211 of theCommissions Rules and Regulations. All such motions or protests must be filed in
accordance with Section 154.210 of the Commission s Regulations. Protests will be
considered by the Commission in determining the appropriate action to be taken, but
will not serve to make protestants parties to the proceedings. Any person wishing to
become a party must file a motion to intervene. This filing is available for review at the
Commission in the Public Reference Room or may be viewed on the Commission
website at httP://www.ferc.aov using the II FERRrS" link. Enter the docket number
excluding the last three digits in the docket number field to access the document. ForAssistance, call [phone] or for TTY, [phone]. Comments, protests and
interventions may be filed electronically via the Internet in lieu of paper. TheCommission strongly encourages electronic filings. See, 18 CFR 385.2001 (a)(1 )(iii)and the instructions on the Commission s web site under the "Filing- link.
,./
Magalie R. Salas
Secretary
Northwest Pipe6ne Corporatioo
FERC Gas Tariff
Third Revised Volume No.1
Exhibit No.
Case No. INT-O4-
Intermountain- Gas Company
Page 17 of 26
Twenty&condRerised Sheet No. 14
SupeBedingSub Twen .First Revised Sheet No. 14
STATEMENT OF Pt1E:L USE IlliQUIR.EMENTS FACTORS
FOR REIMBURSEMENT OF FUEL USE
Applicable to Transportation Service Rendered Under
te Schedules Contained in this Tariff. Third Revised Volume No.
The rates set forth on Sheet Nos. 5. 6, 7, 8 and 8.1 are exclusive offuel use requirements. Shipper shall reimburse Transporter in-kind for itsfuel use requirements in accordance with Section 14 of the General Terms andonditions contained herein.
The fuel use reimbursement furnished by Shippers shall be as follows for
he applicable ~te Schedules included in this Tariff:
~te Schedule TF-l
Rate Schedule TF-l - EvergreenIncremental Surcharge (1)
Rate Schedule TF-2
Rate Schedule TI-
Rate Schedule SGS-2F
Rate Schedule SGS-
Rate Schedule LS-
Rate Schedule LS-2F
Rate Schedule LS-
Rate Schedule DEX-l
1.34%
Expansion
80%
1.34%
1.34%
00%
00%
97%
97%
97%
34%
..J The fuel use factors set forth above shall be calculated and adjusted as
lained in Section 14 of the General Terms and Conditions. Fueleimbursement quantities to be supplied by Shippers to Transporter shall beete~ed by applying the factors Set forth above to the quantity of gas
ominated for receipt by Transporter from Shipper
for transportation. forinjection into storage, or for deferred exchange , as applicable.
ootnote
(1)In addition to the Rate Schedule TF-l fuel use requirements factor, theEvergreen Expansion Incremental Surcharge will apply to the quantity of
gas nominated for receipt at the Sumas, SIPI or Pacific Pool receipt
points under Evergreen Expansion service agreem~ts.
Issued by: Lareo M.Gertscb. Director
Issued on; February 27. 1004
Effective: April 1, 2004
Exhibit No.
Case No. INT-O4-
Intermountain Gas Company
Page 18 of 26
Gas Transmission Northwest Corporation
FERC Gas Tariff
Third Revised Volume No, i-First Revised Sheet No.
Superseding
Original Sheet No.
STATEMENT OF EFFECTIVE RATES AND CHARGES FOR
TRANSPORTATION OF NATURAL GAS
Rate Schedules FTS-l and LFS-
RESERVATION DELIVERY (c)
(Dth-MILE)
FUEL (d)
(Oth)
MILEAGE (a)
(Oth/MILE)
NON-MILEAGE (b)
(Dth)
MAXIMUM MINIMUM MAXIMUM MINIMUM MAXIMUM MINIMUM MAXIMUM MINIMUM
BASE 011212 000000 884028 000000 000013 000013 0050%0000%
MRRS (e) 0.000227 000000 049280 000000
CES 000227 000000 049280 000000
EXTENS ION CHARGES
MEDFORD
l (f) 0.296969 0,000000 000016 0,000016
2(g) 0.194607 0.000000
(WWP)
000000 0.000000
2(h) 0.090388 0.000000
(Diamond 1)
000000 0.000000
2(h) 0.035477 0,000000
(Diamond 2)
000000 0,000000
COYOTE SPRINGS
3(i) 0.064705 0.00000 000000 o. 000000
OVERRUN CHARGE (j )
SURCHARGES
ACA (k)
GRI (m)
HLF
LLF
0, 002100 002100
050000 0, 000000 004000 000000
0 - 031000 000000 004000 000000
Issued by: John A Roscher, Director of Rates & Regulatory Affairs
Issued on: November 7 , 2003 Effective on: November 1, 2003
Exhibit No.
Case No. INT-O4-
Intermountain Gas Company
Page 19 of 26
For the period of May 1 , 2004. until further notice, a fuel
usage rate of 0028% per Dth/mile will be in effect.
Applicable per Dth/mile rates for the most common paths
are calculated below.
FERC Gas Tariff, First Revised Volume No, 1-
Fuel Use Rates
(Forward haul Service Only)
K\ngs9,,-te:t~:
Moyie Springs 22,000616
Bonner s Ferry 27,000757
Schweitzer 55.001554
Sandpoint 59.001659
Athol 84.002374
Rathdrum 97.002734
Spokane 108,003032
Mica 121,003392
Spangle 134.003757
Rosalia 145.004080
St John 158,004449
Palouse 172,004818
Lacrosse 182,005118
Kosmos Farms 271,007606
Stanfield 277.007766
Stanfield City 282.007917
South Hermiston 289.008115
Coyote Springs 304.008519
Boardman 311.008708
Madras 410,011484
Prineville 426,011950
Redmond 438,012272
Bend 454.012726
South Bend 457,012810
Stearns 469,013137
LaPine 483.013549
Gilchrist 500.014027
Chemult 519.44 014544
Diamond Junction 530.014857
Klamath Falls 599.016774
Medford Extension 599.016778
Tuscarora 609.017074
Malin 612.46 017149
SpokanE!to:
Palouse 63,001786
Stanfield 169,004734
South Hermiston 181.005083
Coyote Springs 195,005487
Boardman 202,005676
Madras 301.87 008452
Prineville 318,008918
Redmond 330.009240
Bend 346,009694
S. Bend 349,009778
Stearns 360,010105
LaPine 375,010517
Gilchrist 392.010995
Chemult 411.011512
Diamond Junction 422,011825
Klamath Falls 490,013742
Medford Extension 490,013745
Tuscarora 501.014042
Malin 504,014117
St~nfieldto:
South Hermiston
Coyote Springs
Boardman
Madras
Prineville
Redmond
Bend
South Bend
Stearns
LaPine
Gilchrist
Chemult
Diamond Junction
Klamath Falls
Medford Extension
Tuscarora
Malin
12.46
26.
33.
132.
149.43
160.
177,
180.
191.
206.
223.
242.
253.
321.69
321.
332.43
335.
Exhibit No.
Case No. INT-04-
Intermountain Gas Company
Page 20 of 26
000349
000753
000942
003718
004184
004506
004960
005044
005371
005783
006261
006778
007090
009007
009011
009308
009383
((
TransCanada
" ,
In business to cf,filiver
TransCanada Home i' BC System
Effective Rates and Charges for 2004
Commodity Rates at
Effective Heating Value Forecast of 38.00 MJ
FS-Firm Service Demand Rate
(cents/GJ/Month/Km)
FS-1 Firm Service Commodity Rate (cents/GJ/km)
IS-Interruptible Service Commodity Rate
(cents/GJ/km) *
*The IS-1 Interruptible Service Commodity Rate is calculated by taking the
FS-1 Firm Service Demand Rate at 90% load factor and adding the FS-
Firm Service Commodity Rate.
Toll Rate
1.083436382
002072979
041650563
Rates Effective January 1, 2004
Expressed in Canadian Dollars and Cents
(MMBtu units expressed in US Dollars)
Firm Service (FS-1)
MMBtu
(Cdn (US
cents)cents)
6.43
MMBtu
(Cdn (US
cents)cents)
Demand Rate
Commodity Rate
Total FS-l Rate (Kingsgate)
Interruptible Service (15-1)
Interruptible Commodity Rate
Total IS-1 Rate (Kingsgate)
1. Tolls are payable in Canadian dollars and
GJ units are used for billing puposes.
2. Posted commodity rates are based on Effective Heating Value
Forecast or 38.0 GJ/E3
3. Conversion factors $Cdn to $U.S. divide by 1,30 (subject to change)
cents/GJ to cents/MMBtu multiply by 1.055056.
4. The 2003 average fuel ratio to Kingsgate is forecast at 0.9%.5. All rates are based on 100% load factor utilization except for
interruptible which is at a 90% load factor,
6. All rates do not include a provision for GST.
Exhibit No.
Case No. INT-O4-
Intermountain Gas Company
Page 21 of 26
Q:~ ~~~~~~;da
TransCanada Home f BC System
Current Fuel Rates & Heating Values
Fuel Rate Effective May 1 , 2004
Fuel Rate and MJ value on TransCanada s B.C. System for May, 2004
Please be advised that effective May 1 , 2004 at 08:00 the fuel rate on
TransCanada s B.C. System will change to 0.8% and the heat content posted
at Kingsgate will remain at 37.90 MJ.
If you have any questions please contact Lisa Draudson at 403.920.5593 or
Gordon Betts at 920-6834.
Path Kilometer % Fuel Rate
Post Per GJ
Alberta/B.C. Interconnect to:
Sparwood Sales Tap 04452255
Byron Creek Sales Tap 18.08529584
Fernie Sales Tap 53.2516696
Elko Sales Tap 69.32665495
Galloway Sales Tap 85.3983597
Cranbrook Sales Tap 99.0.46444054
Yahk Sales Tap 156.4 73298184
East Kootenay Exchange 162.4 76110135
Kingsgate Meter Station 170.
East Kootenay to:
Kingsgate Meter Station 038898
For the period of May 1 , 2004, until further notice, a fuel rate of 0.0046866%
per GJ/km will be in effect. Applicable per GJ/km rates for the most common
paths are provided above.
Exhibit No.
Case No. INT-04-
Intermountain Gas Company
Page 22 of 26
Exhibit No.
Case No. INT-O4-
Intermountain Gas Company
Page 23 of 26
NOVA Gas Transmission Ltd.
Page 1
Table of Rates, Tolls and Charges
TABLE OF RATES TOLLS AND CHARGES
Service Rates, Tolls and Charges
Rate Schedule FT-Refer to Attachment "I" for the applicable FT-R Demand Rate per month and
Surcharge for each Receipt Point
Average Finn Service Receipt Price (AFSRP)$188.41/103
Rate Schedule FT-Refer to Attachment "I" for the applicable FT-RN Demand Rate per month and
Surcharge for each Receipt Point
Rate Schedule FT -FT-D Demand Rate per month $188.4l!10J
Rate Schedule STFT STFT Bid Price
Minimum bid of 135% of FT-D Demand Rate
Rate Schedule FT-FT-A Commodity Rate $0.57/103
Rate Schedule FT-Refer to Attachment "2" for the applicable FT -P Demand Rate per month.
Rate Schedule LRS Contract Tenn Effective LRS Rate ($/1O3 /dav)
5 years
10 years
15 years
20 years
Rate Schedule LRS-LRS-2 Rate per month $50 000
Rate Schedule LRS-LRS-3 Demand Rate per month $188.71/1O3
10, Rate Schedule IT-Refer to Attachment" I" for the applicable IT-R Rate and Surcharge for each
Receipt Point
II. Rate Schedule IT-IT-D Rate $6.81/1O
12, Rate Schedule FCS The FCS Charge is detennined in accordance with Attachment "1" to the
applicable Schedule of Service
13, Rate Schedule OS Schedule No,Charge
2003-00452-333./ month
2003-03435-899,/ month
2003-03734- 7 698./ month
2003-058091-568./ month
2003-03624-27./ month
2003-07178-150./ month
2003-07179-391.00 / month
2003-07113-/ month
2003-05812-118./ month
2003-05809-163./ month
2003-03747-707./ month
14, Rate Schedule CO2 Tier Rate $/10
532.41
425,
283,
TARIFF Effective Date: January 1 , 2004 as per EUB Decision 2003-105
Exhibit No.
Case No. INT-O4-
Intermountain Gas Company
Page 24 of 26
Summary of 2004 Interim Station Prices:
($f10 fmonth except IT which is $/10
Firm Service Delivery:188.41
Average Receipt Price:188.41
Receipt Price Floor:101.
Receipt Price Ceiling:274.
Interruptible Delivery:
PremiumfDiscount:105%100%95%110%115%
I-I-I-I-
FT-FT-PRICE PRICE
PRICE 1 PRICE greater Year Non-
Station to ~3 -to ~5 -than 5 -Renewable IT-Project
Number Station Name Year Term Year Term Year Term Firm PRICE Area
Al~~Page 1 of 1
Questar Pipeline Company
FERC Gas Tariff
First Revi~ed Volume No.
Exhibit No.
Case No. INT-O4-
Intermountain Gas Company
Page 25 of 26
Sixteenth Revised Sheet No.
Superseding
Sub. Fifteenth Revised Sheet No.
STA'lEKEN7 OF RATES
8.,;;",R.:ItQ Schedule/
af o,;orqc:
("')
All.nual~irr
(1:11
Cu.rrcnUy
Ch:u:9"
AcI1u:stment.'2./(e)
&ttective
Rate
(4)
1'QJaJICii ftOP.AGI:
Haal:hly Jt".."rv"t~on o."":g9~i-
MinilllUib
Usage Ch~ge
Injection
wi th4J:awal
2. a137S
O. COOOo
2. 81375/Dth
OOOOO/Pth
038'12
038'12
O38121Dth
O3812/Dtb
c:r.u BUm STOP.AGI:
ru... Sbuall'" s~ - I'SS
Mgnthly ~e~ervation Charge
Do,liv"....,bHity
Kaxilmlm
MinilllUm
Capacity
Maximum
Minimum.
U....g.. o,;;I;cg~
Injel:t.ioD
Wi tI1d;cawool
Auth....i.,$d Overrun Ch",rge
Hax1aUIII.
Miniawa
h1:azrupUbl. st:_~. - US
U3",ge Char\Je
Inventory 1/
Maximum
"'inim1,\111
hj 8c;t ion
W1th~aw~1
85338
00000 2. 85338/Dth
OOoOO/Dth
023'19
00000 o. O:23"/Dtb
O. OOOOO/Dtb
010
01 '1S1
00210 o. 012S9/Dth
OnU/nth
30315
01 '1&1
00210
00210 30S25/Dt.h
01.991/Dth
O. OS~Z'1
00000
01049
01781
00210
O. 05927/Dt.h
O. OOooo/D'th
0125'/Dth
O17SllPth
O~OWIL Wr.tllm:n:rc ~J:$!1,/Pe~kia9 Sta;C;;lg8 service - fKS
Maximum.
Minimum.Fi~ stora\Je Service - FSS
lti x iInwD
MiniMumst~ v..~ a...q... ~iaab1c
Peaking Storage Service - PKS:
In;lectioll
iiithdra\oJal
Clay B",sin Storage Serv~ee - FSS:Injection
wi thdraw~l
40890
00000 40090/Dt:h
OOOOO/Dt:h
S'J068
00000
b v.,l_uic Re~_.6. 1./
5706B/DtIl
OOOOO/Dt.1I
03872
039'12.03B72/t1t:h
o. 038'12/Dt.h
01049
01781
O. 00210 O12:i~/Dt:h
O1791/Dtb
PAlUt MID I.our slUNJ:a: - rAt.!
Daily Charge
KaxiIDUIII
Minimum
Delivery Charge
30315
00000
028JO 00210
30315/Dth
O. OOOOO/nt:h
o. 03 04 0/IJ\:h
- 2.0\ (0.2' Ut.ilit:y ;;InQ 1.8\ compressor tuel) lor Rate Schedule PALl
Issued by: A. K. Allred, President and CEO
Issued on: August 13, 2003 Etfective on: Octobe~ 1, 2003
Exhibit No.
Case No. INT-O4-
Intermountain Gas Company
Page 26 of 26
QueBt~ Pipeline company
FERC Gas Tariff
Ct. -~... -g",....
...~
rt !If,.,
Tenth Revised Sheet No. 6A
Superseding
!C:!.."'...+ 1If... j:;1l
FOOTNOTES
.1fShipper my request service in exceu of its ~D end Questar IllaY ~rovide the service if
capacity ia aV9Heble.
YAppl ied to the average IIIDlIthly uorking gas balence.
lIReleased capacity my be sold at B vohlllctric rate. Shippers releesing capacity on a
volumetric basis must specify a rate between the maximum and miniMUm volUQatric rete stated on this
Statement of ~ates and notify Questa~ of the criteria by which bids era to be evaluated.
!/Storage usage dhargos ere applicable to storage services that are released at e volumetric
rate and ",it l be billed to the replaCMlent shipper according to i 18.2 of the General Terms and
Conditions of Part 1 of this tariff.
~he annual cIIar'!;lt! adjustlllent (AcA) as. spaefffed by tf1e Cannission will be billed accordh1Q
to ~S 4(f) and 3(d) of Rate Schedule FSS and IS5. regpectfvety, and i 11 of the Ceoeral Tenns ahd
Conditions of ~art 1 of this ~ariff.
NOTE; The IIIOntl\ly ratas stated on Questar's Statelllent of RIItes may be converted to a dailyratt! by .ul tiplying the monthly base tariff rate times the number of 8Onths in the rate period and
dividing the result by tht! ~r of days in the rate period. The result is r~ to the fOUrthdeci8IBl place.
IS5ued B1'=
Issued on;
K. Allrecl, Executive VP and COO
February 19, 2003 Effective; Apri1 " 2003
EXIllBIT NOS. 4-
CASE NO. INT-O4-
INTERMOUNTAIN GAS COMPANY
(11 pages)
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Exhibit No.1 0
Case No. INT-O4-
Intermountain Gas Company
Page 1 of
INTERMOUNTAIN GAS COMPANY
Proposed Temporary Surcharges (Credits) . Variable Costs
Description
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Account 1860 Amounts Which Apply to RS., RS-, GS., and L V-1 :
Account 1860 Variable Costs (1)
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268 262,707
$ (0.00409)
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1
EXECUTIVE OFFICES
INTERMOUNTAIN GAS COMPANY
555 SOUTH COLE ROAD. P.O. BOX 7608 . BOISE, IDAHO 83707 . [phone] . FAX: [phone]
NEWS RELEASE Contact: Mike Huntington
Vice President
Marketing & External Affairs
[phone]May 5, 2004
TODAY, INTERMOUNTAIN GAS COMPANY ("INTERMOUNTAIN ) FILED ITS ANNUAL PURCHASED GAS COST ADJUSTMENT
APPLICATION WITH THE IDAHO PUBLIC UTILITIES COMMISSION ("IPUC"). THIS TYPE OF APPLICATION IS FILED EACH YEAR TO ENSURE THAT
THE COSTS THAT INTERMOUNTAIN IS INCURRING ON BEHALF OF ITS CUSTOMERS ARE PROPERLY REFLECTED IN ITS SALES PRICE.
IN ITS APPLICATION, INTERMOUNTAIN REQUESTS PERMISSION TO ADJUST ITS PRICES TO REFLECT THE HIGHER PRICES THAT
INTERMOUNTAIN MUST PAY TO ITS NATURAL GAS SUPPLIERS.
WILLIAM C. "BILL" GLYNN, PRESIDENT OF INTERMOUNTAIN GAS COMPANY, SAID
, "
As OUR CUSTOMERS ALREADY REALIZE
CRUDE OIL AND ITS DERIVATIVE GASOLINE, ARE CURRENTLY UNDER SEVERE PRICE PRESSURE. SIMILARLY NATURAL GAS, AS ANOTHER
ENERGY COMMODITY, IS NOW EXPERIENCING THOSE SAME PRESSURES BECAUSE IDAHO IS NOT ISOLATED FROM THE PRICE INFLUENCES OF
THE NATIONAL MARKET. CONSEQUENTLY, WE ARE FEELING THAT PRICE IMPACT IN OUR ROCKY MOUNTAIN AND CANADIAN SUPPLY BASINS.
WHILE CONSERVATION AND WISE ENERGY USE ARE THE BEST SHORT RANGE SOLUTIONS TO THE SUPPLY DEMAND IMBALANCE THAT DRIVES
THESE PRICE INCREASES, THE BEST LONG TERM SOLUTION IS ALLOWING THE INDUSTRY TO ACCESS THE ENORMOUS AMOUNTS OF NATURAL
GAS THAT ALREADY EXIST ON PUBLIC LANDS. THE INDUSTRY CAN PRUDENTLY DRILL WHERE THE RESOURCES EXIST WITHOUT DAMAGING
THESE LANDS, AND I ASK THAT OUR CUSTOMERS BECOME MORE INFORMED ON THIS IMPORTANT PUBLIC POLICY ISSUE.
GLYNN SAID
, "
WHILE THIS APPLICATION REFLECTS THE CURRENT AND MARKET FORECAST OF NATURAL GAS PRICES FOR THE
NEXT TWELVE MONTHS, EVEN AT THESE HIGHER PRODUCER PRICES, NATURAL GAS IN SOUTHERN IDAHO WILL STILL BE 25% - 45% LESS
THAN ELECTRICITY.
THE COMPANY IS NOT REQUESTING ANY CHANGE IN THE PRICE COMPONENT FOR ITS OWN SERVICE, OPERATION, MAINTENANCE, OR
CAPITAL COSTS, WHICH HAS REMAINED THE SAME FOR OVER 20 YEARS. THEREFORE THE COMPANY S EARNINGS WILL NOT INCREASE AS A
RESULT OF THE PROPOSED PRICE CHANGES.
GLYNN WENT ON TO SAY
, "
INTERMOUNTAIN ENCOURAGES ALL ITS CUSTOMERS TO BE CONSCIOUS OF THEIR ENERGY USAGE.
HELPFUL TIPS ON WAYS TO CONSERVE AND USE ENERGY WISELY, AND HOW TO REQUEST ENERGY ASSISTANCE ARE PROVIDED THROUGH
BILL INSERTS AND ON THE COMPANY S WEB SITE (www.intqas.com). WE CONTINUE TO WORK WITH THE LOCAL AGENCIES THAT
ADMINISTER ENERGY ASSISTANCE FUNDS TO HELP THOSE RESIDENTIAL CUSTOMERS WHOSE INCOMES ARE MOST IMPACTED BY HIGHER
ENERGY PRICES. WE ALSO HAVE A NUMBER OF PROGRAMS TO HELP OUR CUSTOMERS LEVEL OUT THEIR ENERGY BILLS OVER THE YEAR
AND STABILIZE THE POTENTIAL IMPACT THAT COLD WEATHER WILL HAVE DURING PERIODS OF HIGHER NATURAL GAS COSTS.
IF THIS PROPOSED INCREASE IS APPROVED, RESIDENTIAL CUSTOMERS USING NATURAL GAS FOR HEATING AND WATER HEATING
COULD EXPERIENCE AN AVERAGE MONTHLY INCREASE OF $6.02 (9.9%). THOSE RESIDENTIAL CUSTOMERS USING NATURAL GAS FOR
SPACE HEATING ONLY COULD EXPERIENCE AN AVERAGE MONTHLY INCREASE OF $4.08 (8.7%). COMMERCIAL CUSTOMERS COULD
EXPERIENCE AN AVERAGE MONTHLY INCREASE OF $26.19 (10.5%).
IF APPROVED AS FILED, THE TOTAL NET REVENUE INCREASE FROM THIS CURRENT REQUEST WILL BE APPROXIMATELY $22.
MILLION (10%) AND IS PROPOSED TO BE EFFECTIVE JULY 1, 2004. THIS PROPOSAL IS SUBJECT TO PUBLIC REVIEW AND APPROVAL BY THE
IPUC. A COpy OF INTERMOUNTAIN S APPLICATION IS AVAILABLE AT THE OFFICES OF BOTH THE IDAHO PUBLIC UTILITIES COMMISSION AND
THE COMPANY.
EXECUTIVE OFFICES
INTERMOUNTAIN GAS COMPANY
555 SOUTH COLE ROAD. P.O. BOX 7608 . BOISE, IDAHO 83707 . [phone] . FAX: [phone]
CUSTOMER NOTICE Contact: Mike Huntington
Vice President
Marketing & External Affairs
[phone]
ON MAY 5, 2004, INTERMOUNTAIN GAS COMPANY ("INTERMOUNTAIN ) FILED ITS ANNUAL PURCHASED GAS COST ADJUSTMENT
APPLICATION WITH THE IDAHO PUBLIC UTILITIES COMMISSION ("IPUC"). THIS TYPE OF APPLICATION IS FILED EACH YEAR TO ENSURE THAT
THE COSTS THAT INTERMOUNTAIN IS INCURRING ON BEHALF OF ITS CUSTOMERS ARE PROPERLY REFLECTED IN ITS SALES PRICE.
IN ITS APPLICATION, INTERMOUNTAIN REQUESTS PERMISSION TO ADJUST ITS PRICES TO REFLECT THE HIGHER PRICES THAT
INTERMOUNTAIN MUST PAY TO ITS NATURAL GAS SUPPLIERS.
WILLIAM C. "BILL" GLYNN, PRESIDENT OF INTERMOUNTAIN GAS COMPANY, SAID
, "
As OUR CUSTOMERS ALREADY REALIZE
CRUDE OIL AND ITS DERIVATIVE GASOLINE, ARE CURRENTLY UNDER SEVERE PRICE PRESSURE. SIMILARLY NATURAL GAS, AS ANOTHER
ENERGY COMMODITY, IS NOW EXPERIENCING THOSE SAME PRESSURES BECAUSE IDAHO IS NOT ISOLATED FROM THE PRICE INFLUENCES OF
THE NATIONAL MARKET. CONSEQUENTLY, WE ARE FEELING THAT PRICE IMPACT IN OUR ROCKY MOUNTAIN AND CANADIAN SUPPLY BASINS.
WHILE CONSERVATION AND WISE ENERGY USE ARE THE BEST SHORT RANGE SOLUTIONS TO THE SUPPLY DEMAND IMBALANCE THAT DRIVES
THESE PRICE INCREASES, THE BEST LONG TERM SOLUTION IS ALLOWING THE INDUSTRY TO ACCESS THE ENORMOUS AMOUNTS OF NATURAL
GAS THAT ALREADY EXIST ON PUBLIC LANDS. THE INDUSTRY CAN PRUDENTLY DRILL WHERE THE RESOURCES EXIST WITHOUT DAMAGING
THESE LANDS, AND I ASK THAT OUR CUSTOMERS BECOME MORE INFORMED ON THIS IMPORTANT PUBLIC POLICY ISSUE.
GLYNN SAID
, "
WHILE THIS APPLICATION REFLECTS THE CURRENT AND MARKET FORECAST OF NATURAL GAS PRICES FOR THE
NEXT TWELVE MONTHS, EVEN AT THESE HIGHER PRODUCER PRICES, NATURAL GAS IN SOUTHERN IDAHO WILL STILL BE 25% - 45% LESS
THAN ELECTRICITY.
THE COMPANY IS NOT REQUESTING ANY CHANGE IN THE PRICE COMPONENT FOR ITS OWN SERVICE, OPERATION, MAINTENANCE, OR
CAPITAL COSTS, WHICH HAS REMAINED THE SAME FOR OVER 20 YEARS. THEREFORE THE COMPANY S EARNINGS WILL NOT INCREASE AS A
RESULT OF THE PROPOSED PRICE CHANGES.
GLYNN WENT ON TO SAY
, "
INTERMOUNTAIN ENCOURAGES ALL ITS CUSTOMERS TO BE CONSCIOUS OF THEIR ENERGY USAGE.
HELPFUL TIPS ON WAYS TO CONSERVE AND USE ENERGY WISELY, AND HOW TO REQUEST ENERGY ASSISTANCE ARE PROVIDED THROUGH
BILL INSERTS AND ON THE COMPANY'S WEB SITE (www.intqas.com). WE CONTINUE TO WORK WITH THE LOCAL AGENCIES THAT
ADMINISTER ENERGY ASSISTANCE FUNDS TO HELP THOSE RESIDENTIAL CUSTOMERS WHOSE INCOMES ARE MOST IMPACTED BY HIGHER
ENERGY PRICES. WE ALSO HAVE A NUMBER OF PROGRAMS TO HELP OUR CUSTOMERS LEVEL OUT THEIR ENERGY BILLS OVER THE YEAR
AND STABILIZE THE POTENTIAL IMPACT THAT COLD WEATHER WILL HAVE DURING PERIODS OF HIGHER NATURAL GAS COSTS.
IF THIS PROPOSED INCREASE IS APPROVED, RESIDENTIAL CUSTOMERS USING NATURAL GAS FOR HEATING AND WATER HEATING
COULD EXPERIENCE AN AVERAGE MONTHLY INCREASE OF $6.02 (9.9%). THOSE RESIDENTIAL CUSTOMERS USING NATURAL GAS FOR
SPACE HEATING ONLY COULD EXPERIENCE AN AVERAGE MONTHLY INCREASE OF $4.08 (8.7%). COMMERCIAL CUSTOMERS COULD
EXPERIENCE AN AVERAGE MONTHLY INCREASE OF $26.19 (10.5%).
IF APPROVED AS FILED, THE TOTAL NET REVENUE INCREASE FROM THIS CURRENT REQUEST WILL BE APPROXIMATELY $22.
MILLION (10%) AND IS PROPOSED TO BE EFFECTIVE JULY 1 2004. THIS PROPOSAL IS SUBJECT TO PUBLIC REVIEW AND APPROVAL BY THE
IPUC. A COpy OF INTERMOUNTAIN S APPLICATION IS AVAILABLE AT THE OFFICES OF BOTH THE IDAHO PUBLIC UTILITIES COMMISSION AND
THE COMPANY.
WORKPAPERNOS.
CASE NO. INT-G-O4-
INTERMOUNTAIN GAS COMPANY
(8 pages)
Workpaper No.
Case No. INT-O4-
Intermountain Gas Company
Page 1 of
Intermountain Gas Company
Northwest Pipeline TF-1 Full Rate Demand Workpaper
Northwest Pi eline TF.1 Full Rate Demand As Filed In INT.O3.
Line INT-03-INT-03-INT-03-
No,Trans ortation Annual Therms Prices Annual Cost
(a)(b)(c)(d)
TF-1 Demand 1 Contract #1 412 537 600 02862 806 826
TF-1 Demand 1 Contract #2 550,000 02862 731 241
TF-1 Demand 1 Contract #3 000,000 02862 089 260
TF-1 Demand 1 Contract #4 23,542 500 02862 673 786
TF-1 Demand 1 Contract #5 100 000 02862 346 302
TF-1 Demand 1 Contract #6
TF-1 Demand 1 Contract #7
Total Annual Cost 546 730 100 02862 647,415
Annualized Northwest Pi eline TF.1 Full Rate Demand From INT.O3-
Line INT-04-INT-04-INT-04-
No,Trans ortation Annual Therms Prices Annual Cost
(a)(b)(c)(d)
TF-1 Demand 1 Contract #1 412 537 600 02855 775 886
TF-1 Demand 1 Contract #2 550 000 02855 729 325
TF-1 Demand 1 Contract #3 000,000 02855 083,785
TF-1 Demand 1 Contract #4 542 500 02855 672 021
TF-1 Demand 1 Contract #5 850 000 02855 937 703
TF-1 Demand 1 Contract #6
TF-1 Demand 1 Contract #7
Total Annual Cost 567,480,100 02855 198,719
Annual Cost Difference As Filed VS. Annualized 551 304
Incremental Northwest Pi eline TF.1 Full Rate Demand
Line INT-04-INT-04-INT-04-
No,Trans ortation Annual Therms Prices Annual Cost
(a)(b)(c)(d)
TF-1 Demand 1 Contract #1
TF-1 Demand 1 Contract #2
TF-1 Demand 1 Contract #3
TF-1 Demand 1 Contract #4
TF-1 Demand 1 Contract #5
TF-1 Demand 1 Contract #6 200 000 02855 690,789
TF-1 Demand 1 Contract #7 5,460 000 02855 155 856
Total Incremental Cost 29,660 000 02855 846 645
Total Annual Cost Difference 397 949 (1)
(1) See Exhibit 4 , Line 3, Column (h)
Workpaper No.
Case No. INT-O4-
Intermountain Gas Company
Page 1 of
Intermountain Gas Company
Northwest Pipeline TF-1 Discounted Demand Workpaper
Northwest Pi eline TF.1 Discounted Demand As Filed In INT.O3.
Line INT-03-INT-03-INT-03-
No.Trans ortation Annual Therms Prices Annual Cost
(a)(b)(c)(d)
TF-1 Demand 1 Contract#1 680,000 02792 219 546
TF-1 Demand 1 Contract #2 28,470 000 01675 476,873
TF-1 Demand 1 Contract #3 29,404,400 01481 435,4 79
TF-1 Demand 1 Contract #4 650 000 01675 379 388
TF-1 Demand 1 Contract #5 200 000 01173 283 867
TF-1 Demand 1 Contract #6
Total Annual Cost 148,404,400 01883 795 152
Annualized Northwest Pi eline TF.1 Discounted Demand From INT.O3.
Line INT-04-INT-04-INT-04-
No,Trans ortation Annual Therms Prices Annual Cost
(a)(b)(c)(d)
TF-1 Demand 1 Contract #1 680 000 02785 216,488
TF-1 Demand 1 Contract #2 28,470 000 01671 475 734
TF-1 Demand 1 Contract #3 29,404,400 01476 434 009
TF-1 Demand 1 Contract #4 650 000 02785 630,803
TF-1 Demand 1 Contract #5 500 000 01671 609 879
TF-1 Demand 1 Contract #6
Total Annual Cost 160,704,400 02095 366,912
Annual Cost Difference As Filed VS. Annualized 571 760
Incremental Northwest Pi eline TF.1 Discounted Demand
Line INT-04-INT-04-INT-04-
No.Trans ortation Annual Therms Prices Annual Cost
(a)(b)(c)(d)
TF-1 Demand 1 Contract #1
TF-1 Demand 1 Contract #2
TF-1 Demand 1 Contract #3
TF-1 Demand 1 Contract #4
TF-1 Demand 1 Contract #5
TF-1 Demand 1 Contract #6 500 000 01949 711 385
Total Incremental Cost 500 000 01949 711 385
Total Annual Cost Difference 283 145 (1)
(1) See Exhibit 4, Line 4, Column (h)
Intermountain Gas Company
Upstream Capacity Workpaper
Line
No,
Upstream Capacity As Filed In INT.O3.
INT-03-1 INT-03-Transportation Annual Therms Prices
(a)(b)(c)
Upstream Contract #1
Upstream Contract #2
Upstream Contract #3
Total Annual Cost
200 713 500
155 624 370
155,025 220
511 363 090
01060
00477
01349
00970
Line
No.
Annualized Upstream Capacity From INT.O3.
INT-04- INT-04-
Transportation
(a)
Annual Therms
(b)
Prices
(c)
Upstream Contract #1
Upstream Contract #2
Upstream Contract #3
Total Annual Cost
199 687 850
156,446 890
155 025 220
511 159 960
01271
00500
01351
01059
Annual Cost Difference As Filed VS. Annualized
Workpaper No.
Case No. INT-O4-
Intermountain Gas Company
Page 1 of
INT-03-
Annual Cost
(d)
127 563
742 328
091 289
961 181
INT-04-
Annual Cost
(d)
539 031
782 224
094 183
5,415,438
454 257
Incremental Upstream Capacity
Line INT-04-INT-04-INT-04-
No,Trans ortation Annual Therms Prices Annual Cost
(a)(b)(c)(d)
10 Upstream Contract #1
Upstream Contract #2
12 Upstream Contract #3
13 Upstream Contract #4 058 160 01325 206,496
14 Upstream Contract #5 172 258 810 00470 809 276
15 UpstreamContract#6 129 967 270 01139 1,479 978
16 Total Incremental Cost 393 284 240 00889 3,495 750
17 Total Annual Cost Difference 950,007 (1)
(1) See Exhibit 4 , Line 5, Column (h)
Workpaper No.
Case No. INT-O4-
Intermountain Gas Company
Page 1 of
Intermountain Gas Company
Other Storage Facilities
INT-03-
Line Monthly INT-03-INT-03-INT-03-
No,Stora e Facilities Billinq Determinant Prices Monthly Cost Annual Cost
(a)(b)(c)(d)(d)
Demand Costs.
Clay Basin I Reservation 266 250 (1)28530 75,961 911 532
Clay Basin II Reservation 221 840 (1)28534 63,300 759,600
Clay Basin I Capacity 950 000 (2)00238 041 912,492
Clay Basin 1\ Capacity 26,625,000 (2)00238 63,368 760,416
AECO I Demand (2)00000
AECO 1\ Demand 064 970 (2)00109 28,411 340,932
Total Demand Costs 639 970 (3)307 081 684 972
Cycling Costs -
Clay Basin Cycling Costs 575 000 00076 517 534 204
AECO Cycling Costs 064 970 00074 288 231,456
Total Cycling Costs 639 970 805 765 660
Storage Demand Charge Credit 390,700
Total Costs Including Storage Credit 059 932
INT-04-
Monthly INT-04-INT-04-INT-04-
Stora e Facilities Billinq Determinant Prices Monthly Cost Annual Cost
(a)(b)(c)(d)(d)
Demand Costs -
Clay Basin I Reservation 266,250 (1)28534 972 911 664
Clay Basin II Reservation 221 840 (1)0.28534 300 759 600
Clay Basin I Capacity 950 000 (2)00238 041 912,492
Clay Basin 1\ Capacity 625 000 (2)00238 63,368 760,416
AECO I Demand
AECO 1\ Demand 064 970 (2)00130 822 405 864
Total Demand Costs 639 970 (3)312 503 3,750 036
Cycling Costs.
Clay Basin Cycling Costs 58,575 000 00076 517 534 204
AECO Cycling Costs 26,064 970 00074 288 231,456
Total Cycling Costs 639 970 805 765 660
Estimated Storage Demand Charge Credit 1,400 000
Total Costs Including Storage Credit 115,696
Total Annual Cost Difference Including Storage Credit (944 236) (4)
(1) Charge Based on Maximum Daily Withdrawal
(2) Charge Based on Maximum Contractual Capacity
(3) Non Additive Billing Determants; Only Includes Capacity Volumes
(4) See Exhibit 4, Line 19, Column (h)
Workpaper No.
Case No. INT-O4-
Intermountain Gas Company
Page 1 of
INTERMOUNTAIN GAS COMPANY
Peak Day Analysis for Demand Allocators in Case No. INT -O4-
FIRM
Line CORE TOTAL TRANSPORTATION TOTAL FIRM
No,RS-RS-GS.CORE TRANSPORTATION
DEMAND ALLOCATORS PER CASE NO. INT-O3-
Peak Day Therms 434,491 502 979 069,049 006,519 199 616 070 254 686
% olTotal 92,19043%80957%
TOTAL
PEAK
261 205
.1.QQ.Q.QQQ?!g
PROPOSED DEMAND ALLOCATORS PER CASE NO. INT-O4-:
Peak Day Therms (Line 2)434,491 502 979 069 049 006 519
Customers Embedded within Line 2 61,024 155,427 937 241 388
Peak Day Usage Per Customer (Line 5 divided by Line 6)42.
January 2004 Actual Customers 813 166,419 25,741 253 973
INT-O4- Peak Day Therms (Line 7 mulitplied by Line 8)440 109 609,272 103,517 152 898 157 322 070
% olTotal 93,68875%467484%1 63641%
(1) FY04 Contract Therms
212 392 (1)365,290
31125%
Detail Detail Amount Sub-Total Total
(b)(c)(d)(e)(f)
4,427 981.91
673 733,53)
077 139
01701 868 822,
542 555,66)
(114 573.75)
501 351.50
050 970,11)
561 363.75
(988,254,86)
394,
(3,045,53)
348,
097 480,09)
INTERMOUNTAIN GAS COMPANY
Analysis of Account 1860 Surcharges (Credits)
Estimated June 30, 2004
LineNo. Description
(a)
ACCOUNT 1860 VARIABLE AMOUNTS:
Net Cumulative Deferred Gas Balance in 1860.2010 as of 7/1/03
Amortization in 1860,2020 as of 3/31/04
Estimated Therm Sales 4/1 through 6/30/04
Amortization Rate
Estimated Amortization in 1860.2020 at 6/30/04
Estimated Balance in 1860,2010 at 6/30/04
Deferred Gas Costs From Producers/Suppliers in 1860,2180 at 7/1/03
Deferred Gas Costs From Producers/Suppliers in 1860,2180 through 3/31/04
Estimated Deferred Costs in 1860,2180 from 4/1 through 6/30/04
Estimated Balance in 1860.2180 at 6/30/04
Daily Gas Excess Sales Deferred in 1860,2240 at 3/31/04
Gas Cost Carrying Charge Deferred in 1860,2340 at 3/31/04
Estimated Gas Cost Carrying Charge from 4/1 through 6/30/04
Estimated Balance in 1860,2340 at 6/30/04
ESTIMATED ACCOUNT 1860 VARIABLE BALANCE AT 6/30/04
ACCOUNT 1860 FIXED AMOUNTS:
Net Cumulative Deferred Gas Balance in 1860,2050 at 7/1/03
RS-1 Deferred Gas Baiance in 1860,2060 at 7/1/03
Amortization for RS-1 in 1860,2060 at 3/31/04
Estimated RS-1 Therm Saies 4/1 through 6/30/04
RS-1 Amortization Rate
Estimated RS-1 Balance in 1860,2060 at 6/30/04
866 315
(0,00786)
RS-2 Deferred Gas Balance in 1860,2070 at 7/1/03
Amortization for RS-2 in 1860,2070 at 3/31/04
Estimated RS-2 Therm Sales 4/1 through 6/30/04
RS-2 Amortization Rate
Estimated RS-2 Balance in 1860,2070 at 6/30/04
244 130
(0,00358)
GS-1 Deferred Gas Baiance in 1860,2080 at 7/1/03
Amortization for GS-1 in 1860,2080 at 3/31/04
Estimated Therm Sales 4/1 through 6/30/04
GS-1 Amortization Rate
Estimated GS-1 Balance in 1860,2080 at 6/30/04
104 057
(0,00838)
Industrial Deferred Gas Balance in 1860,2090 at 7/1/03
Amortization for T-1 & T-2 in 1860,2090 at 3/31/04
Estimated T-1 Block 1 & 2 Therm Sales 4/1 through 6/30/04
T -1 Amortization Rate
6,436 803
(0,00177)
165 210
03074
Estimated T -2 Contract 4/1 through 6/30/04
2 Amortization Rate
Estimated Industrial Balance in 1860,2090 at 6/30/04
078,
Estimated Cumulative Balance in 1860,2050 at 6/30/04
Fixed Cost Collection Deferred in 1860.2200 at 7/1/03
Fixed Cost Collection Deferred in 1860,2200 through 3/31/04
Estimated Fixed Cost Collection Deferred from 4/1 through 6/30/04
Estimated Balance in 1860,2200 at 6/30/04
Statoil Revenue Deferred in 1860.2260 at 7/1/03
Statoil Revenue Deferred in 1860,2260 through 3/31/04
Estimated Statoil Revenue Deferred from 4/1 through 6/30/04
Estimated Balance in 1860,2260 at 6/30/04
Capacity Released/Purchased Deferred in 1860.2320 at 3/31/04
223.38
(224 449.45)
109,
670,24)
(395 322,11)
534,
251.45
(625 229,33)
143 332,
(119,64)
($20948,23)
(11 393,14)
Workpaper No.
Case No. INT-O4-
Intermountain Gas Company
Page 1 of 2
556 969,
(268 335,32)
(494 526,35)
(767 309,89)
(27 382.45)
(584,82)
(194,428,31)
370 540,
039 718,
215,829,
885.24)
(43 360.40)
(14 166.47)
(59,412,11)
(539 195,89)
INTERMOUNTAIN GAS COMPANY
Analysis of Account 1860 Surcharges (Credits)
Estimated June 30, 2004
Line
No.Description
(a)
Gas Cost Carrying Charge Deferred in 1860.2420 at 3/31104
Estimated Gas Cost Carrying Charge from 4/1 through 6/30/04
Estimated Balance in 1860.2420 at 6/30104
Detail
(b)
Gas Cost Carrying Charge Deferred in 1860.2430 at 3/31/04
Estimated Gas Cost Carrying Charge from 4/1 through 6/30/04
Estimated Balance in 1860,2430 at 6/30/04
NWP RP93.5 Surcharge Amortization Deferred in 1860,2510 at 3/31/04
Market Segmentation Deferred in 1860,2530 at 711103
Market Segmentation Deferred in 1860,2530 through 3/31/04
Estimated Deferral in 1860.2530 from 4/1 through 6/30/04
Estimated Balance in 1860,2530 at 6/30/04
RS-1 Amortization in 1860,2540 at 3/31/04
Estimated RS-1 Thenn Sales from 4/1 through 6/30/04
RS,1 Amortization Rate
Estimated RS-1 Amortization in 1860,2540 at 6/30/04
866 315
00897
RS-2 Amortization in 1860,2540 at 3/31/04
Estimated RS-2 Thenn Saies from 4/1 through 6/30/04
RS-2 Amortization Rate
Estimated RS-2 Amortization in 1860,2540 at 6/30/04
244 130
00842
GS-1 Amortization in 1860.2540 at 3/31/04
Estimated GS Thenn Sales from 4/1 through 6/30/04
GS-1 Amortization Rate
Estimated GS-1 Amortization in 1860,2540 at 6/30/04
104 057
00839
Estimated Core Amortization in 1860,2540 at 6/30/04
1 Amortization in 1860,2550 at 3/31/04
Estimated T-1 Block 1&2 Thenn Saies from 4/1 through 6/30/04
1 Amortization Rate
Estimated T-1 Amortization in 1860,2550 at 6/30/04
6,436 803
00404
2 Amortization in 1860,2550 at 3/31/04
Estimated T-2 Contract from 4/1 through 6/30/04
T -2 Amortization Rate
Estimated T-2 Amortization in 1860,2550 at 6/30/04
165,210
06043
Estimated Industrial Amortization in 1860,2550 at 6/30/04
Estimated Balance in 1860,2530 at 6/30/04
NWP RP95.409 Refund Amortization Deferred in 1860.2570 at 3131104
ESTIMATED ACCOUNT 1860 FIXED BALANCE AT 6/30/04
TOTAL DEFERRED ACCOUNT 1860 BALANCE
Workpaper No.
Case No. INT-O4-
Intermountain Gas Company
Page 2 of 2
Detail Amount Sub.Total Total
(c)(d)(e)(f)
111.02
49,
160,
852,
782,
634.
(1,626.78)
813.57
780 123,12)
589 292,
368 601,55)
252 979,
620,
305 600.43
941 314,
229,395,
170,709,
626 259,
143 503.04
769 762,
246 072.64
886,
004,
106 891,
951.22
983.64
39,934,
146 826.42
297,
521,
652 625.
555 145.
Workpaper No.
Case No. INT-04-
Intermountain Gas Company
Page 1 of
INTERMOUNTAIN GAS COMPANY
1 Tariff Block 1 , Block 2, and Block 3 Adjustment
Line
No.Description
(a)
Industrial Therm Sales (10/1/03 - 9/30/03)
Blocks 1 and 2 Therm Sales
Percent Therm Sales between Blocks 1 and 2
Proposed Adjustment to T -1 Tariff (1)
Industrial Therm Sales (10/1/03 - 9/30/03)
Annualized Adjustment (Line 4 multiplied by Line 5)
Annualized Adjustment (Line 4 multiplied by Line 5)
Percent Annualized Sales included in Block 1
Adjustment to Block 1 (Line 7 mulitplied by Line 8)
Block 1 Therms
Price AdjustmentlTherm Block 1 (Line 9 divided by Line 10)
Northwest Pipeline TF-1 Commodity Charge Change (2)
Total Price AdjustmentlTherm Block 1
Annualized Adjustment (Line 4 multiplied by Line 5)
Percent Annualized Sales included in Block 2
Adjustment to Block 2 (Line 14 multiplied by Line 15)
Block 2 Therms
Price AdjustmentlTherm Block 2 (Line 16 divided by Line 17)
Northwest Pipeline TF-1 Commodity Charge Change (2)
Total Price AdjustmentlTherm Block 2
Total Price AdjustmentlTherm Block 3
Block 1 Block 2 Block 3
Therm Sales Therm Sales Therm Sales
(b)(c)(d)
093 530 218 630
093 530 218 630
94,988%012%
(1) See Exhibit No., Line 37, Col. (I) minus the difference of Line 22, Col. (0 minus Line 22, Col. (c)
(2) See Exhibit No, 4, Line 22, Col. (0 minus Line 22, Col. (c)
Total
(e)
312 160
312 160
100,000%
01540
312 160
374,407
374,407
94.988%
355 642
093 530
01540
00000
01540
374,407
012%
765
218 630
01540
00000
01540