IGC-PGA-APP.pdf

EXECUTIVE OFFICES
INTERMOUNTAIN GAS COMPANY
555 SOUTH COLE ROAD. P.O. BOX 7608 . BOISE, IDAHO 83707 . [phone] . FAX: [phone]
May 23 2001
Ms. Jean Jewell
Commission Secretary
Idaho Public Utilities Commission
472 W. Washington St.
P. O. Box 83720
Boise , 10 83720-0074
RE:Intermountain Gas Company
Case No. INT-02-
Dear Ms. Jewell:
Enclosed for filing with this Commission is an original signed copy of Intermountain Gas
Company s Application and supporting Workpapers for Authority to Decrease Its Prices on
July 1 2002. Intermountain is also filing this Application electronically with the Commission.
Please acknowledge receipt of this filing by stamping and returning a photocopy of this
Application cover letter to us.
If you have any questions or require additional information regarding the attached , please
contact me at 377-6168.
ve~
Zl P. McGrath
Director
Market Services and Regulatory Affairs
MPM/slk
Enclosures
cc:W. C. Glynn
J. K. lebens
N. C. Hedemark
M. E. Huntington
P. R. Powell
M. W. Richards, Jr.
RECEIVED
Thursday, 23 May, 2002 02:45:59 PM
IDAHO PUBLIC UTILITIES COMMISSION
INTERMOUNTAIN GAS COMPANY
CASE NO. INT-02-
APPLICATION,
EXHIBITS,
AND
WORKP APERS
In the Matter of the Application of INTERMOUNTAIN GAS COMPANY
for Authority to Decrease Its Prices on July 1, 2002
(July 1, 2002 Purchased Gas Cost Adjustment Filing)
RECEIVED
Thursday, 23 May, 2002 02:45:59 PM
IDAHO PUBLIC UTILITIES COMMISSION
Morgan W. Richards, Jr.
MOFFATT, THOMAS, BARRETT, ROCK & FIELDS, CHARTERED
PO Box 829, Boise, Idaho 83701
Telephone [phone]
MTBR&F 11-500.310
Attorneys for Intennountain Gas Company
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
In the Matter of the Application of
INTERMOUNTAIN GAS COMPANY
for Authority to Decrease Its Prices
Case No. INT-02-
APPLICATION
Intennountain Gas Company ("Intennountain"), 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 , 2002 new rate schedules which will decrease
its annualized revenues by $52.5 million, pursuant to the Rules of Procedure of the Idaho Public
Utilities Commission ("Commission ). Because of changes in Intennountain's gas related costs, as
described more fully in this Application, Intennountain s earnings will not be effected as a result of
the proposed decrease in prices and revenues. Intennountain's current rate schedules showing the
proposed decreases are attached hereto as Exhibit No.1 and are incorporated herein by reference.
Intennountain'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
Intennountain 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
In support of this Application, Intennountain does allege and state as follows:
APPLICATION - 2
Intennountain 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.
Intennountain 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, Inkom, 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.
Intennountain'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.
Intennountain seeks with this Application to pass through to each of its customer classes a
decrease in gas related costs resulting from: 1) a net decrease in costs for Intennountain's natural
gas interstate transportation, 2) an updated customer allocation of gas related costs pursuant to the
Company s Purchased Gas Cost Adjustment provision, and 3) the inclusion of temporary
surcharges and credits for one year relating to gas and interstate transportation costs from
APPLICATION - 3
Intennountain's deferred gas cost account. Intennountain also seeks with this Application
eliminate the temporary surcharges and credits included in its current prices during the past
months, pursuant to Case No. INT-01-3. The aforementioned changes would result in an overall
price decrease to Intennountain's RS-, RS-, GS-, LV-, T-1 and T-2 customers.
These price changes are applicable to service rendered under rate schedules affected by and
subject to Intennountain s Purchased Gas Cost Adjustment ("PGA"), approved by this Commission
in Order No. 26019, Case No. INT-95-
Exhibit No.4 summarizes the price changes in: 1) Intennountain's base rate gas costs and its
rate class allocation, and 2) adjusting temporary surcharges or credits flowing through to
Intennountain's direct sales and transportation customers. Exhibit No.4 is attached hereto and
incorporated herein by reference.
III.
The current prices of Intennountain are those approved by this Commission in Order
No. 28783 , Case No. INT-01-
IV.
Intennountain s proposed prices incorporate all price changes impacting Intennountain
Interstate Capacity including, but not limited to, prices charged by Williams Gas Pipeline - West
Williams" or "Northwest") tariffs which have transpired since Intennountain s last PGA filing
in Case No. INT-01-3. Exhibit No., Lines 1 through 32, details the proposed decrease in
Intennountain s prices resulting from Intennountain s natural gas interstate transportation and
storage costs.
The Weighted Average Cost of Gas ("W ACOG") reflected in Intennountain s proposed
prices is $0.35295 per thenn, as shown on Exhibit No., Lines 26 through 29, Column (t). This
is the same WACOG recently approved by this Commission as part of Case No. INT-01-
Order No. 28783. Current market based commodity prices support the continuance of the
$0.35295 per thenn W ACOG to Intennountain s customers.
The PGA mechanism established with this Commission has been instrumental in
providing Intennountain, on behalf of its customers, the needed flexibility to patiently await, and
then lock or hedge, natural gas prices driven by market fundamentals rather than the vagaries of
the natural gas futures market. Intennountain Gas Company continues to be vigilant in managing
APPLICATION - 4
its gas supplies and storage agreements and is party to certain natural gas hedging transactions
that will afford its customers savings over the next twelve (12) month period as compared to the
$0.35295 per thenn W ACOG.
Intennountain strongly supports long-tenn price stability for its customers and
incorporates a price stability criterion when managing its gas supplies. Natural gas futures prices
portend an upward trend for future PGA periods as depicted on Exhibit No.5. While there is no
assurance that this will be the case, Intennountain believes that market fundamentals will not
support the future price levels shown on Exhibit No., and continues to rely strongly on the
supply and demand fundamentals that should result in natural gas prices at a lower price range.
Intennountain believes that by allowing the W ACOG to remain at the $0.35295 per
thenn level, a price increase can be avoided, or at a minimum mitigated, during the July 2003
PGA period (1 year from today) by offsetting future increases with the savings generated by
Intennountain s currently hedged supplies.
Intennountain continues to be vigilant in monitoring and managing the prices paid
pursuant to the contracts with its suppliers. Intennountain intends to file an "out of period" PGA
if natural gas prices decline substantially to a level that facilitates price stability for the future
with the pass through of any deferred gas cost credits that may exist at the time.
Exhibit No.5 is attached hereto and incorporated herein by reference.
VI.
Pursuant to Case No. INT-01-, Intennountain has included temporary surcharges and
credits in its July 1 , 2001 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-01-3. Line 34 of
Exhibit No.4 reflects the elimination of these temporary surcharges and credits.
VII.
Intennountain's PGA tariff, approved in Order No. 26019, Case No. INT-95-, includes
provisions whereby Intennountain 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. Intennountain s proposed prices include a fixed cost collection adjustment
pursuant to these PGA provisions, as outlined on Exhibit No., Line 25. The price reduction
resulting from this adjustment is included on Exhibit No., Line No. 35. Exhibit No.6 is attached
hereto and incorporated herein by reference.
APPLICATION - 5
VIII.
Intermountain is party to certain agreements whereby Intennountain has released segmented
portions of its finn capacity rights when not needed to meet its customer needs, and proposes to
pass back to its customers the benefits generated from the capacity release agreements, totaling
$2.4million. Exhibit No., Line 1 , reflects the inclusion of the $2.4 million credit. Intennountain
proposes to pass back this amount via the per thenn credit as detailed on Exhibit No.8. Exhibit
No.s 7 and 8 are attached hereto and incorporated herein by reference.
IX.
On July 26 2001 , Northwest submitted its Compliance Filing in Federal Energy Regulatory
Commission s ("FERC") Docket No. RP95-409. The Compliance Filing indicated that Northwest
would be preparing refunds consistent with the Compliance Filing and that Northwest intended to
issue the refunds by August 31 , 2001. Intennountain Gas Company received $3.3 Million from
Northwest pursuant to the Compliance Filing. The rates at issue in the RP95-409 Case were
effective for a locked-in period of 13 months from February 1 , 1996 through February 28, 1997.
Several of Intennountain Gas Company s industrial customers that received finn transportation
service from Intennountain during this 13 month period have since migrated to Intennountain s T-
and T-4 service. Intennountain proposes to refund an allocated portion of the $3.3 million, or $0.
million, directly to Intennountain's LV-, T-, T-, T-3 and T-4 customers to reimburse these
customers for overpayment's made during the locked-in period via a credit on the industrial
customer s bill. The allocated portion is reflective of the fixed cost responsibility assigned to
Intennountain's customers during the locked-in period.
Intennountain proposes to pass back to its RS-, RS- 2, and GS-1 customers a refund amount
generated from Northwest's Case No. RP95-409, totaling $2.4 million. Exhibit No., Line 2
reflects the inclusion of the $2.4 million refund. Intennountain proposes to pass back this amount
via the per thenn credit as detailed on Exhibit No.9. Exhibit No.9 is attached hereto and
incorporated herein by reference.
APPLICATION - 6
In compliance with the Federal Energy Regulatory Commission s Orders in Docket No.
RP93-5 and in conformity with Part 154 ofFERC's regulations, Northwest was directed to impose
surcharges resulting from excess refunds made during the period April 1, 1993 through October 31
1994. Intennountain Gas Company was surcharged $1.2 Million from Northwest pursuant to
Docket No. RP93-5. Several of Intennountain Gas Company s industrial customers that received
finn transportation service from Intennountain during this April 1, 1993 through October 31, 1994
period, and received a portion of the excess refunds, have since migrated to Intennountain s T - 3 and
4 service. Intennountain proposes to charge an allocated portion of the $1.2 million, or $0.
million, directly to Intennountain s LV-, T-, T-, T-3 and T-4 customers via a surcharge on the
industrial customer s bilL The allocation of this surcharge to all customer classes is reflective of the
refunds originally made pursuant to Docket No. RP93-5 which were included in Intennoutain'
IPUC Case No. INT-98-
Intennountain proposes to collect from its RS-, RS-, and GS-1 customers a surcharge
amount generated from Northwest's Case No. RP93-5 totaling $0.9 million. Exhibit No., Line 3
reflects the inclusion of the $0.9 million surcharge. Intennountain proposes to collect this
amount via the per thenn surcharge as detailed on Exhibit No. 10. Exhibit No. 10 is attached
hereto and incorporated herein by reference.
XI.
Intennountain proposes to allocate deferred gas costs from its Account No. 186 balance to
its customers through temporary price adjustments effective during the 12-month period ending
June 30, 2003, as follows:
1) Intennountain has been deferring in its Account No. 186 fixed gas costs. The debit
shown on Exhibit No. 11 , Line 11 , Cot (b) of $116 073 is predominantly attributable to the
collection of interstate pipeline capacity costs and the true-up of expense issues previously ruled on
by this Commission. Intennountain proposes to collect or pass back these balances via the per therm
surcharges and credits, as detailed on Exhibit No. 11 and included on Exhibit No., Line 4. Exhibit
No. 11 is attached hereto and incorporated herein by reference.
Intennountain has been deferring in its Account No. 186 amounts representing
unamortized variable gas costs from Case No. INT-01-3. Intennountain s Account No. 186
balance estimated at June 30, 2002 includes a debit balance of $470 959 pursuant to these
APPLICATION - 7
unamortized amounts, as shown on Exhibit No. 12, Lines 2-, Col. (b). Intennountain proposes
to collect this debit balance via the per thenn surcharge, as shown on Exhibit No. 12 and
included on Exhibit No., Line 5. Exhibit No. 12 is attached hereto and incorporated herein by
reference.
3) Intennountain has been deferring in its Account No. 186 deferred gas cost credits of
766 014 (Exhibit No. 12, Lines 5-, Col. (b)J, attributable to Intennountain s variable gas cost
collection since July 1 , 2001. In it's Order No. 28783, Case No. INT-01-, the Commission
directed Intennountain Gas Company to continue to defer on its books $3 505 756 in spot market
purchases until the next PGA tracker. The Commission Staff has completed its investigation of
these purchases and the amount has been included for collection in the deferred credit noted above.
Intennountain's gas supply management efforts were instrumental in securing supplies below the
W ACOG embedded in its tariffs resulting in the overall credit shown above. Intennountain
proposes to pass back the $6 766 014 credit balance via a per thenn credit, as shown on Exhibit No.
12 and included on Exhibit No., Line 5.
XII.
Intennountain has allocated the proposed price decrease to each of its customer classes
based upon Intennountain's PGA provision. A straight cents per thenn price decrease was not
utilized for the T -1 tariff. No fixed costs are currently recovered in the tail block of Intennountain
T -1 tariff. Absent Williams ' finn transportation TF -1 Commodity Charge, the proposed decrease in
the T -1 tariff is fixed cost related, and therefore, a cents per thenn decrease was made only to the
first two blocks ofthe tariff for these fixed costs.
XIII.
The proposed decrease in the T -2 tariff is fixed cost related, and therefore, a cents per therm
decrease was made only to the T-2 demand charge for these fixed costs.
XIV.
Exhibit No. 13 is an analysis of the overall price decrease by class of customer. Exhibit No.
13 is attached hereto and incorporated herein by reference.
APPLICATION - 8
xv.
The proposed overall price decrease herein requested among the classes of service of
Intennountain will not affect Intennountain's earnings, and is just, fair, and equitable.
XVI.
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 Intennountain s customers
through a Customer Notice and by a Press Release sent to daily and weekly newspapers, and major
radio and television stations in Intennountain'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 in Intennountain s rate
proceedings.
XVII.
Intennountain requests that this matter be handled under modified procedure pursuant to
Rules 201-204 ofthe Commission s Rules of Procedure. Intennountain stands ready for immediate
consideration ofthis matter.
APPLICATION - 9
WHEREFORE, Intennountain 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 , 2002 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 23rd day of May, 2002.
INTERMOUNTAIN GAS COMPANY MOFFATT, THOMAS, BARRETT, ROCK
& FIELDS , CHARTERED
By l\~k-L~ ~~~iJ."C? Michael E. Huntington
Vice President
Marketing & External Affairs
By \J,
Morgan W. Ri ards, Jr.
Of the Finn
Attorneys for Intennountain Gas Company
~L-
APPLICATION - 10
CERTIFICATE OF MAILING
I HEREBY CERTIFY that on this 23rd day of May, 2002, I served a copy of the
foregoing Case No. INT -02- upon:
Lisa Nordstrom
Deputy Attorney General
Idaho Public Utilities Commission
472 W. Washington St., PO Box 83720
Boise, ID 83720-0074
R. Scott Pasley
J. R. Simplot Company
PO Box 27
Boise, ID 83707
ConleyE. Ward, Jr.
Givens, Pursley, Webb & Huntley
277 N. 6th St., Suite 200
PO Box 2720
Boise, ID 83701
Wendell M. Phillips
615 South Phillippi Street
Boise, ID 83705
Edward A. Finklea
Paula E. Pyron
Energy Advocates LLP
526 NW 18 Avenue
Portland, OR 97209
David Hawk
J. R. Simplot Company
PO Box 27
Boise, ID 83707
Paula Pyron
Northwest Industrial Gas Users
4113 Wolf Berry Court
Lake Oswego, OR 97035
by depositing true copies thereof in the United States Mail, postage prepaid, in envelopes addressed
to said persons at the above addresses.
APPLICATION -
:r -?F=
ector
Market Services and Regulatory Affairs
EXHIBIT NO.
CASE NO. INT-02-
INTERMOUNTAIN GAS COMPANY
CURRENT TARIFFS
Showing Proposed Price Changes
(8 pages)
COMPARISON OF JULY 16, 2001 PRICES
TO PROPOSED JULY 1, 2002 PRICES
Exhibit No.
Case No. INT-O2-
Intermountain Gas Company
Page 1 of 8
July 16,2001 ProposedLinePricesProposedJuly 1, 2002
No.Rate Class INT-01-Adjustment Prices
(a)(b)(c)(d)
RS-
April - November 94975 $ (0.20818)74157
December - March 83719 (0.20818)62901
RS-
April - November 81517 (0.20524)60993December - March 78154 (0.20524)57630
GS-
April - November
Block 1 83797 (0.20419)63378
Block 2 81624 (0.20419)61205
Block 3 79522 (0.20419)0.59103
December - March
Block 1 78712 (0.20419)58293
Block 2 76592 (0.20419)0.56173
Block 3 74546 (0.20419)54127CNG Fuel 74546 (0.20419)54127
LV-l (1)
Block 1 64497 (0.20237) 2 0.44260
Block 2 60648 (0.20237) 3 0.40411
Block 3 0.53086 (0.19603) 4 33483
Block 1 12482 (0.00634) 2 0.11848
Block 2 08633 (0.00634) 3 07999
Block 3 01071 00000 4 01071
Ammonia 02525 00000 02525
Demand Block 1 60887 (0.07038)1.53849
Demand Block 2 80729 (0.07038)73691Commodity Charge 00656 00000 00656Over-Run Service 04915 00000 04915
I The LV -1 Adjustment is calculated by taking Line 22 - 24, Col ( c), minus the variable
temporary from INT-01-, plus the variable temporary on Exhibit 1'Z, Line 8, Col (b)2 See Workpaper No., Line 13, Co! (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.
Thirt second Third Revised eet No. 01 (Page 1 of 1)
Exhibit No.
Case No. INT-O2-
Intermountain Gas Company
Page 2 of 8Name
of Utility Intermountain Gas Company
. IDAHO PUBLIC UTILITIES COMMISSIONAPPROVED EFFECTIVE
Rate Schedule RS-
RESIDENTIAL SERVICE
Jlll.16 '------;Jt!I:--i
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1f-1f1~ SECRETARY
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 billing periods ending April through November
Customer Charge - $2.50 per bill
$0.74157
Commodity Charge - $0. 9~97S per therrn*
For billing periods ending December through March
Customer Charge - $6.50 per bill
$0.62901
Commodity Charge - $0.83719 per therrn*
*Includes:
$ (0.03915)
Temporary purchased gas cost adjustment of $0 .16~16
Weighted average cost of gas of $0.35295
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 ServiceProvisions of the Company I s Tariff, of which this rate schedule is a part.
Issued by: Intermountain Gas Company
By: Michael E. Huntington Title:
Effective: July 1 e, 2001 July 1 , 2002
Vice President - Marketing and External Affairs
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.Thirty Socond Third Revised Sheet No.
Name
of Utility
02 (Page 1 of 1)
Intermountain Gas Company
Exhibit No.
Case No. INT-O2-
Intermountain Gas Company
Page 3 of 8
IDAHO PUBLIC UTILITIES COMMISSIONAPPROVED EFFECTIVE
JtJllo'OI ~u"L16'
\'..., -
"'- 01;;,;;~
~1fJ.~ SECREI'ARY
Rate Schedule RS-
MULTIPLE USE RESIDENTIAL SERVICE
AVAILABILITY:
Available to individually metered consumers using gas forresidential purposes including both water heating and space heating.several
RATE:
Monthly minimum charge is the customer charge.
For billing periods ending April through November
Customer Charge - $2.50 per bill
$0.60993
Commodity Charge - $9.81517 per the~*
For billing periods ending December through March
Customer Charge - $6.50 per bill
$0.57630
Commodity Charge - $0. 7815i per the~*
*Includes:
$ (0.03839)
Temporary purchased gas cost adjustment of $9.16159
Weighted average cost of gas of $0.35295
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 ServiceProvisions of the Company I s Tariff, of which this rate schedule is a part.
Issued by: Intermountain Gas Company
By: Michael E. Huntington Title:Effective: July 1 e, 2901 July 1 , 2002
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. 03
Name
of Utility
(Page 1 of 2)
Intermountain Gas Company
Exhibit No.
Case No. INT-O2-
Intermountain Gas Company
Page 4 of 8
IDAHO PUBLIC UTILITIES COMMISSIONAPPROVED EFFECTIVE
JJl..16 '61 .)u':.. 16 '
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~1fJ.~ SECRETARY
Rate Schedule GS-
GENERAL SERVICE
AVAILABILITY:
Available to individually metered customers whose requirements for natural
gas do not exceed 2,000 theDms per day, at any point on Company's distributionsystem. Requirements in excess of 2,000 theDms per day may be served underthis rate schedule upon execution of a one-year written service contract.
RATE:
Monthly minimum charge is the customer charge.
For billing periods ending April through November
Customer Charge - $2.00 per bill
Commodity Charge - First 200 theDms per bill ~ $0.83797Next 1,800 theDms per bill ~ $0.81624Over 2,000 theDms per bill ~ $0.79522
$0.63378*
$0.61205*
$0.59103*
For billing periods ending December through March
CUstomer Charge - $9.50 per bill
Commodity Charge - First 200 theDms per bill ~ $0.78712Next 1,800 theDms per bill ~ $0.76592Over 2,000 theDms per bill ~ $0.74516
$0.58293*
$0.56173*
$0.54127*
*Includes:
Temporary purchased gas cost adjustment of $0.16038
Weighted average cost of gas of $0.35295
$(0.03877)
Issued by: Intermountain Gas Company
By: Michael E. Huntington Title:Effective: July 16, 2001 July 1 , 2002
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. 03
Name
of Utility
(Page 2 of 2)
Intermountain Gas Company
Exhibit No.
Case No. INT-O2-
Intermountain Gas Company
Page 5 of 8
IDAHO PUBLIC UTILITIES COMMISSIONAPPROVED EFFECTIVE
:JL 16 '81 v " 16 '
\""".
0"" ..,';;,~~
t--1fJ.~ SECRETARY
Rate Schedule GS-
GENERAL SERVICE (Continued)
For separately metered deliveries of gas utilized solely as CompressedNatural Gas Fuel in vehicular internal combustion engines.
Customer Charge - $9.50 per bill
$0.54127
Commodi ty Charge - $ 9 . 7 t 5 t 6 per the~*
*Includes:
Temporary purchased gas cost adjustment of $0.16938
Weighted average cost of gas of $0.35295
$ (0.03877)
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas asprovided 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 Inte~ountainGas Company, upon exiting the GS-1 service, all gas and transportationrelated costs incurred to serve the customer during the GS-1 serviceperiod 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-service, any excess gascommodity or transportation payments made by the customer during thetime they were a GS-1 customer.
2. All natural gas service hereunder is subject to the General ServiceProvisions of the Company's Tariff, of which this rate schedule is apart.
Issued by: Intermountain Gas Company
By: Michael E. Huntington Title:
Effective: July 1 e, 2001 July 1 , 2002
Vice President - Marketing and External Affairs
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.
Fo Second Third Revised Sheet No. 04 (Page 1 of
Name
of Utili Intermountain Gas Com an
Exhibit No.
Case No. INT-O2-
Intermountain Gas Company
Page 6 of 8
IDAHO PUBLIC UTILITIES COMMISSIONAPPROVED EFFECTIVE
JUl1o '8t u'UL 16 '
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t--1fJ.~ SECRETARY
Rate Schedule LV-
LARGE VOLUME FIRM SALES SERVICE
AVAILABILITY:
Available at any mutually agreeable delivery point on the Company'distribution system to any existing customer receiving service under the Company'
rate schedules LV-l, T-l, or T-2, or any new customer whose usage does not exceed500,000 therms annually, upon execution of a one-year minimum written servicecontract for firm sales service in excess of 200,000 therms per year.
MONTHLY RATE:
Commodi ty Charge:
First 250,000 therms per bill ~ $O.6ii97* $0.44260*Next 500,000 therms per bill ~ $O.696i8* $0.40411*Amount Over 750,000 therms per bill ~ $0.53086 ** $0.33483**
The above prices include weighted average cost of gas of $0.35295
Includes temporary purchased gas cost adjustment of $0.16819 $ (0.02944)
**
Includes temporary purchased gas cost adjustment of $0.17130 $(0.02473)
PURCHASED GAS COST ADJUSTMENT (PGA):
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. All natural gas service hereunder is subject to the General ServiceProvisions 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, butnot limited to, the expiration of the contract term) will pay to Intermountain GasCompany, upon exiting the LV-1 service, all gas and/or interstate transportationrelated costs to serve the customer during the LV-1 contract period not borne bythe customer during the LV-1 contract period. Any LV-customer will haverefunded to them, upon exiting the LV-1 service, any excess gas and/or interstatetransportation related payments made by the customer during the LV-contractperiod.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 customerduring the current contract period used less than the contract minimum of 200,
000therms, an additional amount shall be billed. The additional amount shall becalculated by billing the deficit usage below 200,000 therms at the T-l Block 1rate. The customer'future eligibility for the LV-1 Rate Schedule will berenegotia ted wi th the Company.
Issued by: Intermountain Gas Company
By: Michael E. Huntington Title:Effective: JlIly 18, 2001 July 1 , 2002
Vice President - Marketing and External Affairs
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.
Twen €igAtR Ninth Revised Sheet No. 05
Name
of Utili
(Page 1 of 2
Intermountain Gas Compan
Exhibit NO.
Case No. INT-02-
Intermountain Gas Company
Page 7 of 8
IDAHO PUBLIC UTILITIES COMMISSIONAPPROVED EFFECTIVE
JUlH'81 .,"u" 16'81
\"",-
"'-.;1';;,\:~
~JfJ.g-tf SECRETARY.
Rate Schedule T-l
FIRM TRANSPORTATION SERVICE
AVAILABILITY:
Available at any mutually agreeable delivery point on the Company's distributionsystem to any existing customer receiving service under the Company s rate schedulesLV-1, T-1, or T-2, upon execution of a one year minimum written service contract forfi~ transportation service in excess of 200, 000 the~s per year.
MON'l'HLY RATE:
Commodi ty Charge:
All usage other than as feedstock in the production of ammonia:
Block One:First 250,000 the~s transported ~$9.12i82*$0.11848Block Two:Next 500,000 therms transported ~98633 $0.07999Block Three:Amount over 750,000 therms transported ~$0.01071Alltherms used as feedstock in the production of ammonia:$0.02525
*Includes temporary purchased gas cost adjustment of $(9.99281)$(0.00471)
PURCHASED GAS COST ADJUSTMEN'l':
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. All natural gas service hereunder is subject to the General Service provisions ofthe Company I s Tariff, of which this Rate Schedule is a part.
2. The customer shall negotiate a Maximum Daily Fi~ Quantity (MDFQ) amount, whichwill be stated in and will be in effect throughout the term of the servicecontract. The MDFQ shall not exceed the customer's historical maximum daily usage,as agreed to by the Company.
In the event the Customer requires daily usage in excess of the MDFQ, and subjectto the availability of fi~ interstate transportation to service Intermountain
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 predeterminedby negotiation between the Customer and Company, and shall be included in theservice contract. All volumes transported under the secondary rate schedule aresubject to the provisions of the applicable rate schedule T-3 or T-
Issued by: Intermountain Gas Company
By: Michael E. Huntington Title:
Effective: July 1 e , 2001 July 1 , 2002
Vice President - Marketing and External Affairs
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.
NiAtATenth Revised Sheet No.10 (Page 1 of 2)
Exhibit No.
Case No. INT-O2-
Intermountain Gas Company
Page 8 of 8
Name
of Utility Intermountain Gas Company
IDAHO PUBLIC UTiliTIES COMMISSIONAPPROVED EFFECTIVE
.jJLl6 '81 ~~L 16 '
~..... -",.
"'- OIo;;-,S~
'3-J!1~ SECRETARY
Rate Schedule T-
FIRM TRANSPORTATION SERVICE WITH MAXIMUM DAILY DEMANDS
AVAILABILITY:
Available at any mutually agreeable delivery point on the Company s distributionsystem to any existing T-2 customer whose daily contract demand for nonammonia theDms
on any given day meets or exceeds a predeteDmined level agreed to by the customer and
the Company upon execution of a one-year minimum written service contract for fiDmtransportation service in excess of 200,000 theDms per year.
MONTHLY RATE:
FiDm Service Rate Per TheDm
Demand Charge:
FiDm Daily Demand
First 15,000 theDms
Amount over 15,000 theDms
Commodi ty Charge:
For FiDm TheDms Transported
*Includes temporary purchased gas
Over-Run Service
$1.69887+$1.53849*
$9.89729+$0.73691*
$0.00656
cost adjustment of $(0.97129)$(0.09627)
Commodi ty Charge:
For TheDms Transported In Excess Of MDFQ:$0.04915
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. All natural gas service hereunder is subject to the GeneralProvisions of the Company s Tariff, of which this Rate Schedule is a part.Service
2. The customer shall nominate a Maximum Daily FiDm Quantity (MDFQ), which willbe stated in and will be in effect throughout the teDm of the service contract.
3. The monthly Demand Charge will be equal to the MDFQ times the FiDm DailyDemand rate. FiDm 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 iswar ran ted.
4. The actual theDm usage for the month or the MDFQ times the number of days in
the billing month, whichever is less, will be billed at the commodity charge for fiDmtheDms .
Issued by: Intermountain Gas Company
By: Michael E. Huntington
Effective: July 16, 2001 July 1 , 2002
Title: Vice President - Marketing and External Affairs
EXHIBIT NO.
CASE NO. INT -02-
INTERMOUNTAIN GAS COMPANY
PROPOSED TARIFFS
(7 pages)
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.
Thirty-Third Revised Sheet No. 01 (Page
Name
of Utility
1 of 1)
Exhibit No.
Case No. INT-O2-
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 billing periods ending April through November
Customer Charge - $2.50 per bill
Commodity Charge - $0.74157 per the~*
For billing periods ending December through March
Customer Charge - $6.50 per bill
Commodi ty Charge - $ 0 . 62901 per the~*
*Includes:
Temporary purchased gas cost adjustment of $ (0.03915)
Weighted average cost of gas of $0.35295
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 , 2002
Vice President - Marketing and External Affairs
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.
Thirty-Third Revised Sheet No.
Name
of Utility
02 (Page 1 of 1)
Intermountain Gas Company
Exhibit No.
Case No. INT-O2-
Intermountain Gas Company
Page 2 of 7
Rate Schedule RS-
MULTIPLE USE RESIDENTIAL SERVICE
AVAILABILITY:
Available to individually metered consumers using gas for
residential purposes including both water heating and space heating.
several
RATE:
Monthly minimum charge is the customer charge.
For billing periods ending April through November
Customer Charge - $2.50 per bill
Commodi ty Charge - $ 0 . 60993 per the~*
For billing periods ending December through March
Customer Charge - $6.per bill
Commodi ty Charge $ 0 . 57630 per the~*
*Includes:
Temporary purchased gas cost adjustment of $ (0.03839)
Weighted average cost of gas of $0.35295
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 I s Tariff, of which this rate schedule is a part.
Issued by: Intermountain Gas Company
By: Michael E. Huntington Title:
Effective: July 1 , 2002
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. 03
Name
of Utility
(Page 1 of 2)
Intermountain Gas Company
Exhibit No.
Case No. INT-O2-
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 2,000 the~s per day, at any point on Company's distributionsystem. Requirements in excess of 2, 000 the~s 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 billing periods ending April through November
Customer Charge - $2.00 per bill
Commodity Charge - First 200 the~s per bill ~ $0.63378*
Next 1,800 the~s per bill ~ $0.61205*
Over 2, 000 the~s per bill ~ $0.59103*
For billing periods ending December through March
Customer Charge - $9.50 per bill
Commodity Charge - First 200 the~s per bill ~ $0.58293*
Next 1, 800 the~s per bill ~ $0.56173*
Over 2,000 the~s per bill ~ $0.54127*
*Includes:
Temporary purchased gas cost adjustment of $ (0.03877)
Weighted average cost of gas of $0.35295
Issued by: Intermountain Gas Company
By: Michael E. Huntington Title:
Effective: July 1 , 2002
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. 03
Name
of Utility
(Page 2 of 2)
Intermountain Gas Company
Exhibit No.
Case No. INT-O2-
Intermountain Gas Company
Page 4 of 7
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
Commodi ty Charge - $ 0 .54127 per theDm*
*Includes:
Temporary purchased gas cost adjustment of $ (0.03877)
Weighted average cost of gas of $0.35295
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 InteDmountain
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-service, any excess gas
commodity or transportation payments made by the customer during the
time they were a GS-1 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 apart.
Issued by: Intermountain Gas Company
By: Michael E. Huntington Title:
Effective: July 1 , 2002
Vice President - Marketing and External Affairs
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.
Forty-Third Revised Sheet No. 04
Name
of Utili
(Page 1 of
Intermountain Gas Com pan
Exhibit No.
Case No. INT-O2-
Intermountain Gas Company
Page 5 of 7
Rate Schedule LV-
LARGE VOLUME FIRM SALES SERVICE
AVAILABILITY:
Available at any mutually agreeable delivery point on the Company '
distribution system to any existing customer receiving service under the Company
rate schedules LV-l, T-l, 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:
Commodi ty Charge:
First 250,000 therms per bill ~ $0.44260*Next 500,000 therms per bill ~ $0.40411*
Amount Over 750,000 therms per bill ~ $0.33483**
The above prices include weighted average cost of gas of $0.35295
Includes temporary purchased gas cost adjustment of $ (0.02944)
**
Includes temporary purchased gas cost adjustment of $ (0.02473)
PURCHASED GAS COST ADJUSTMENT (PGA):
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. 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-l customer who exits the LV-l 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-l service, all gas and/or interstate transportation
related costs to serve the customer during the LV-l contract period not borne bythe customer during the LV-contract period. Any LV-customer will have
refunded to them, upon exiting the LV-l service, any excess gas and/or interstate
transportation related payments made by the customer during the LV-l contractperiod.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-l Block 1rate. The customer future eligibility for the LV-l Rate Schedule will be
renegotiated wi th the Company.
Issued by: Intermountain Gas Company
By: Michael E. Huntington Title:
Effective: July 1 , 2002
Vice President - Marketing and External Affairs
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.Twenty Ninth Revised Sheet No. 05 (Page
Name
of UtilitY
1 of 2)
Intermountain Gas Company
Exhibit No.
Case No. INT-O2-
Intermountain Gas Company
Page 6 of 7
Rate Schedule T-
FIRM TRANSPORTATION SERVICE
AVAILABILITY:
Available at any mutually agreeable delivery point on the Company I s distribution
system to any existing customer receiving service under the Company s rate schedules
LV-1, T-1, 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:
Commodi ty Charge:
All usage other than as feedstock in the production of ammonia:Block One: First 250,000 therms transported ~ $0.11848*Block Two: Next 500,000 therms transported ~ $0.07999*
Block Three: Amount over 750,000 therms transported ~ $0.01071
All therms used as feedstock in the production of ammonia: ~ $0.02525
*Includes temporary purchased gas cost adjustment of $ (0.00471)
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for
in the Company I s Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
1. All natural gas service hereunder is subject to the General Service provisions of
the Company I s Tariff, of which this Rate Schedule is a part.
2. The customer shallwill be stated in
contract. The MDFQ
as agreed to by the
negotiate a Maximum Daily Firm Quantity (MDFQ) amount, which
and will be in effect throughout the term of the service
shall not exceed the customer s historical maximum daily usage,
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'
system, all such usage may be transported and billed under either secondary rateschedule T-3 or T-4. The secondary rate schedule to be used shall be predeterminedby 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-
Issued by: Intermountain Gas Company
By: Michael E. Huntington Title:
Effective: July 1 , 2002
Vice President - Marketing and External Affairs
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.Tenth Revised Sheet No.10 (Page 1 of 2)
Exhibit No.
Case No. INT-O2-
Intermountain Gas Company
Page 7 of 7
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 Rate Per Therm
Demand Charge:
Firm Daily Demand
First 15,000 therms
Amount over 15,000 therms
$1. 53849*
$0.73691*
Commodi ty Charge:For Firm Therms Transported $0.00656
*Includes temporary purchased gas cost adjustment of $(0.09627)
Over-Run Service
Commodi ty Charge:
For Therms Transported In Excess Of MDFQ:$0.04915
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. All natural gas service hereunder is subject to the Genera1
Provisions of the Company s Tariff, of which this Rate Schedule is a part.Service
2. The customer shall nominate a Maximum Daily Firm Quantity (MDFQ), which will
be stated in and will be in effect throughout the term of the service contract.
3. The month1y 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 iswarranted.
4. The actua1 therm usage for the month or the MDFQ times the number of days in
the billing month, whichever is less, wi11 be billed at the commodity charge for firm
therms .
Issued by: Intermountain Gas Company
By: Michael E. Huntington
Effective: July 1 , 2002
Title: Vice President - Marketing and External Affairs
EXHIBIT NO.
CASE NO. INT-02-
INTERMOUNTAIN GAS COMPANY
PERTINENT EXCERPTS FROM WILLIAMS FILINGS
(16 pages)
ExhibitNo.
Case No. INT-O2-
Intermountain Gas Company
Pa~~~.of 1.~
W ii/lams
GAS PIPELINE. WEST
295 Chipeta W~y (84108)
O, Box 58900
Salt Lake Cily. UT S4158.09oo
pnone: [phone]FAX: [phone]
January 23, 2002
TO: ALL HOLDERS OF NORTHWEST PIPELINE CORPORATION'
FERC GAS TARIFF, THIRD REVISED VOLUME NO.
Please insert the enclosed tariff sheets into your copy of Northwesfs FERC Gas Tariff
Third Revised Volume No.1. A brief description of the proceedings in which these tariff
sheets were accepted or are pending is provided below. Also, enclosed is a list of
Northwest's currently effective tariff sheets as of January 23, 2002.
Docket No. RP02-
On November 29, 2001 , Northwest filed the following tariff sheet to incorporate the new
GRI surcharges approved by the Commission for 2002. In an order dated December
, 2001 , the Commission accepted this sheet to be effective January 1, 2002.
Twenty-Second Revised Sheet No.
Docket No. RP02-116
On December 3, 2001 , Northwest filed tariff sheets to add a new rate schedule, Rate
Schedule DEX-, to Northwest's tariff for the deferred exchange of storage gas. This
rate schedule provides a mechanism for Northwest to increase the level of its system
balancing gas in a particular gas storage facility without using mainline capacity to
transport the gas from a storage facility connected to its system in a different
geographical area. In an order dated January 2, 2002, the Commission accepted thesheets filed on December 3 to be effective January 1 , 2002, subject to conditions. On
January 23 2002, Northwest filed revised tariff sheets to comply with the January 2
2002 order. These tariff sheets supersede certain sheets filed on December 3. Thus
the following tariff sheets were either accepted in the January 2 order or were filed onJanuary 23 and are currently pending Commission acceptance.
1 As discussed below , certain tariff sheets pending in Docket No. RPO2.116 are included in this
list.
All-Holders
January 23, 2002
Page 2 of 2
Substitute Eighth Revised Sheet No.6'"
Substitute Fifteenth Revised Sheet No. 14~
Fifth Revised Sheet No. 15
Substitute Second Revised Sheet No. 115*
Substitute Second Revised Sheet No. 116*
Substitute Third Revised Sheet No. 117"
Substitute Second Revised Sheet No. 118*
First Revised Sheet No. 119
Eighth Revised Sheet No. 200
Third Revised Sheet No. 215
Exhibit No.
Case No. INT-O2-
Intermountain Gas Company
Page 2 of 16
Substitute Eighth Revised Sheet No. 231 *
Seventh Revised Sheet No. 231-
Third Revised Sheet No. 231-
Fifth Revised Sheet No. 245
Fourth Revised Sheet No. 303-
Substitute Original Sheet No. 359*
Substitute Third Revised Sheet No. 360*
Second Revised Sheet No. 361
First Revised Sheet No. 362
These tariff sheets are designated as pending on the enclosed tariff sheets.
Other Information
If you have questions concerning Northwest's regulatory issues , please call me or anyof the other individuals listed below:
Billie Tolman
John Woolf
Toni Sharp
Gary Kotter
Bruce Warner
Barbara Odland
Manager, Tariffs & Regulatory Analysis
Sr. Regulatory Analyst
Sr. Regulatory Analyst
Manager, Certificates
Manager, Rates and Planning
Office Administrator
[phone]
[phone]
[phone]
[phone]
[phone]
[phone]
Northwest publishes FERCWatch to provide customers with information on Northwest'
current and pending filings. It can be viewed on Northwest's EBB and Internet web site.
You may also view Northwest's tariff on its Internet web site at www.1Iine.williams.com.
Sincerely,
(;.
4J*t
John A. Woolf
AJiholdO1 2302voI1 doc
TF01013800083099NORTHWEST PIPELINE CORPORATIONTF021 3Third Revised Volume No.TF030 00000P126 Sheet No. 0
TF04
TF05Larry Larsen, Vice President
TF06083099
TF07
Exhibit No.
Case No. INT-O2-
Intermountain Gas Company
Page 3 of 16
100199
FERC GAS TARIFF
THIRD REVISED VOLUME NO.
(Superseding Second Revised Volume No.1 and
First Revised Volume No.1-A)
NORTHWEST PIPELINE CORPORATION
Filed with
FEDERAL ENERGY REGULATORY COMMISSION
Communications concerning this Tariff should be sent to:
Larry E. Larsen , Vice President, Customer Services and Rates Northwest
Pipeline Corporation
295 Chipeta Way (84108)
O. Box 58900
Salt Lake City, Utah 84158-0900
Telephone:
Facsimile:
[phone]
[phone]
TF0301
TF04
TF05Larry E.
TF06011802
TF07
060001P126Sixth Revised Sheet No.
Fifth Revised Sheet No.
Larsen, Vice President
021802
RATE SCHEDULES
Table of Contents
Map
Preliminary Statement
Statement of Rates
Fuel Use Requirements Factors
Rate Schedules - Index
TF-
TI-
SGS-
SGS-
LS-
LS-
LS-
TF-
Firm Transportation
Interruptible Transportation
Storage Gas Service - Firm
Storage Gas Service - Interruptible
Liquefaction-Storage Gas Service
Liquefaction-Storage Gas Service -Liquefaction-Storage Gas Service -
Firm Redelivery Transportation
FirmInterruptible
General Terms and Conditions - Index
Forms of Service Agreements
Non-Conforming Service Agreements
Negotiated Rate Service Agreements
Original Volume No.
Exhibit No.
Case No. INT-O2-
Intermountain Gas Company
Page 4 of 16
Sheet No.
100
200
304
363
370
An index of special rate schedules consisting of individual service
agreements between Northwest and various Shippers is included in Northwest'
FERC Gas Tariff, Original Volume No.
TF0302 000002P1260riginal Sheet No.
TF04
TF05Laren M. Gertsch, DirectorTF06101893 110193
Exhibit No.
Case No. INT-O2-
Intermountain Gas Company
Page 5 of 16
PRELIMINARY STATEMENT RELATED
TO FERC GAS TARIFF, THIRD REVISED VOLUME NO.
CONTAINING TRANSPORTATION AND STORAGE RATE SCHEDULES
Northwest Pipeline Corporation ("Northwest" or Transporter ) is a
natural gas company" as defined by the Natural Gas Act and "an interstatepipeline" as defined by the Natural Gas Policy Act of 1978. As such,
Northwest is subj ect to the jurisdiction of the Federal Energy Regulatory
Commission. Northwest is engaged in the transportation (the term
transportation, as defined herein , includes storage service), in interstate
commerce, of natural gas for Shippers, pursuant to the regulations of the
Federal Energy Regulatory Commission.
The maj or facilities of Northwest are depicted on the map constituting
Sheet No.4 of this Tariff. Northwest's pipeline system extends from a point
near Blanco, New Mexico, through the states of Colorado, Utah, Wyoming,
Idaho, Oregon and Washington to a point on the International Boundary near
Sumas, Washington.
This Tariff contains transportation and storage rate schedules
available for Shippers with whom Northwest contracts through executed Service
Agreements for the transportation and storage of natural gas. It is the
policy of Northwest to undertake the transportation and storage of gas only
pursuant to written contracts with eligible customers upon the terms and
conditions set forth in this Tariff, executed on a non-discriminatory basis
after consideration of Northwest's existing commitments, delivery capacity,points of deli very and other relevant factors.
This FERC Gas Tariff is filed in compliance with Part 154, Subchapter
E, Chapter I, Title 18 of the Code of Federal Regulations, as promulgated by
Order of the Federal Power Commission in Docket No. R-I07, dated October 30,
1948.
TF0303 000010P126Sheet No.
TF04
TF05Laren M. Gertsch , DirectorTF06101893
Exhibit No.
Case No. INT-O2-
Intermountain Gas Company
Page 6 of 16
110193
RESERVED FOR FUTURE USE
TF0304 10009P126First Revised SheetTF04 Original Sheet No.
TF05Larry E. Larsen, Vice President
TFO 61 0 10 97 0 925 97RP97 -315
TF078061361
No.
Exhibit No.
Case No. INT-02-
Intermountain Gas Company
Page 7 of 16
060197
System Map
TF0305 0220003P158Twenty-Second Revised SheetTF04 Twenty-First Revised Sheet No.
TF05Larry Larsen, Vice President
TF06112901
TF07
No.
Exhibit No.
Case No. INT-O2-
Intermountain Gas Company
Page 8 of 16
010102
STATEMENT OF RATES
Effective Rates Applicable to Rate Schedules TF-1 , TF-2 and TI-
(Dollars per Dth)
Rate Schedule and
Type of Rate
Base
Tariff Rate
Minimum Maximum
Currently
Effecti ve
Tariff Rate (3)
ACA (2) Minimum MaximumGRI (1)
Rate Schedule TF-(4) (5)
Reservation
(Large Customer)
High Load Factor
Low Load Factor
Volumetric
(Large Customer)
(Small Customer)( 6)
00000 27760 00217 00000 27977
00000 27760 00134 00000 27894
01225 03000 00550 00210 01435 03760
01225 58521 00880 00210 01435 59611
01225 30760 00550 00210 01435 31520Scheduled Overrun
Rate Schedule TF-(4) (5)
Reservation 00000 27760 00000 27760
Volumetric 01225 03000 01225 03000
Scheduled Daily Overrun 01225 30760 01225 30760
Annual Overrun 01225 30760 01225 30760
Rate Schedule TI-1
Volumetric (7)01225 30760 00550 00210 01435 31520
Scheduled Overrun 01225 30760 00550 00210 01435 31520
TF0305-A
TF04
TF05Larry Larsen,
TF06120100
TF07
0160003P158Sixteenth Revised Sheet No. 5-A
Fifteenth Revised Sheet No. 5-A
Vice President
Exhibit No.
Case No. INT-O2-
Intermountain Gas Company
Page 9 of 16
010101
STATEMENT OF RATES (Continued)
Effective Rates Applicable to Rate Schedules TF-1, TF-2 and TI-1 (Continued)
(Dollars per Dth)
Unauthorized Overrun and Underrun (8)Rate
Unauthorized Daily Overrun
At least the Threshold Percentage; but
less than the Threshold Percentage plus 2%00000
The Threshold Percentage plus 2% or more 10.00000
Unauthorized Daily Underrun
At least 5%; but less than 10%00000
10% or more 10.00000
Unauthorized Underrun Imbalances
not eliminated after 72 hours 10.00000
Footnotes
(1) Section 13 of the General Terms and Conditions describes the basis and
app 1 i cabi 1 i ty of the GRI Adj ustment surcharges.
(2) Section 16 of the General Terms and Conditions describes the basis and
applicability of the ACA surcharge.
TF0305-B
TF04
TF05Larry Larsen,
TF06120100
TF07
0020003P158Second Revised Sheet No. 5-B
First Revised Sheet No. 5-BVice President
Exhibit No.
Case No. INT-02-
Intermountain Gas Company
Page 10 of 16
010101
STATEMENT OF RATES (Continued)
Effective Rates Applicable to Rate Schedules TF-1, TF-2 and TI-1 (Continued)
(Dollars per Dth)
Footnotes (Continued)
(3)The currently effective tariff rate is
and the applicable surcharges. To the
the maximum currently effective tariff
applied on a non-discriminatory basis,Order No. 497.
the sum of the base tariff rate
extent Transporter discounts
rate, such discounts will be
subj ect to the policies of
Shippers receiving service under these rate schedules are required to
furnish fuel reimbursement in-kind at the rates specified on Sheet
No. 14.
A "Facility Cost-of-Service Charge," as defined in Section 21 of the
General Terms and Conditions, is payable in addition to all other
rates and charges if such a charge is included in Exhibit C to a
Shpper s Transportation Service Agreement.
In addition to the reservation rates and surcharges shown on Sheet
No.5, Shippers who contract for Columbia Gorge Expansion Project
capaci ty are subj ect to a Facilities Reservation Surcharge pursuant toSection 3.4 of Rate Schedule TF-1. The Facilities Charge used in
deriving the Columbia Gorge Expansion Project Facilities Reservation
Surcharge has a minimum rate of $0 and a maximum rate as follows
(rates become effective November 1 of the year prior to the stated
year and continue through October 31 of the stated year, except the
Facilities Charge effective November 1, 2023 continues through March
, 2025):
Year Rate Year Rate Year Rate
2000 $0.23127 2008 $0.17068 2016 $0.11600
2001 $0.22533 2009 $0.16411 2017 $0.11221
2002 $0.21642 2010 $0.15706 2018 $0.10823
2003 $0.20800 2011 $0.15002 2019 $0.10425
2004 $0.19948 2012 $0.14259 2020 $0.09999
2005 $0.19245 2013 $0.13593 2021 $0.09628
2006 $0.18523 2014 $0.12889 2022 $0.09230
2007 $0.17819 2015 $0.12185 2023 $0.08832
2024 $0.08411
TF0305 - C
TF04
TF05Larry Larsen,
TF06120100
TF07
0000003P1580ri gi na 1 Sheet No. 5-
Exhibit No.
Case No. INT-O2-
Intermountain Gas Company
Page 11 of 16
Vice President
010101
STATEMENT OF RATES (Continued)
Effective Rates Applicable to Rate Schedules TF-1, TF-2 and TI-(Continued)
(Dollars per Dth)
Footnotes (Continued)
(4) All reservation rates are dai ly rates computed on the basis of 365
days per year. except that such rates for 1 eap years are computed on the
basis of 366 days.
Rate Schedules TF-1 (Large Customer) and TF-2 maximum base tariff
reservat i on rates are compri sed of $0.27193 for transmi ss i on costs and
$0.00567 for storage costs. and maxi mum base tari ff vol umetri c rates are
compri sed of $0.02966 for transmi ss i on costs and $0.00034 for storage costs.
(5) Rates for Rate Schedules TF-1 and TF-2 are also applicable to
capacity release service. (Section 22 of the General Terms and Conditions
descri bes how bi ds for capaci ty release wi 11 be evaluated.The reservation
rate is the comparable volumetric bid reservation charge applicable to
Rep 1 acement Shi ppers bi ddi ng for capaci ty released on a one- part vol umetri c
bi d bas is. For the peri ad from March 27. 2000 through September 30. 2002
the maxi mum reservation rates do not apply to capaci ty release transactions
of less than one (1) year.
(6) Rate Schedule TF-1 (Small Customer) one-part volumetric
rate is based upon a 50% load factor, and the maximum base
tariff rate is comprised of $0.57353 for transmission costs and
$0.01168 for storage costs. Transporter will not transport gas
for delivery for Small Customers subj ect to this Rate Schedule
TF-1 under any interruptible Service Agreement or under any
capacity release Service Agreement unless such Small Customer
has exhausted its daily levels of firm service entitlement for
that day.
(7) Rate Schedule T1-1 maximum base tariff volumetric rate is comprised
of $0.30159 for transmi ssi on costs and $0.00601 for storage costs.
(8) Applicable to Rate Schedules TF-1, TF-2 and TI-1 pursuant
to Section 15.5 of the General Terms and Conditions.
TF036 080003P126Sub Eighth RevisedTF04 Seventh Revised Sheet
TF05Larry Larsen, Vice President
TFO 6012 302 0102 02RP02-116-00 0
TF079861002
Sheet No.
No.
Exhibit No.
Case No. INT-O2-
Intermountain Gas Company
Page 12 of 16
010102
STATEMENT OF RATES (Continued)
Effective Rates Applicable to Rate Schedule DEX-1
(Dollars per Dth)
Base
Tariff Rate
Currently
Effecti veTariff
Ra t e ( 3 )
Type of Rate
Maximum
Minimum Maximum GRI (1)ACA ( 2) Minimum
Deferred Exchange 0000 30760 00550 00210 00210 31520
Footnotes
(1 )Section 13 of the General Terms and Conditions describes the basis and
applicabili ty of the GRI Adj ustment surcharges.
(2)Section 16 of the General Terms and Conditions describes the basis and
app1icabili ty of the ACA surcharge.
(3)The currently effective tariff rate is
and the applicable surcharges. To the
the maximum currently effective tariff
applied on a non-discriminatory basis,
Order No.4 97.
the sum of the base tariff rate
extent Transporter discounts
rate, such discounts will be
subj ect to the policies of
Shippers receiving service under this rate schedule are required to
furnish fuel reimbursement in-kind at the rates specified on Sheet
No. 14, except as provided in Section 4 of Rate Schedule DEX-
PENDING COMMISSION ACCEPTANCE
TF0307
TF04
TF05Larry Larsen,
TF06120100
TF07
110003P128E1eventh Revised Sheet No.
Tenth Revised Sheet No.Vice President
Exhibit No.
Case No. INT-O2-
Intermountain Gas Company
Page 13 of 16
010101
STATEMENT OF RATES (Continued)
Effective Rates Applicable to Rate Schedules SGS-2F and SGS-
(Dollars per Dth)
Rate Schedule and
Type of Rate
Currently EffectiveTariff Rate (1)
Minimum Maximum
Rate Schedule SGS-2F (2)
Demand Charge
Capaci ty Demand Charge
00000
00000
01689
00062
Volumetric Bid Rates
Wi thdrawal Charge
Storage Charge
00000
00000
01689
00062
Rate Schedule SGS-
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 computed 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 of
the 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 released
on a one-part volumetric bid basis. For the period from March 27
2000 through September 30, 2002 , the maximum rates do not apply to
capaci ty release transactions of less than one (1) year.
TF0308
TF04
TF05Larry Larsen,
TF06120100
TF07
0140003P126Fourteenth Revised Sheet No.
Thirteenth Revised Sheet No.Vice President
Exhibit No.
Case No. INT-O2-
Intermountain Gas Company
Page 14 of 16
010101
STATEMENT OF RATES (Continued)
Effective Rates Applicable to Rate Schedule LS-
(Dollars per Dth)
Type of Rate
Currently EffectiveTariff Rate (1)
Demand Charge (2)
Capaci t y Charge (2)
02600
00332
Liquefaction
Vaporization
55685
03030
Footnotes
(1 )Shippers receiving service 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 computed on the basis of 365 days per year,
except that rates for leap years are computed on the basis of 366
days.
TF038 . 1
TF04
TF05Larry Larsen,
TF06120100
TF07
110003P128Eleventh Revised Sheet No. 8.
Sub Tenth Revised Sheet No.8. 1Vice President
Exhibit No.
Case No. INT-O2-
Intermountain Gas Company
Page 15 of 16
010101
STATEMENT OF RATES (Continued)
Effective Rates Applicable to Rate Schedules LS-2F and LS-
(Dollars per Dth)
Rate Schedule and
Type of Rate
Currently EffectiveTariff Rate (1)
Minimum Maximum
Rate Schedule LS-2F (3)
Demand Charge (2)
Capaci ty Demand Charge (2)
Liquefaction
Vaporization
00000 02600
00000 00332
00000 02600
00000 00332
55685 55685
03030 03030
Volumetric Bid Rates
Vaporization Demand-Related Charge (2)
Storage Capaci t y Charge (2)
Rate Schedule LS-
Volumetric 00161 00826
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 computed on the basis of 365 days per year,
except that rates for leap years are computed on the basis of 366
days.
(3)Rates are also applicable to capacity release service. (Section 22 of
the General Terms and Conditions describes how bids for capacity
release will be evaluated.The Vaporization Demand-Related Charge
and Storage Capacity Charge are applicable to Replacement Shippers
bidding for capacity released on a one-part volumetric bid basis. For
the period from March 27, 2000 through September 30, 2002, the maximum
rates do not apply to capacity release transactions of less than one
(1) year.
TF0309 020003P126Second Revised SheetTF04 First Revised Sheet No.
TF05Larry Larsen, Vice President
TFO 60 4 0300021100RP93-034
TF07 90 6114 6
No.
Exhibit No.
Case No. INT-O2-
Intermountain Gas Company
Page 16 of 16
060100
DOCKET NOS. RP93-5 AND RP93-96 SURCHARGE COLLECTION PLAN
On April 3, 2000, Transporter filed tariff sheets with the Commission
reflecting revised rates in Docket Nos. RP93-5 and RP93-96 applicable to the
period from April 1, 1993, to October 31 , 1994. The filing reflects
additional amounts, including applicable interest, owed by Shippers to
Transporter. The filing outlined the following surcharge collection plan.
Option 1. Payment to Transporter in a lump sum (Lump Sum Option)
Option 2.Offset of Docket No. RP95-409 general rate case refund due
Shipper, if any, with amounts owed Transporter in Docket
Nos. RP93-5 and RP93-96 (Offset Option). This Offset Option
is only available to parties who were Shippers during the
Docket No. RP95-409 effective period (February 1, 1996 hrough
February 28, 1997).
Option 3.Payment to Transporter over a period of time, which will
extend no longer than one year from the first payment duedate (Time Payment Option). The Time Payment Option is
available only to Shippers maintaining a currently effective
Service Agreement at the effective date of the surcharge.
Upon the Commission s acceptance of Transporter s surcharge collection
plan, Transporter will request Shippers to elect one of the above surcharge
collection options. Within 45 days of Commission authorization (Transporter
has requested Commission authorization prior to July 1, 2000), Transporter
will send invoices to Shippers electing Option 1 or Option 3. Any Shipper
failing to make an election will be deemed to have elected Option
Any Shipper electing Option 2 will not be billed at the time of the
ini tial billing to Shippers electing Option 1 or Option 3. At the point
Transporter becomes obligated to make Docket No. RP95-409 refunds (Refund
Obligation Date), the amount owing in Docket Nos. RP93-5 and RP93-96,
inclusive of interest accrued up to the Refund Obligation Date, will be
offset with the Docket No. RP95-409 refund. Any balance still owed
Transporter in Docket Nos. RP93-5 and RP93-96, after the offset, will be
billed immediately following the offset. This amount, along with accrued
interest on any unpaid balance, will be due within 30 days after the offset.
Any remaining amount due the Shipper after the offset, along with accrued
interest, will be refunded to the Shipper in the ordinary course of the
Docket No. RP95-409 refund. Interest will be computed through any and all
payment due dates or offset date in accordance with Section 154.501 (d) of
the Commission s regulations. Thirty days after the last payment is due
under the surcharge collection options described above, Transporter will
file a final surcharge report with the Commission detailing by Shipper the
payments received by Transporter and any amounts offset against refunds due
in Docket No. RP95-409.
EXIllBIT NOS. 4-
CASE NO. INT-G-O2-
INTERMOUNTAIN GAS COMPANY
(12 pages)
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(a
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(b
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9
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r
t
h
w
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t

P
i
p
e
l
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n
e

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e
f
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d

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o
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o
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t

P
i
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o
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3
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1
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t
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n

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t
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t

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1
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c
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1
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p
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4

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T

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l
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RS
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GS
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(b
)
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(d
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(e
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(f
)
(g
)
(2
,
38
5
,
55
1
)
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5
3
,
99
6
)
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8
5
,
84
9
)
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5
,
7
0
6
)
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$
(2
)
35
,
61
6
03
4
12
3
32
0
07
4
52
1
86
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10
6
,
54
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84
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01
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5
5
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00
6
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7
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01
1
3
0
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en

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s
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r
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i
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n
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)
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r
t
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w
e
s
t

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p
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l
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n
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r
c
h
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r
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o
c
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o
.

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9
3
-
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m
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l
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z
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d

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a
l
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1
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1
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d

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c
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t

P
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r

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h
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m
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p
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r

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o
.
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i
n
e

1
0
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h
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r
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a
m
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p
p
l
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t
o

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1,

T
-
, T
-
,
a
n
d

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u
s
t
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m
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r

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i
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s
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T
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M
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A
I
N

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M
P
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N
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r
t
h
w
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s
t

P
i
p
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l
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n
e

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o
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k
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t

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o
.

R
P
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3
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S
T

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F

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C
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L
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A
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(1
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To
t
a
l
RS
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RS
-
GS
-
(b
)
(c
)
(d
)
(e
)
(f
)
(g
)
89
5
,
20
2
15
8
,
52
5
38
9
39
2
34
7
28
5
-
(
2
)

$
-
(
2
)
61
6
03
4
12
3
,
32
0
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4
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,
52
1
86
3
40
,
10
6
,
54
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o
p
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s
e
d

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e
m
p
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r
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o
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n
e

3
0
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2
0
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2
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.
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s
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p
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n
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l
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n
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e
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)
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)
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)
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)
(g
)
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x
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d

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t
s
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o
m

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c
t
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)
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08
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d

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s
t

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o
l
l
e
c
t
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n

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d
j
u
s
t
m
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t

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c
e
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.

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8
6
0
.
22
0
0
)
52
8
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5
,
7
8
5
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9
52
7
)
34
3
97
5
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7
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0
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4
2
9
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i
t

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e
e

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e
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1
0
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0
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58
7
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4
3
0
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,
72
4
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50
1
)
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4
8
)
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8
4
)
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e
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e

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e
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r
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l

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e
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5
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2
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4
82
2
)
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8
39
7
)
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,
93
0
)
(9
6
9
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Exhibit No. 12
Case No. INT-O2-
Intermountain Gas Company
INTERMOUNTAIN GAS COMPANY Page 1 of
Proposed Temporary Surcharges (Credits). Variable Costs
Line
No.Description
(a)
Amount
(b)
Account 1860 Amounts Which Apply to RS., RS.2, GS., and L V.
Account 1860 Variable Costs 470,959
Normalized Sales/CD Vols. (10/1/00 - 9/30/01)254 583 811
Proposed Temporary Surcharge (Credit)00185
Variable Gas Costs
Normalized Sales/CD Vols. (10/1/00 - 9/30/01)
Proposed Temporary Surcharge (Credit)
$ (6 766 014)
254 583,811
$ (0.02658)
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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]DATE May 23 2002
TODAY, INTERMOUNTAIN GAS COMPANY ("INTERMOUNTAIN ) FILED ITS ANNUAL NATURAL GAS PURCHASE COST REVIEW
APPLICATION WITH THE IDAHO PUBLIC UTILITIES COMMISSION ("IPUC"). THIS TYPE OF APPLICATION IS FILED EACH YEAR AT THIS
TIME TO PROVIDE THE IPUC WITH A REVIEW MECHANISM THAT HELPS INSURE THAT THE NATURAL GAS COSTS THAT
INTERMOUNTAIN IS INCURRING ON BEHALF OF ITS CUSTOMERS ARE PROPER AND ARE REFLECTED IN ITS SALES PRICE.
THE APPLICATION REQUESTS THE NECESSARY AUTHORIZATION TO DECREASE PRICES ON AVERAGE BY 24%.
THIS APPLICATION REFLECTS THE LOWER PRICES THAT INTERMOUNTAIN HAS BEEN PAYING SINCE ITS LAST ADJUSTMENT
ONE YEAR AGO. THE DECREASE ALSO REFLECTS THE FACT THAT ALL PREVIOUS COSTS DEFERRED DURING THE RECENT PERIOD OF
UNUSUALLY HIGH ENERGY PRICES HAVE NOW BEEN RECOVERED.
WILLIAM C. "BILL" GLYNN, PRESIDENT OF INTERMOUNTAIN GAS COMPANY, SAID, "THE FUNDAMENTAL LAW OF SUPPLY
AND DEMAND IS WORKING IN THE MARKETPLACE AND HAS PROVIDED THIS OPPORTUNITY TO PASS LOWER NATURAL GAS COSTS ON
TO OUR CUSTOMERS.THIS PRICE DECREASE IS WELCOME NEWS COMPARED TO THE HIGH PRICES THAT WE HAVE ALL
EXPERIENCED OVER THE PAST TWO YEARS AND WILL PROVIDE OUR CUSTOMERS WITH MORE DISPOSABLE INCOME FOR OTHER
GOODS AND SERVICES, FURTHER STRENGTHENING THE STATE AND NATIONAL ECONOMIC RECOVERY"
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 NEARLY 20 YEARS. THEREFORE THE COMPANY
EARNINGS WILL NOT CHANGE AS A RESULT OF THE PROPOSED PRICE DECREASES.
INTERMOUNTAIN CONTINUES TO ENCOURAGE ALL ITS CUSTOMERS TO BE CONSCIOUS OF THEIR ENERGY USAGE AND THE
WISE USE OF ENERGY AS WELL. THE COMPANY WILL CONTINUE TO PROVIDE HELPFUL TIPS ON WAYS TO CONSERVE AND USE
ENERGY WISELY THROUGH ITS BILL INSERTS AND ON ITS WEB SITE (www.intqas.com
IF THIS PROPOSED DECREASE IS APPROVED, RESIDENTIAL CUSTOMERS USING NATURAL GAS FOR HEATING AND WATER
HEATING COULD EXPERIENCE AN AVERAGE ANNUAL DECREASE OF $188 (24.2%). THOSE RESIDENTIAL CUSTOMERS USING
NATURAL GAS FOR SPACE HEATING ONLY COULD EXPERIENCE AN AVERAGE ANNUAL DECREASE OF $128 (21.8%). COMMERCIAL
CUSTOMERS COULD EXPERIENCE AN AVERAGE ANNUAL DECREASE OF $795 (25.6%).
IF APPROVED AS FILED, THE TOTAL NET REVENUE DECREASE FROM THIS CURRENT REQUEST WILL BE APPROXIMATELY
$52.5 MILLION (24.0%) AND IS PROPOSED TO BE EFFECTIVE JULY 1 , 2002. A COpy OF INTERMOUNTAIN'S APPLICATION IS
AVAILABLE FOR PUBLIC REVIEW AT THE COMPANY'S OFFICES AND ON ITS WEB SITE.
EXECUTIVE OFFICES
INTERMOUNTAIN GAS COMPANY
555 SOUTH COLE ROAD. P.O. BOX 7608 . BOISE, IDAHO 83707 . [phone] . FAX: [phone]
CUSTOMER NOTICE
DATE May 23,2002
Contact: Mike Huntington
Vice President
Marketing & External Affairs
[phone]
TODAY, INTERMOUNTAIN GAS COMPANY ("INTERMOUNTAIN") FILED ITS ANNUAL NATURAL GAS PURCHASE COST REVIEW
APPLICATION WITH THE IDAHO PUBLIC UTILITIES COMMISSION ("IPUC"). THIS TYPE OF APPLICATION IS FILED EACH YEAR AT THIS
TIME TO PROVIDE THE IPUC WITH A REVIEW MECHANISM THAT HELPS INSURE THAT THE NATURAL GAS COSTS THAT
INTERMOUNTAIN IS INCURRING ON BEHALF OF ITS CUSTOMERS ARE PROPER AND ARE REFLECTED IN ITS SALES PRICE.
THE APPLICATION REQUESTS THE NECESSARY AUTHORIZATION TO DECREASE PRICES ON AVERAGE BY 24%.
THIS APPLICATION REFLECTS THE LOWER PRICES THAT INTERMOUNTAIN HAS BEEN PAYING SINCE ITS LAST ADJUSTMENT
ONE YEAR AGO. THE DECREASE ALSO REFLECTS THE FACT THAT ALL PREVIOUS COSTS DEFERRED DURING THE RECENT PERIOD OF
UNUSUALLY HIGH ENERGY PRICES HAVE NOW BEEN RECOVERED.
WILLIAM C. "BILL" GLYNN , PRESIDENT OF INTERMOUNTAIN GAS COMPANY, SAID
, "
THE FUNDAMENTAL LAW OF SUPPLY
AND DEMAND IS WORKING IN THE MARKETPLACE AND HAS PROVIDED THIS OPPORTUNITY TO PASS LOWER NATURAL GAS COSTS ON
TO OUR CUSTOMERS.THIS PRICE DECREASE IS WELCOME NEWS COMPARED TO THE HIGH PRICES THAT WE HAVE ALL
EXPERIENCED OVER THE PAST TWO YEARS AND WILL PROVIDE OUR CUSTOMERS WITH MORE DISPOSABLE INCOME FOR OTHER
GOODS AND SERVICES, FURTHER STRENGTHENING THE STATE AND NATIONAL ECONOMIC RECOVERY"
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 NEARLY 20 YEARS. THEREFORE THE COMPANY'
EARNINGS WILL NOT CHANGE AS A RESULT OF THE PROPOSED PRICE DECREASES.
INTERMOUNTAIN CONTINUES TO ENCOURAGE ALL ITS CUSTOMERS TO BE CONSCIOUS OF THEIR ENERGY USAGE AND THE
WISE USE OF ENERGY AS WELL. THE COMPANY WILL CONTINUE TO PROVIDE HELPFUL TIPS ON WAYS TO CONSERVE AND USE
ENERGY WISELY THROUGH ITS BILL INSERTS AND ON ITS WEB SITE (www.intqas.com
IF THIS PROPOSED DECREASE IS APPROVED, RESIDENTIAL CUSTOMERS USING NATURAL GAS FOR HEATING AND WATER
HEATING COULD EXPERIENCE AN AVERAGE ANNUAL DECREASE OF $188 (24.2%). THOSE RESIDENTIAL CUSTOMERS USING
NATURAL GAS FOR SPACE HEATING ONLY COULD EXPERIENCE AN AVERAGE ANNUAL DECREASE OF $128 (21.8%). COMMERCIAL
CUSTOMERS COULD EXPERIENCE AN AVERAGE ANNUAL DECREASE OF $795 (25.6%).
IF APPROVED AS FILED, THE TOTAL NET REVENUE DECREASE FROM THIS CURRENT REQUEST WILL BE APPROXIMATELY
$52.5 MILLION (24.0%) AND IS PROPOSED TO BE EFFECTIVE JULY 1, 2002. A COpy OF INTERMOUNTAIN'S APPLICATION IS
AVAILABLE FOR PUBLIC REVIEW AT THE COMPANY'S OFFICES AND ON ITS WEB SITE.
WORKP APER NOS. 1-
CASE NO. INT -G-O2-
INTERMOUNTAIN GAS COMPANY
(8 pages)
Workpaper No.
Case No. INT-O2-
Intermountain Gas Company
Page 1 of
Intermountain Gas Company
Northwest Pipeline TF-1 Discounted Demand Workpaper
Line INT-01-INT-01-INT-01-
No.Trans ortation Annual Therms Prices Annual Cost
(a)(b)(c)(d)
TF-1 Demand 1 Shipper #1 600 000 01627 1,425 252
TF-1 Demand 1 Shipper #2 28,470,000 01683 479,150
TF-1 Demand 1 Shipper #3 404,400 01375 404 311
TF-1 Demand 1 Shipper#4 450,000 13987 512 940
Total Annual Cost 145 924,400 01934 821 653
INT -02-INT-02-INT -02-
Trans ortation Annual Therms Prices Annual Cost
TF-1 Demand 1 Shipper #1 600,000 01623 1,421 748
TF-1 Demand 1 Shipper #2 28,470,000 01679 478,011
TF-1 Demand 1 Shipper #3 29,404,400 01371 403,134
TF-1 Demand 1 Shipper #4 150 000 13987 170,980
Total Annual Cost 145 624,400 01699 473 873
Total Annual Cost Difference 347 780 (1)
(1) See Exhibit 4, Line 4, Column (h)
Workpaper No.
Case No. INT-O2-
Intermountain Gas Company
Page 1 of 1
Intermountain Gas Company
Upstream Capacity Workpaper
Line INT-01-INT-01-INT-01-
No.Trans ortation Annual Therms Prices Annual Cost
(a)(b)(c)(d)
Upstream Capacity #1 206 118 920 01069 203 115
Upstream Capacity #2 166,568,630 00508 845,991
Upstream Capacity #3 155 025 220 01642 545 781
Total Upstream Capacity 527,712 770 01060 594 887
INT-02-INT-02-INT-02-
Trans ortation Annual Therms Prices Annual Cost
Upstream Capacity #1 181 258,720 01067 934 483
Upstream Capacity #2 138,819,721 00466 647,497
Upstream Capacity #3 155,025,220 01642 545,358
Total Upstream Capacity 475,103,661 01079 127 338
Total Annual Cost Difference (467,549) (1)
(1) See Exhibit 4, Line 5, Column (h)
Workpaper No.
Case No. INT-O2-
Intermountain Gas Company
Page 1 of
Intermountain Gas Company
Other Peaking Facilities
Line INT-01-
Monthly INT-G-O1-INT-01-INT-01-
No.Peakin Facilities Billinq Determinant Prices Monthlv Cost Annual Cost
(a)(b)(c)(d)(d)
Demand Costs.
Clay Basin I Demand 266 250 (1)28534 971 911 655
Clay Basin 11 Demand 221 880 (1)28534 311 759 730
Clay Basin I Capacity 950,000 (2)00238 977 911 725
Clay Basin 11 Capacity 625 000 (2)00238 314 759 771
AECO I Demand 530 350 (2)00162 825 165 900
AECO II Demand 064 970 (2)00107 964 335,562
Total Demand Costs 170 320 (3)320 362 844 343
Cycling Costs -
Clay Basin Cycling Costs 575 000 00089 148 625 778
AECO Cycling Costs 595,320 00057 674 236 084
Total Cycling Costs 170,320 822 861 862
Storage Credit 491,463
Total Costs including storage credit 214 742
INT-02-
Monthly INT-02-INT-02-INT-02-
Peakin Facilities Billinq Determinant Prices Monthlv Cost Annual Cost
Demand Costs.
Clay Basin I Demand 266 250 (1)28534 75,971 911 655
Clay Basin II Demand 221 880 (1)28534 311 759 730
Clay Basin I Capacity 950 000 (2)00238 977 911 725
Clay Basin 11 Capacity 625 000 (2)00238 314 759 771
AECO I Demand 530 350 (2)00159 576 162 912
AECO 11 Demand 064 970 (2)00108 28,137 337 644
Total Demand Costs 170 320 (3)320 286 843,437
Cycling Costs.
Clay Basin Cycling Costs 575 000 00064 526 450 308
AECO Cycling Costs 595 320 00070 107 289 286
Total Cycling Costs 170 320 633 739 594
Storage Credit 489 000
Total Costs including storage credit 094 031
Total Annual Cost Difference including Storage Credit 120 711 (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-O2-
Intermountain Gas Company
Page 1 of
Intermountain Gas Company
Socal Cycling Costs Workpaper
Line INT-01-INT-01-INT-01-
No.Socal Storaqe Facilities Annual Therms Prices Annual Cost
(a)(b)(c)(d)
SoCal Cycling 500 000 01591 71,595
Total Cycling Costs 500 000 71,595
Other Storaqe Facilities
SoCal Cycling
Total Cycling Costs
INT-02-
Annual Therms
INT-02-
Prices
00000
INT-02-
Annual Cost
Total Cycling Cost Difference (71 595)(1)
(1) See Exhibit 4, Line 20, Column (h)
Workpaper No.
Case No. INT-O2-
Intermountain Gas Company
Page 1 of
INTERMOUNTAIN GAS COMPANY
Peak Day Analysis for Demand Allocators in Case No. INT -O2-
FIRM
Line CORE TOTAL TRANSPORTATION TOTAL FIRM
No.RS-RS.GS.CORE TRANSPORTATION
DEMAND ALLOCATORS PER CASE NO.INT.O1-
Peak Day Therms 428,232 330 389 026,865 785,486 242,120 58,370 300,490
% oITotal 90.26272%73728%
TOTAL
PEAK
085 976
PROPOSED DEMAND ALLOCATORS PER CASE NO.INT-O2-:
Peak Day Therms (Line 2)428,232 330 389 026 865 2,785,486
Customers Embedded within Line 2 60,145 137 579 23,953 221 677
Peak Day Usage Per Customer (Line 5 divided by Line 6)42.
January 2002 Actual Customers 59,991 145,911 394 230,296
INT-01- Peak Day Therms (Line 7 mulitplied by Line 8)427,136 1,410 959 045,771 883 866 223,406 070
% of Total 1350695%91.19399%1.illm.
(1) FY02 Contract Therms
278,476 (1)162 342
80600%
Detail Detail Amount Sub-Total Total
(b)(c)(d)(e)(f)
998,154.
(34929,524.33)
46,310,726
17130 933,027.
(42 862 551.69)
135,602.
912 373.
323 562.97)
(3,354,825.02)
(6,766,014.20)
346,244.
(10 887.59)
335 356.
295 055.05)
INTERMOUNTAIN GAS COMPANY
Analysis of Account 1860 Surcharges (Credits)
Estimated June 30, 2002
LineNo. Description
(a)
ACCOUNT 1860 VARIABLE AMOUNTS:
Net Cumulative Deferred Gas Balance in 1860.2010 as of 7/16/01
Amortization in 1860.2020 as of 3/31/02
Estimated Therm Sales 4/1 through 6/30/02
Amortization Rate
Estimated Amortization in 1860.2020 at 6/30/02
Estimated Balance in 1860.2010 at 6/30/02
Deferred Gas Costs From Producers/Suppliers in 1860.2180 at 7/16/01
Deferred Gas Costs From Producers/Suppliers in 1860.2180 through 3/31/02
Estimated Deferred Costs in 1860.2180 from 4/1 through 6/30/02
Estimated Balance in 1860.2180 at 6/30/02
Daily Gas Excess Sales Deferred in 1860.2240 at 3/31/02
Gas Cost Carrying Charge Deferred in 1860.2340 at 3/31/02
Estimated Gas Cost Carrying Charge from 4/1 through 6/30/02
Estimated Balance in 1860.2340 at 6/30/02
ESTIMATED ACCOUNT 1860 VARIABLE BALANCE AT 6/30/02
ACCOUNT 1860 FIXED AMOUNTS:
Net Cumulative Deferred Gas Balance in 1860.2050 at 7/16/01
RS-1 Deferred Gas Balance in 1860.2060 at 7/16/01
Amortization for RS-1 in 1860.2060 at 3/31/02
Estimated RS-1 Therm Sales 4/1 through 6/30/02
RS-1 Amortization Rate
Estimated RS-1 Balance in 1860.2060 at 6/30/02
797051
(0.00180)
RS-2 Deferred Gas Balance in 1860.2070 at 7/16/01
Amortization for RS-2 in 1860.2070 at 3/31/02
Estimated RS-2 Therm Sales 4/1 through 6/30/02
RS-2 Amortization Rate
Estimated RS-2 Balance in 1860.2070 at 6/30/02
23,720 104
00112
(9,260.15)
170967.
GS-1 Deferred Gas Balance in 1860.2080 at 7/16/01
Amortization for GS-1 in 1860.2080 at 3/31/02
Estimated Therm Sales 4/1 through 6/30/02
GS-1 Amortization Rate
Estimated GS-1 Balance In 1860.2080 at 6/30/02
204 590
00222 974.
Industrial Deferred Gas Balance in 1860.2090 at 7/16/01
AmortizationforT-1 & T-2in 1860.2090 at 3/31/02
Estimated T-1 Block 1 & 2 Therm Sales 4/1 through 6/30/02
1 Amortization Rate
379,488
(0.00224)
Estimated T-2 Confract 4/1 through 6/30/02
2Amortization Rate
Estimated Industrial Balance in 1860.2090 at 6/30/02
168 210
00710
Estimated Cumulative Balance in 1860.2050 at 6/30/02
Fixed Cost Collection Deferred in 1860.2200 at 7/16/01
Fixed Cost Collection Deferred in 1860.2200 through 3/31/02
Estimated Fixed Cost Collection Deferred from 4/1 through 6/30/02
Estimated Balance in 1860.2200 at 6/30/02
4 Exit Fee Adjustment Deferred in 1860.2210 at 7/16/01
4 Exit Fee Adjustment Deferred in 1860.2210 through 3/31/02
Estimated T-4 Exit Fee Adjustment Deferred from 4/1 through 6/30/02
Estimated Balance in 1860.2210 at 6/30/02
Statoil Revenue Deferred in 1860.2260 at 7/16/01
Statoil Revenue Deferred in 1860.2260 through 3/31/02
Estimated Statoil Revenue Deferred from 4/1 through 6/30/02
Estimated Balance in 1860.2260 at 6/30/02
Capacity Released/Purchased Deferred in 1860.2320 at 3/31/02
654.
(58,325.75)
10,434.
(29,962.19)
133 370.
566.
817.76)
($43 249.86)
(18,770.05)
194.
Workpaper No.
Case No. INT-O2-
Intermountain Gas Company
Page 1 of 2
(191 946.37)
(40,105.82)
129974.
197 681.91
(63,643.38)
961.
157 760.
(824 155.88)
195 236.
528 841.
413.
800.55)
200.77)
(10,587.40)
776.
(43 840.74)
(13,568.60)
(55,632.43)
(401 828.13)
INTERMOUNTAIN GAS COMPANY
Analysis of Account 1860 Surcharges (Credits)
Estimated June 30, 2002
Line
No.Description
(a)
Detail
(b)
Detail
(c)
Expansion II Refund Amortizations in 1860.2130 at 7116/01
Amortizations Deferred in 1860.2130 through 3/31/02
Estimated Amortizations Deferred in 1860.2130 from 4/1 through 6/30/02
Estimated Balance in 1860.2130 at 6/30/02
Expansion II Refund Amortizations in 1860.2140 at 7/16/01
Amortizations Deferred in 1860.2140 through 3/31/02
Estimated Amortizations Deferred in 1860.2140 from 4/1 through 6/30/02
Estimated Balance in 1860.2140 at 6/30/02
Gas Cost Carrying Charge Deferred in 1860.2420 at 3131/02
Estimated Gas Cost Carrying Charge from 4/1 through 6/30/02
Estimated Balance in 1860.2420 at 6130102
Gas Cost Carrying Charge Deferred in 1860.2430 at 3/31/02
Estimated Gas Cost Carrying Charge from 4/1 through 6/30/02
Estimated Balance in 1860.2430 at 6/30/02
NWP RP93.5 Surcharge Deferred in 1860.2500 at 7116101
NWP RP93-5 Surcharge Deferred in 1860.2500 through 3/31/02
Estimated NWP RP93-5 Surcharge Deferral in 1860.2500 from 4/1 through 6/30/02
Estimated Balance in 1860.2500 at 6/30102
Market Segmentation Deferred in 1860.2530 at 7/16101
Market Segmentation Deferred in 1860.2530 through 3/31/02
Estimated Deferral in 1860.2530 from 4/1 through 6/30/02
Estimated Balance in 1860.2530 at 6/30/02
849.
782 644.53)
592639.
246,466.
797,051
00894 51,825.
856,083.
720 104
00859 203 755.
635,111.
16,204590
00870 140 979.
143,510.
379,488
00505 316.42
32,019.
168 210
06419 10,797.40
RS-1 Amortization in 1860.2540 at 3/31/02
Estimated RS-1 Therm Saies from 4/1 through 6/30/02
RS-1 Amortization Rate
Estimated RS-1 Amortization in 1860.2540 at 6/30/02
RS-2 Amortization in 1860.2540 at 3/31/02
Estimated RS-2 Therm Saies from 4/1 through 6/30/02
RS-2 Amortization Rate
Estimated RS-2 Amortization in 1860.2540 at 6/30/02
GS-1 Amortization in 1860.2540 at 3/31/02
Estimated GS Therm Saies from 4/1 through 6/30/02
GS-1 Amortization Rate
Estimated GS-1 Amortization in 1860.2540 at 6/30/02
1 Amortization in 1860.2550 at 3/31/02
Estimated T-1 Block 1&2 Therm Sales from 4/1 through 6/30/02
1 Amortization Rate
2 Amortization in 1860.2550 at 3/31/02
Estimated T-2 CD Therm Sales from 4/1 through 6/30/02
2 Amortization Rate
Estimated industriai Amortization in 1860.2550 at 6/30/02
Estimated Balance in 1860.2530 at 6/30/02
NWP RP95.409 Refund Deferred in 1860.2560 at 7116/01
NWP RP95-409 Surcharge Deferred in 1860.2560 through 3/31/02
Estimated NWP RP95-409 Surcharge Deferral in 1860.2560 from 4/1 through 6/30/02
Estimated Balance in 1860.2560 at 6130/02
ESTIMATED ACCOUNT 1860 FIXED BALANCE AT 6/30/02
TOTAL DEFERRED ACCOUNT 1860 BALANCE
Workpaper No.
Case No. INT-O2-
Intermountain Gas Company
Page 2 of 2
Amount
(d)
874.31)
273.
(153.48)
659.
600.91)
129.
039.
587.15)
164 514.
367,434.35)
298,292.48
059,839.
776 091.
228,643.
281,413.24)
Sub.Total
(e)
Total
(f)
601.31)
505.
(1,471.05)
30,452.
164 514.
567.72)
(3,281,413.24)
000 826.46)
(8,295 881.51)
INTERMOUNTAIN GAS COMPANY
1 Tariff Block 1 , Block 2, and Block 3 Adjustment
Workpaper No.
Case No. INT-O2-
Intermountain Gas Company
Page 1 of
Line
No.
Block 1 Block 2 Block 3
Descri tion Therm Sales Therm Sales Therm Sales Total
(a)(b)(c)(d)(e)
Industrial Therm Sales (10/1/00 9/30101)369,084 588 946 148 510 106 540
Blocks 1 and 2 Therm Sales 369 084 588 946 958 030
Percent Therm Sales between Blocks 1 and 2 77.373%22.627%100.000%
Proposed Adjustment to T-1 Tariff (1)(0.00600)
Industrial Therm Sales (10/1/00 9/30101)106 540
Annualized Adjustment (Line 4 multiplied by Line 5) (240,639)
Annualized Adjustment (Line 4 multiplied by Line 5)(240 639)
Percent Annualized Sales included in Block 1 77.373%
Adjustment to Block 1 (Line 7 mulitplied by Line 8)(186 190)
Block 1 Therms 369,084
Price AdjustmentlTherm Block 1 (Line 9 divided by Line 10)(0.00634)
Northwest Pipeline TF-1 Commodity Charge Change (2)00000
Total Price AdjustmentlTherm Block 1 (0.00634)
Annualized Adjustment (Line 4 multiplied by Line 5)(240 639)
22.627%
(54,449)
588 946
(0.00634)
00000
(0.00634)
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
(1) See Exhibit No., Line 38, Col. (I) minus the difference of Line 23, Col. (D minus Line 23, Col. (c)
(2) See Exhibit No., Line 23, Col. (D minus Line 23, Col. (c)