20070817Application.pdf

EXECUTIVE OFFICES
INTERMOUNTAIN GAS COMPANY
555 SOUTH COLE ROAD' P.O. BOX 7608' BOISE , IDAHO' [phone]' FAX [phone]
August 16 , 2007 RECEIVED
Intil hUG t b 5: I 5
Ms. Jean Jewell
Commission Secretary
Idaho Public Utilities Commission
472 W. Washington St.
P. O. Box 83720
Boise, 10 83720-0074
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~1\~ S i ON
RE:Intermountain Gas Company
Case No. INT-07-
Dear Ms. Jewell:
Enclosed for filing with this Commission is a signed original and seven copies of
Intermountain Gas Company s Application and supporting Workpapers for Authority to
change its Prices on October 1 , 2007.
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.
MPM/sc
Enclosures
W. C. Glynn
E. N. Book
P. R. Powell
M. E. Rich
S. R. Thomas.
Idaho Public Utilities Commission
Office of the SecretaryRECEIVED
AUG 1 6 2007
Boise, Idaho
INTE RM 0 UNT AIN GAS CO MP ANY
CASE NO. INT -O7-
APPLICATION,
EXHIBITS,
AND
WORKP APERS
In the Matter of the Application of INTERMOUNTAIN GAS COMPANY
for Authority to Change Its Prices on October 1 , 2007
(October 1 , 2007 Purchased Gas Cost Adjustment Filing)
Idaho Public Utilities Commission
Office of the Secretary
RECEIvED
Stephen R. Thomas, ISB No. 2326
MOFFATT, THOMAS, BARRETT, ROCK &
FIELDS, CHARTERED
Post Office Box 829
Boise, Idaho 83701
Telephone: [phone]
Facsimile: [phone]
MTBR&F 11-500.0340
Attorney for Intermountain Gas Company
AUG 1 6 2007
Boise, Idaho
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
In the Matter of the Application of
INTERMOUNT AIN GAS COMPANY
for Authority to Change Its Prices
Case No. INT-07-
APPLICATION
Intermountain Gas Company ("Intermountain ), 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 October 1 , 2007 new rate schedules which will
decrease its annualized revenues by $25.4 million, pursuant to the Rules of Procedure of the Idaho
Public Utilities Commission ("Commission ). Because of changes in Intermountain s gas related
costs, as described more fully in this Application, Intermountain s earnings will not be decreased as
a result of the proposed changes in prices and revenues. Intermountain s current rate schedules
showing proposed changes are attached hereto as Exhibit No.1 and are incorporated herein by
reference. Intermountain'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:
Paul R. Powell
Executive Vice President & Chief Financial Officer
Intermountain Gas Company
Post Office Box 7608 , Boise, ID 83707
and
Stephen R. Thomas
Moffatt, Thomas, Barrett, Rock & Fields, Chartered
Post Office Box 829
Boise, ID 83701
APPLICATION - 2
In support of this Application, Intermountain does allege and state as follows:
Intermountain 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.
Intermountain 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, MorelandlRiverside, and Shelly;
Blaine County - Bellevue, Hailey, Ketchum, and Sun Valley;
Bonneville County - Ammon, Idaho Falls, lona, and Dcon;
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.
Intermountain s properties in these locations consist of transmission pipelines, a liquefied
natural gas storage facility, distribution mains, services, meters and regulators, and general plant
and equipment.
II.
Intermountain seeks with this Application to pass through to each of its customer classes a
change in gas related costs resulting from: 1) a decrease in costs billed Intermountain pursuant to
APPLICATION - 3
the Settlement of the General Rate Case filed by Northwest Pipeline Corporation ("Northwest" or
Northwest Pipeline ), 2) the annualized impact of the General Rate Case filed by Gas
Transmission Northwest Corporation ("Gas Transmission Northwest" or "GTN"), 3) changes in
Intermountain s firm transportation and storage costs resulting from Intermountain s management
of its storage and firm capacity rights on pipeline systems including Northwest Pipeline and GTN
4) a decrease in Intermountain s Weighted Average Cost of Gas ("W ACOG"), 5) an updated
customer allocation of gas related costs pursuant to the Company s Purchased Gas Cost Adjustment
provision, 6) the collection of unaccounted for gas on Intermountain s distribution system and
7) the inclusion of temporary surcharges and credits for one year relating to gas and interstate
transportation costs from Intermountain s deferred gas cost accounts. Exhibit No.3 contains
pertinent excerpts from pipeline and related facilities' tariffs. Intermountain also seeks with this
Application to eliminate the temporary surcharges and credits included in its current prices during
the past 12 months, pursuant to Case No. INT-06-04. The aforementioned changes would result
in an overall price decrease to Intermountain s RS-, RS-, GS-, LV-, and T-2 Demand
customers, and a price increase to Intermountain s T-, T-2 Commodity, T-3 and T-4 customers.
These price changes are applicable to service rendered under rate schedules affected by and
subject to Intermountain s Purchased Gas Cost Adjustment ("PGA"), initially approved by this
Commission in Order No. 26109, Case No. INT-95-, and additionally approved through
subsequent proceedings.
Exhibit No.4 summarizes the price changes in: 1) Intermountain s base rate gas costs and its
rate class allocation, and 2) adjusting temporary surcharges or credits flowing through to
Intermountain s direct sales and transportation customers. Exhibit No.s 3 and 4 are attached hereto
and incorporated herein by reference.
III.
The current prices of Intermountain are those approved by this Commission in Order
No. 30137, Case No. INT-06-04.
IV.
Intermountain s proposed prices incorporate all price changes impacting Intermountain
firm interstate transportation capacity including, but not limited to , any such changes
APPLICATION - 4
implemented by Northwest and GTN which have occurred since Intermountain s last PGA filing
in Case No. INT-06-04.
On June 30, 2006, Northwest Pipeline Corporation filed a general system rate case
with the Federal Energy Regulatory Commission ("FERC") in Docket No. RP06-416-000. The
FERC suspended the effective date of Northwest's proposed rates until January 1 , 2007, subject
to refund and conditions and the outcome of the final FERC Order on the matter.
Intermountain s prices as approved in Case No. INT-06-04 were weighted to reflect this
January 1 , 2007 effective date, or 9 months of Intermountain s 12 month October I , 2006
through September 30, 2007 PGA period. Subsequent to Northwest's original filing and
Intermountain s filed Case No. INT-06-, on January 31 2007, Northwest and other parties
including Intermountain Gas Company, filed a Settlement ("Settlement") to resolve all
outstanding issues in the RP06-416-000 proceeding resulting in a rate reduction as compared to
Northwest's initial Case. On March 30, 2007, the FERC issued an Order approving the
Settlement effective April 1 , 2007. Intermountain proposes with this Application to incorporate
the benefits of these lower prices to include the annualization, or 12 month application, of the
same. Rows 3 and 4 of Exhibit No.4 reflect these changes.
Intermountain trap.sports natural gas from Alberta on the Gas Transmission Northwest
system from the international border at Kingsgate to the interconnection with Northwest Pipeline
at Stanfield. On June 30, 2006, GTN filed a general system rate case with the Federal Energy
Regulatory Commission in Docket No. RP06-407-000. The FERC s~spended the effective date
ofGTN's proposed rates until January 1 2007, subject to refund and conditions and the outcome
of the FERC hearing. Intermountain s prices as approved in Case No. INT-06-04 were
weighted to reflect this January 1 2007 effective date, or 9 months oflntermountain s 12 month
October 1 , 2006 through September 30, 2007 PGA period. The outcome of GTN's General Rate
Case proceeding is still pending before the FERC. Intermountain proposes with this Application
to incorporate the annualization, or 12 month application, ofGTN's filed Case.
TransCanada s BC system, formally known as Alberta Natural Gas ("ANG") and now
known as Foothills Pipeline System ("Foothills ) and its Alberta system also know as Nova Gas
Transmission ("Nova ), implemented price increases during 2007. The Foothills increase relates
to the assignment of its former ANG assets to its parallel Foothills system while the Nova
APPLICATION - 5
increase largely relates to temporary credits passed back to customers during the last quarter of
2006 which have now expired. Intermountain s capacity costs have also increased on these
Canadian pipelines due to the tightening exchange rate between u.S. and Canadian currencies.
Intermountain s review of the adequacy of its interstate transportation and storage
services is performed on an annual basis under design weather and certain load growth
assumptions. A summary of the methodology incorporated within this annual review was
included in the Company s Integrated Resource Plan, which is currently on file with this
Commission.
Intermountain s adequacy review included analyzing upstream pipeline capacity which
indicated a need to procure additional upstream capacity in order to more closely align deliveries
from those upstream pipelines with Intermountain s take-away rights on Northwest at its
Stanfield interconnect with GTN.
Row 5 of Exhibit No.4 includes the costs for this incremental upstream capacity as well
as the aforementioned annualization of GTN's General Rate Case and price increases on
TransCanada s pipelines.
Intermountain continues to take the necessary steps to manage its natural gas storage and
has procured an incremental amount of economically priced liquid storage at Northwest'
Plymouth LNG facility to enhance Intermountain s overall storage portfolio. Rows 13 through 18
of Exhibit No.4 include the costs for this incremental storage.
Intermountain is party to certain agreements whereby Intermountain manages its storage
related assets in conjunction with a third party asset manager. Intermountain proposes to pass back
to its customers the benefits generated from these agreements as included on Exhibit No., Line
19.
Exhibit No., Lines I through 23, details the proposed changes in Intermountain s prices
resulting from the aforementioned adjustments to Intermountain s cost of storage, and interstate
and upstream capacity from its various suppliers.
The W ACOG reflected in Intermountain s proposed prices is $0.63583 per therm, as shown
on Exhibit No., Line 24, Column (f). This compares to $0.68500 per therm currently included in
the Company s tariffs.
APPLICATION - 6
Above normal natural gas storage inventory levels in the nation, continued gains in
exploration and production of natural gas at the regional level in relation to demand, coupled with
Intermountain s management of its natural gas supply portfolio all combined to facilitate this
reduction to the Company s proposed W ACOG.
The proposed W ACOG includes the benefits to Intermountain s customers generated by
Intermountain s management of significant natural gas storage assets whereby gas is procured
during the traditionally lower priced summer season for withdrawal and use during the winter when
prices would otherwise be substantially higher. Additionally, and in an effort to further stabilize the
prices paid by our customers during the upcoming winter period, Intermountain entered into
various hedging agreements to lock-in the price for significant portions of its underground storage
and other winter "flowing" supplies.
Intermountain believes that the W ACOG proposed in this Application, subject to the effect
of actual supply and demand, will likely materialize during the upcoming PGA period.
Intermountain will employ, in addition to those natural gas hedges already in place for the high
winter demand, cost effective financial instruments to secure those prices embedded within the filed
W ACOG when and if those pricing opportunities materialize in the marketplace.
However, liquidity in the market is sustained by contrary opinions and natural gas prices
could indeed realize levels different ITom those included in this Application. Although current
commodity futures prices dictate the use of this $0.63583 per therm W ACOG, Intermountain
continues to remain vigilant in monitoring natural gas prices and is committed to come before this
Commission prior to this winters heating season with an Application to further amend these
proposed prices, should forward prices materially deviate ITom the $0.63583 per thermo
Timely natural gas price signals and the accounting for any cost differences brought about
by changes in the natural gas market, facilitated through the use of the PGA mechanism, enhances
our customers' ability to make timely and informed energy use decisions and ensures they only pay
the actual cost of such supplies. It is important to continue to alert our customers in a timely manner
to impending changes before their winter natural gas usage is before them. By employing the use of
customer mailings and various media resources, Intermountain will continue to educate its
customers regarding the wise and efficient use of natural gas, billing options available to help our
customers manage their energy budget, and pending natural gas unit price changes.
APPLICATION - 7
VI.
Pursuant to Case No. INT -06-, Intermountain has included temporary surcharges and
credits in its October 1 , 2006 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 -06-04. Line 29 of
Exhibit No.4 reflects the elimination of these temporary surcharges and credits.
VII.
Intermountain s PGA tariff includes provisions whereby Intermountain s proposed prices
will be adjusted for updated customer class sales volumes and purchased gas cost allocations
pursuant to the Company s approved cost of service methodology. Intermountain s proposed prices
include a fixed cost collection adjustment pursuant to these PGA provisions, as outlined on Exhibit
No., Line 24. The price impact of this adjustment is included on Exhibit No., Line No. 30.
Exhibit No.5 is attached hereto and incorporated herein by reference.
VIII.
Intermountain is party to certain agreements whereby Intermountain has released segmented
portions of its firm capacity rights when not needed to meet its customer needs. Intermountain
proposes to pass back to its customers the benefits generated ITom the capacity release agreements
totaling $3.4 million. Exhibit No., Line 1 , reflects the inclusion of the $3.4 million credit.
Intermountain proposes to pass back this amount via the per therm credit as detailed on Exhibit
No.7. Exhibit No.s 6 and 7 are attached hereto and incorporated herein by reference.
IX.
Intermountain proposes to allocate deferred gas costs ITom its Account No. 186 balance to
its customers through temporary price adjustments to be effective during the 12-month period
ending September 30, 2008, as follows:
1) Intermountain has been deferring in its Account No. 186 fixed gas costs. The
credit amount shown on Exhibit No., Line 10, Co!. (b) of $3.9 million is predominantly
attributable to the collection of interstate pipeline capacity costs, the true-up of expense issues
previously ruled on by this Commission, refunds attributable to the Settlement of Northwest's
General Rate Case and mitigating capacity release credits ITom Intermountain s up-stream capacity.
APPLICATION - 8
Intermountain proposes to collect or pass back these balances via the per therm surcharges and
credits, as detailed on Exhibit No.8 and included on Exhibit No., Line 2. Exhibit No.8 is
attached hereto and incorporated herein by reference.
2) Intermountain has been deferring in its Account No. 186 deferred gas cost credits
of$1.5 million, as shown on Exhibit No., Line 2, Co!. (b), attributable to Intermountain s variable
gas costs since October 1 , 2007. Intermountain proposes to pass back this credit balance via a per
therm credit, as shown on Exhibit No., Line 4, Co!. (b) and included on Exhibit No., Line 3.
Exhibit No.9 is attached hereto and incorporated herein by reference.
Intermountain seeks with this Application to recover, or pass-back during periods
positive gas imbalances, unaccounted for natural gas on its distribution system. Unaccounted for
gas is the difference between the quantity of gas received at the various Northwest gate stations
and the quantity of gas delivered and billed to customers on Intermountain s distribution system
whether it is more or less.
Intermountain s base rates include a component to recover a portion of unaccounted for
gas on Intermountain s system. However, the existing base rate component was set during a
period of very low natural gas commodity costs prior to open access rules. The significant
increase in commodity cost since that time results in a difference in unaccounted for gas recovery
as compared to today s unaccounted for gas levels. Intermountain s level of unaccounted for gas
on its distribution system remains one of the lowest in the nation and Intermountain continues to
monitor and manage towards low levels of unaccounted for gas on its system
Intermountain proposes to allocate and collect this unaccounted for and umecovered gas
balance via a per therm surcharge, as shown on Exhibit No., Lines 5-, Co!. (b) and included
on Exhibit No., Line 3.
XI.
Intermountain has allocated the proposed price changes to each of its customer classes
based upon Intermountain s PGA provision. A straight cent-per-therm price increase was not
utilized for the T-l tariff. No fixed costs are currently recovered in the tail block of Intermountain
T -tariff. Absent Williams' firm transportation TF -1 Commodity Charge increase and the
unaccounted for gas recovery as included on Exhibit No., the proposed increase in the T-l tariff is
APPLICATION - 9
fixed cost related, and therefore, a cent per therm increase relating to fixed costs was made only to
the first two blocks of the T-l tariff.
XII.
The proposed decrease to the T-2 tariff Demand Charge is fixed cost related, and therefore
a cent per therm decrease was made to the T-2 Demand Charge for these fixed costs. Additionally,
the proposed increase to the T-2 Commodity Charge incorporates the increase in the Williams' firm
transportation TF-I Commodity Charge pursuant to Northwest's current tariffs as well as the
collection of unaccounted for gas as included on Exhibit No.
XIII.
Each block of the proposed T-3 and T-4 tariffs include a uniform cents per therm increase
for unaccounted for gas recovery as detailed on Exhibit No., Line 12, Co!. (b). The prices
including the proposed adjustment for each block of the T-3 and T-4 tariffs are outlined on Exhibit
No., Page 1 , Lines 30 through 37.
XIV.
Exhibit No. 10 is an analysis of the overall price changes by class of customer. Exhibit No.
10 is attached hereto and incorporated herein by reference.
xv.
The proposed overall price changes herein requested among the classes of service of
Intermountain reflects a just, fair, and equitable pass-through of changes in gas related costs to
Intermountain s customers.
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 Intermountain
customers through a Customer Notice and by a Press Release sent to daily and weekly newspapers
and major radio and television stations in Intermountain 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 Intermountain s rate proceedings.
APPLICATION - 10
XVII.
Intermountain requests that this matter be handled under modified procedure pursuant to
Rules 201-204 of the Commission s Rules of Procedure. Intermountain stands ready for immediate
consideration ofthis matter.
APPLICATION - II
WHEREFORE, Intermountain 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 October 1 , 2007 in the manner shown on Exhibit No.
b. That this Application be heard and acted upon without hearing under modified procedure
and
For such other relief as this Commission may determine proper herein.
DATED at Boise, Idaho, this 16th day of August, 2007.
INTERMOUNTAIN GAS COMPANY
Stephen
Attorney
~~lli
IZ4
Executive Vice President & CFO
APPLICATION - 12
CERTIFICATE OF MAILING
I HEREBY CERTIFY that on this 16th day of August, 2007, I served a copy of the
foregoing Case No. INT-07-03 upon:
Paula Pyron
Northwest Industrial Gas Users
4113 Wolf Berry Court
Lake Oswego, OR 97035-1827
Edward A. Finklea
Cable Huston Benedict Haagensen & Lloyd LLP
1001 SW Fifth Avenue, Suite 2000
Portland, Oregon 97204-1136
R. Scott Pasley
J. R. Simplot Company
PO Box 27
Boise, ID 83707
Steven Gray
J. R. Simplot Company
PO Box 27
Boise, ID 83707
Conley E. Ward, Jr.
Givens, Pursley, Webb & Huntley
277 N. 6th St., Suite 200
PO Box 2720
Boise, ID 83701
by depositing true copies thereof in the United States Mail, postage prepaid, in envelopes addressed
to said persons at the above addresses.
EXHIBIT NO.
CASE NO. INT-07-
INTERMOUNTAIN GAS COMPANY
CURRENT TARIFFS
Showing Proposed Price Changes
(10 pages)
Idaho Public Utilities
Office of the
CommIssion
R E C E I i~tary
AUG 1 6 2007
BOise, Idaho
Exhibit No.
Case No. INT-07-
Intermountain Gas Company
Page 1 of 10
COMPARISON OF PROPOSED OCTOBER 1, 2007 PRICES
TO OCTOBER 1, 2006 PRICES
October 1, 2006 Proposed
Line Prices per Proposed October 1, 2007
No.Rate Class INT -06-Adjustment Prices
(a)(b)(c)(d)
RS-
April - November 1.21543 (0.09084)1.12459
December - March 1.1 0287 (0.09084)1.01203
RS-
April- November 1.06648 (0.08913)97735
December - March 1.03285 (0.08913)94372
GS-
April - November
Block 1 1.08406 (0.09057)99349
Block 2 1.06233 (0.09057)97176
Block 3 1.04131 (0.09057)95074
December - March
Block 1 1.03321 (0.09057)94264
Block 2 1.01201 (0.09057)92144
Block 3 99155 (0.09057)90098
CNG Fuel 99155 (0.09057)90098
LV-l (1)
Block 1 84987 (0.08685) (2)76302
Block 2 81138 (0.08685) (3)72453
Block 3 74067 (0.10139) (4)63928
Block 1 11819 01811 (2)13630
Block 2 07970 01811 (3)09781
Block 3 00899 00357 (4)01256
Demand Block 1 1.83034 (0.01087)1.81947
Demand Block 2 1.02876 (0.01087)1.01789
Commodity Charge 00484 00357 00841
Over-Run Service 04743 00357 05100
Block 1 05560 00191 05751
Block 2 02300 00191 02491
Block 3 00887 00191 01078
Block 1 05983 00191 06174
Block 2 02134 00191 02325
Block 3 00661 00191 00852
(1) The LV-l Adjustment is calculated by taking the figures in Lines 22 - 24, Col (c), plus removal of the
TF-l Commodity Charge change, plus the change in the W ACOG, plus removal of the
temporary variable surcharge from INT-O6-04 of$O.O4906, plus the temporary variable
debit on Exhibit 9, Line 4, Col (b)
(2) See WorkpaperNo. 7, Line 13, Co! (e)
(3) See WorkpaperNo. 7, Line 20, Col(e)
(4) See WorkpaperNo. 7, Line 23, Col (e)
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.
Thirty-Seventh Eighth Revised Sheet No. 01 (Page 1 of 1)
Name
of Utility
Exhibit No.
Case No. INT-07-
Intermountain Gas Company
Page 2 of 10
Intermountain Gas Company
Rate Schedule RS-
RESIDENTIAL SERVICE
IDAHO PUBLIC UTILITIES COMMISSIONAPPROVED EFFECTIVE
SEP 28 '06 OCT 1 ~ '
~-'V\.-l'\)- 30\3t
.n. 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 billinQ periods endinQ April throuQh November
Customer Charge - $2.50 per bill
Commodity Charge - $1.21543 per therm* $1.12459
For billinQ periods endinQ December throuQh March
Customer Charge - $6.50 per bill
Commodity Charge - $1.10287 per therm* $1.01203
Includes:
Temporary purchased gas cost adjustment of $0.03422 $(0.02041)
Weighted average cost of gas of $0.68500 $0.63583
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: Paul R. Powell Title: Executive Vice President & Chief Financial Officer
Effective: October 1 2007
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.
Thirty-Seventh Eighth Revised Sheet No. 02
Name
of Utility
Exhibit No.
Case No. INT-07-
Intermountain Gas Company
Page 3 of 10
(Page 1 of 1)
Intermountain Gas Company
Rate Schedule RS-
MULTIPLE USE RESIDENTIAL SERVICE
IDAHO PUBLIC UTILITIES COMMISSIONAPPROVED EFFECTIVE
SEP 28 '06 OCT 1 ~ '
~.M.. C).I'\). "30\ 31
tn. SECRETARY
AVAILABILITY:
Available to individually metered consumers using gas for several residential purposes
including both water heating and space heating.
RATE:
Monthly minimum charge is the customer charge.
For billina periods endinQ April throuQh November
Customer Charge - $2.50 per bill
Commodity Charge. $1.06648 per therm* $0.97735
For billinQ periods endinQ December throuQh March
Customer Charge - $6.50 per bill
Commodity Charge $1.03285 per therm* $0.94372
Includes:
Temporary purchased gas cost adjustment of $0.02786 $(0.02458)
Weighted average cost of gas of $0.68500 $0.63583
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: Paul R. Powell Title: Executive Vice President & Chief Financial Officer
Effective: October 1 2007
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.
Thirty Ninth Fortieth Revised Sheet No. 03 (Page 1 of 2)
Name
of Utility
Exhibit No.
Case No. INT-07-
Intermountain Gas Company
Page 4 of 10
Intermountain Gas Company
Rate Schedule GS-
GENERAL SERVICE
IDAHO PUBLIC UTILITIES COMMISSIONAPPROVED EFFECTJVE
SEP 28 '06 OCT 1 - '
PJ.-1.-0Ju. 30\3,
lO. SECRETARY
AVAilABILITY:
Available to individually metered customers whose requirements for natural gas do not exceed
000 therms per day, at any point on Company s distribution system. Requirements in excess of
000 therms per day may be served under this rate schedule upon execution of a one-year written
service contract.
RATE:
Monthly minimum charge is the customer charge.
For billinQ periods endinQ April throuQh November
Customer Charge - $2.00 per bill
Commodity Charge - First 200 therms per bill $1.08406* $0.99349
Next 1,800 therms per bill $1.06233* $0.97176
Over 2,000 therms per bill $1.04131 * $0.95074
For billinQ periods endinQ December throuQh March
Customer Charge - $9.50 per bill
Commodity Charge - First 200 therms per bill $1.03321 * $0.94264
Next 1,800 therms per bill $1.01201* $0.92144
Over 2,000 therms per bill $0.99155 * $0.90098
Includes:
Temporary purchased gas cost adjustment of $0.02520 $(0.02655)
Weighted average cost of gas of $0.68500 $0.63583
Issued by: Intermountain Gas Company
By: Paul R. Powell Title: Executive Vice President & Chief Financial Officer
Effective: October 1 , 2GOO 2007
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.
Thirty Ninth Fortieth Revised Sheet No. 03 (Page 2 of 2)
Name
of Utility
Exhibit No.
Case No. INT-07-
Intermountain Gas Company
Page 5 of 10
Intermountain Gas Company IDAHO PUBLIC UTILITIES COMMISSIONA~PROVED EFFECTIVE
Rate Schedule GS-
GENERAL SERVICE (Continued)
SEP 28 '06 OCT 1 ~ '
\)-AA.. b.
\"\).
~C) \
Itl. SECRETARY
For separately metered deliveries of gas utilized solely as Compressed Natural Gas Fuel in
vehicular internal combustion engines.
Customer Charge - $9.50 per bill
Commodity Charge - $0.99155 per therm* $0.90098
Includes:
Temporary purchased gas cost adjustment of $0.02520 $(0.02655)
Weighted average cost of gas of $0.68500 $0.63583
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the
Company s Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
1. Any GS-1 customer who leaves the GS-1 service will pay to Intermountain Gas Company,
upon exiting the GS-1 service, all gas and transportation related costs incurred to serve
the customer during the GS-1 service period not borne by the customer during the time the
customer was using GS-1 service. Any GS-1 customer who leaves the GS-1 service will
have refunded to them, upon exiting the GS-1 service, any excess gas commodity or
transportation payments made by the customer during the time they were a GS-
customer.
2. All natural gas service hereunder is subject to the General Service Provisions of the
Company s Tariff, of which this rate schedule is a part.
Issued by: Intermountain Gas Company
By: Paul R. Powell Title: Executive Vice President & Chief Financial Officer
Effective: October 1 , 2QW 2007
LP.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.
Fo -SavoRth Eighth Revised Sheet No. 04
Name
of Utili
Exhibit No.
Case No. INT-07-
Intermountain Gas Company
Page 6 of 10
IDAHO PUBLIC UTILITIES COMMISSIOAPPROVED EFFECTIVEIntermountain Gas Com an
Rate Schedule LV-
LARGE VOLUME FIRM SALES SERVICE
SEP 2.8 '06 OCT 1 ~ '
~.IV1 -YU. 30\ 31~ Ifl SECRETARY
AVAILABILITY:
Available at any mutually agreeable delivery point on the Company s distribution system to any
existing customer receiving service under the Company s rate schedules LV-1, T-, or T-2, or any new
customer whose usage does not exceed 500,000 therms annually, upon execution of a one-year
minimum written service contract for firm sales service in excess of 200,000 therms per year.
MONTHLY RATE:
Commodity Charge:
First 250,000 therms per bill $0.84987* $0.76302Next 500,000 therms per bill $0.81138* $0.72453
Amount Over 750,000 therms per bill $0.74067** $0.63928
The above prices include weighted average cost of gas of $0.68500 $0.63583
Includes temporary purchased gas cost adjustment of $0.03084 $(0.06240)
**
Includes temporary purchased gas cost adjustment of $0.04906 $(0.05222)
PURCHASED GAS COST ADJUSTMENT (PGA):
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company
Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
1. All natural gas service hereunder is subject to the General SerVice Provisions of the
Company s Tariff, of which this Rate Schedule is a part.
2. Any LV-1 customer who exits the LV-1 service at any time (including, but not limited to, the
expiration of the contract term) will pay to Intermountain Gas Company, upon exiting the LV-1 service,
all gas and/or interstate transportation related costs to serve the customer during the LV-1 contract
. period not borne by the customer during the LV-1 contract period. Any LV-1 customer will have
refunded to them, upon exiting the LV-1 service, any excess gas and/or interstate transportation related
payments made by the customer during the LV-1 contract period.3. In the event that total deliveries to any customer within the last three contract periods met or
exceeded the 200,000 therm threshold, but the customer during the current contract period used less
than the contract minimum of 200,000 therms, an additional amount shall be billed. The additional
amount shall be calculated by billing the deficit usage below 200,000 therms at the T -1 Block 1 rate. The
customer s future eligibility for the LV-1 Rate Schedule will be renegotiated with the Company.
Issued by: Intermountain Gas Company
By: Paul R. Powell Title: Executive Vice President & Chief Financial Officer
Effective: October 1 2007
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.
Thirt -+RfFQ Fourth Revised Sheet No. 05 (Page 1 of 2)
Exhibit No.
Case No. INT-07-
Intermountain Gas Company
Page 7 of 10
Name
of Utili
Rate Schedule T-
FIRM TRANSPORTATION SERVICE
IDAHO PUBLIC UTILITIES COMMISSIONAPPROVED EFFECTIVE
SEP 28 '06 OCT 1 ~ '
~~
Y\J . "?c\
tn. SECRETARY
Intermountain Gas Com an
AVAILABILITY:
Available at any mutually agreeable delivery point on the Company s distribution system to any existing
customer receiving service under the Company s rate schedules LV-, T-1, or T-2, upon execution of a one
year minimum written service contract for firm transportation service in excess of 200,000 therms per year.
MONTHLY RATE:
Commodity Charge:
Block One:
Block Two:
Block Three:
First 250 000 therms transported $0.11819* $0.13630
Next 500,000 therms transported $0.07970* $0.09781
Amount over 750,000 therms transported $0.00899 $0.01256**
Includes temporary purchased gas cost adjustment of $(0.01822)$(0.00827) .
Includes temporary purchased Qas cost adjustment of $0.00191
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company
Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
1. All natural gas service hereunder is subject to the General Service Provisions of the Company s Tariff, of
which this Rate Schedule is a part.
2. The customer shall negotiate a Maximum Daily Firm Quantity (MDFQ) amount, which will be stated in and
will be in effect throughout the term of the service contract. The MDFQ shall not exceed the customer
historical maximum daily usage, as agreed to by the Company.
In the event the Customer requires daily usage in excess of the MDFQ, and subject to the availability of
firm interstate transportation to service Intermountain s system, all such usage may be transported and
billed under either secondary rate schedule T -3 or T -4. The secondary rate schedule to be used shall be
predetermined by negotiation between the Customer and Company, and shall be included in the service
contract. All volumes transported under the secondary rate schedule are subject to the provisions of the
applicable rate schedule T -3 or T -4.
Issued by: Intermountain Gas Company
By: Paul R. Powell Title: Executive Vice President & Chief Financial Officer
Effective: October 1 2007
Name
of Utility Intermountain Gas Company
Exhibit No.
Case No. INT-07-
Intermountain Gas Company
Page 8 of 10
IDAHO PUBUC UTILITIES COMMISSIONAPPROVED EFFEcnVE
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.
Fourteenth Fifteenth Revised Sheet No. 10 (Page 1 of 2)
SEP 28- '06 OCT 1 ~ '
p~.
6,/'"0, 3C\~1
I1u... Jt).11wJ.l SECRETARYRate Schedule T-no
FIRM TRANSPORTATION SERVICE WITH MAXIMUM DAILY DEMANDS
AVAilABILITY:
Available at any mutually agreeable delivery point on the Company s distribution system to any
existing T -2 customer whose daily contract demand for nonammonia therms on any given day meets or
exceeds a predetermined level agreed to by the customer and the Company upon execution of a one-year
minimum written service contract for firm transportation service in excess of 200,000 therms per year.
MONTHLY RATE:
Firm Service
Demand Charge:
Firm Daily Demand -
First 15,000 therms
Amount over 15,000 therms
Commodity Charge:
For Firm Therms Transported
Over-Run Service
Rate Per Therm
$1.83034* $1.81947
$1.02876* $1.01789
$0.00484 $0.00841**
Commodity Charge:
For Therms Transported In Excess Of MDFQ:$0.04743 $0.05100**
Includes temporary purchased gas cost adjustment of $(9.15687)$(0.22610)
Includes temporary purchased aas cost adiustment of $0.00191
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company
Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the Company s Tariff,
of which this Rate Schedule is a part.
The customer shall nominate a Maximum Daily Firm Quantity (MDFQ), which will be stated in and will
be in effect throughout the term of the service contract.
The monthly Demand Charge will be equal to the MDFQ times the Firm Daily Demand rate. Firm
demand relief will be afforded to those T -2 customers paying both demand and commodity charges
for gas when, in the Company s judgment, such relief is warranted.
The actual therm usage for the month or the MDFQ times the number of days in the billing month,
whichever is less, will be billed at the applicable commodity charge for firm therms.
Issued by: Intermountain Gas CompanyBy: Paul R. Powell Title: Executive Vice President & Chief Financial Officer
Effective: October 1 , 200e-2007
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.
RFSt Revised Second Sheet No. 11 (Page 1 of 2)
Exhibit No.
Case No. INT-07-
Intermountain Gas Company
Page 9 of 10
IDAHO PUBLIC UTILITIES COMMISSIONAPPROVED EfFECTIVE
Name
of Utility Intermountain Gas Company
JUL 31 'JUL 3 0 '
~-
N- ~,(P5u
Rate Schedule T -J2. Jk / ~J",,--SECRETAIW
INTERRUPTIBLE DISTRIBUTION TRANSPORTATION SERVICE
AVAilABiliTY:
Available at any point on the Company s distribution system to any customer upon
execution of a one year minimum written service contract.
MONTHLY RATE:
Block One:
Block Two:
Block Three:
First 100,000 therms transported!ID 05560 $0.05751*Next 50,000 therms transported!ID 02300 $0.02491*
Amount over 150,000 therms transported!ID 00887 $0.01078*
Includes temporary purchased aas cost adjustment of $0.00191
ANNUAL MINIMUM Bill:
The customer shall be subject to the payment of an annual minimum bill of $30,000
during each annual contract period, unless a higher minimum is required under the
service contract to cover special conditions.
SERVICE CONDITIONS:
1. The Company, in its sole discretion, shall determine whether or not it has
adequate capacity to accommodate transportation of the customer s gas supply on the
Company s distribution system.
2. All natural gas service hereunder is subject to the General Service Provisions of
the Company s Tariff, of which this Rate Schedule is a part.
3. Interruptible Distribution Transportation Service may be made firm by a written
agreement between the parties if the customer has a dedicated line.
4. If requested by the Company, the customer expressly agrees to interrupt its
operations during periods of capacity constraints on the distribution system.
5. This service does not include the cost of the customer s gas supply or the
interstate pipeline capacity. The customer is responsible for procuring its own supply of
natural gas and transportation to Intermountain s distribution system under this rate.
6. The customer understands and agrees that the Company is not responsible to
deliver gas supplies to the customer which have not been nominated and accepted for
delivery by the interstate pipeline.
7. An existing lV-I, T-I, or T-2 customer electing this schedule may concurrently
utilize Rate Schedule T-3 on the same or contiguous property.
Issued by: Intermountain Gas Company
By: RusseJJ-b-W0J:tI1aR Paul R. Powell Title: Vice President Governmental J\ffuirs and Resource Planning
Executive Vice President and Chief Financial Officer
Effective: July 21 1998 October 1,2007
Name
of Utility Intermountain Gas Company
Exhibit No.
Case No. INT-07-
Intermountain Gas Company
Pag~ 10 of 10
IDAHO PUBLIC UTILITIES COMMISSIONAPPROVED EFPECTIVE
JUl30 '98 JUl31 -sa~~. c..t\.). or1u5tG
Rate Schedule T -4 jl. ~SECRETARV
FIRM DISTRIBUTION ONLY TRANSPORTATION SERVICE
I.P.C. Gas Tariff
Second Revised Volume No.
(Supersedes First Revised Volume No.
;.... . .
First Revised Sheet No. 13 (Paqe 1 of 2)
AVAilABILITY:
Available at any mutually agreeable delivery point on the Company s distribution system to
any customer upon execution of a one year minimum written service contract for firm distribution
transportation service in excess of 200,000 therms per year.
MONTHLY RATE:
Commodity Charge:
Block One:
Block Two:
Block Three:
First
Next
Amount over
250 000 therms transported~ 05983 $0.06174*
500,000 therms transported~ 02134 $0.02325*
750,000 therms transported~ 00661 $0.00852*
Includes temporary purchased aas cost adjustment of $0.00191
SERVICE CONDITIONS:
1. This service excludes the service and cost offirm interstate pipeline charges.
2. The customer is responsible for procuring its own supply of natural gas and interstate
transportation under this Rate Schedule. The customer understands and agrees that the
Company is not responsible to deliver gas supplies to the customer which have not been
nominated, scheduled, and delivered by the interstate pipeline to the designated city gate.
3. 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.
4. The customer shall nominate a Maximum Daily Firm Quantity. (MDFQ), which will be
stated in the contract and in effect throughout the term of the service contract.
5. An existing l V-1, T -1, or T -2 customer electing this schedule may concurrently utilize
Rate Schedule T -4 on the customer s same or contiguous property.
BilLING ADJUSTMENTS:
1. 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 -4 Block 1 rate. The customer s future eligibility for the T-
Rate Schedule will be renegotiated with the Company.
Issued by: Intermountain Gas Company
By: Russell L. 'JVorth::m Paul R. Powell Title Vice President Government;)1 J\fbirs and Resource
Executive Vice President and Chief Financial Officer
Effective: I. .1. ~ ~, ~ CICIO October 1 , 2007
EXHIBIT NO.
CASE NO. INT-07-
INTERMOUNTAIN GAS COMPANY
Idaho Public Utilities Commis .
Office of the Secreta s/on
RECEIVED
AUG f 6 2007
Boise, Idaho
PERTINENT EXCERPTS FROM INTERSTATE PIPELINES AND RELATED
FACILITIES
(47 pages)
Exhibit No.
Case No. fNT -07 -
Intermountain Gas Company
Page 1 of 41-
Williams Northwest Pipeline Corporation
Northwest Pipeline" or "Northwest"
Applicable Filings, Tariffs and Rate Schedules
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 2 of 47
Williifi3s
April 10, 2007
NQKniWlIT PD'ILDII
JI.Bor. $&900
SlIt: lib: ow. \IT 841se.0900
~:
[phone]
FAX: (801) 58+7164
Ms. Philis J. Posey, Acting Secretary
Federal Energy Regulatory Commission
888 First Street, N.
Washington. D.C. 20426
Re:Northwest Pipeline Corporation
Docket No. RPO6-416-
Dear Ms. Posey:
Pursuant to Part 154 of the regulations of the Federal Energy Regulatory Commission
(Commission). Northwest Pipeline Corporation (Northwest) tenders for filing and
acceptance the tariff sheets listed below as part of Its FERC Gas Tariff, Third Revised
Volume No.
2nd Substitute Thlrty-Flrst Revised Sheet No.
Substitute Third Revised Sheet No. 5-
2nd Substitute Sixth Revised Sheet No. 5-C
2nd Substitute First Revised Sheet No. 5.
2nd Substitute Fourteenth Revised Sheet No.' 6 .
Substitute Fifteenth Revised Sheet No.
Substitute Seventeenth Revised Sheet No.
Substitute Fifteenth Revised Sheet No. 8.
The purpose of this filing Is to submit tariff sheets reflecting the rates in the Stipulation
and Settlement Agreement (Settlement) filed by Northwest and other parties in Docket
No. RPO6-416-000 and approved by the Commission on March 30. 2007.
Statement of Nature, Reasons an~ Basis for the Filing
On June 30, 2006. Northwest filed tariff sheets as part of its filing in Docket No. RPO~
416-000 to effectuate a general rate Increase. A suspension order was Issued by the
Commission On July 31 , 2006, accepting and suspending the proposed tariff sheets to
be effective January 1. 2007. subject to refund and conditions. and es~abllshlng hearing
procedures.1 On December 22,2006. Northwest made its motion rate filing to place
116 FERC, 61,107 (2006).
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 3 of 47
Ms. Philis J. Posey
April 10, 2007
Page 2 of 3
new rates into effect on January 1, 2007. On January 18 2007, the Commission
issued a letter order accepting Northwest's motion rates. On January 31 , 2007,
Northwest and other parties filed the Settlement to resolve all outstanding Issues In this
proceeding. On March 30, 2007, the Commission issued an order approving the
Settlement.2 Accordingly, Northwest Is hereby filing tariff sheets reflecting the approved
Settlement rates.
Effective Date and Waiver Request
Northwest requests that the Commission grant any waivers it may deem necessary to
accept the tendered tariff sheets to be effective January 1, 2007, the effective date for
the Settlement rates.
Procedural Matters
Pursuant to the applicable provisions In Section 154 of the Commission s regulations,
Northwest submits the following materials with this filing:
the proposed tariff sheets listed above
. a red lined version of the proposed tariff sheets,
. a form of notice suitable for publication in the Federal Register, and
. a diskette containing the proposed tariff sheets In electronic form, and a separate
diskette containing the form of Federal Register notice.
ServIce and Communications
An original and five copies of tI1is filing are being provided to the Commission. Copies
of this filing have been serv~ upon each person designated on the official service list
complied by the Secretary in this proceeding.
118 FERC, 61 272 (2007).
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 4 of 47
Ms. Philis J. Posey
April 10, 2007
Page 3 of 3
All communications regarding this filing should be served bye-mail to:
Gary K. Kotter
Manager, Certificates and Tariffs
[phone]
Northwest Pipeline Corporation
O. Box 58900
Salt lake City, Utah 84158-0900
garold. k. kotter(glwilliams.com
Steven W. Snarr
Senior Counsel
(801)" 584-7094
NorthWest Pipeline Corporation
O. Box 58900
Salt lake City, Utah 84158-0900
steven. w. snarr~willlam s .com
The undersigned certifies that the contents of this filing are true and correct to the best
of his knowledge and belief; that the paper and electronic versions of the submitted
tariff sheets contain the same information; and that he possesses full power and
authority to sign this filing.
Respectfully submitted,
ELINE CORPORATION
M. ~ertsch
, Rates and Regulatory
Enclosures
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 5 of 47
UNITED STATES OF AMERICA
FEDERAL ENERGY REGULATORY COMMISSION
Northwest Pipeline Corporation Docket No. RPO6-41a.
NOTICE OF COMPLIANCE-FILING
" Take notice that on April 10, 2007, Northwest Pipeline Corporation (Northwest)
tendered for filing and acceptance the following tariff sheets as part of its FERC Gas
Tariff, Third Revised Volume No., to be effective January 1, 2007.
2nd Substitute Thirty-First Revised Sheet No.
Substitute Third Revised Sheet No. 5-8
2nd Substitute Sixth Revised Sheet No. 5-C
2nd Substitute First Revised Sheet No. 5-
2nd Substitute Fourteenth Revised Sheet No.
Substitute Fifteenth Revised Sheet No.
Substitute Seventeenth Revised Sheet No.
Substitute Fifteenth Revised Sheet No. 8.
Northwest states that the purpose of this flling Is to submit tariff sheets reflecting the
rates In the Stipulation and Settlement Agreement filed by Northwest and other parties
in Docket No. RP06-416-000 and approved by the Commission on March 30, 2007.
Northwest states that copies of the filing were served on parties on the official service
list In the above-captioned proceeding.
Any person desiring to protest this filing must file in accordance with Rule 211 of the
Commission s Rules of Practice and Procedure (18 CFR 385.211). Protests to this
filing will be considered by the Commission In determining the appropriate action to be
taken. but will not serve to make protestants partJes to the proceeding. Such protests
must be filed in accordance with the provisions of Section 154.210 of the Commission
regulations (18 CFR 154.210). Anyone flUng a protest must serve a copy of that
docu~ent on all the parties to the proceeding.
The Commission encourages electronic submission of protests In lieu of paper using
the -eFlllng lhik at htto:/Iwww.ferc.aov. Persons unable to file electronically should
submit an original and 14 copies of the protest to the Federal Energy Regulatory
Commission, 888 First Street, N.E., Washington, D~C. 20426.
This fiiing is accessible on-line at http.:/Iwww.ferc.aov, using the "eLibrary" link and is
available for review in the Commission s Public Reference Room in Washington, D.
There is an -eSubscription" link on the web site that enables subscribers to receive
email notification when a document is added to a subscribed docket(s). For assistance
with any FERC Online service, please em ail FERCOnlineSup~ort~ferc.gov, or call
[phone] (toll free). For TTY. call [phone].
Ph Ills J. Posey
Acting Secretary
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 6 of 47
N~rthwt8t PfpeUne Corporation
FERC Gn Tariff
ThIrd Reviled VoIu:meNo. t
2nd Sab ThIrty-Flnt ReviKd Sheet No.
S"penedfq
lit Rev Thfrtieth Revised Shed No.
STATEMENT OF RATES
Effective Rates APPlicable to Rate Schedules TP-l, TF-2 and TI-1.
(DOll$~S pe~ Dth)
Rate Schedule and. .
Type of Rate
Base
Tariff Rate
Minimum Maximum ACA(2)
C1,1r:r:ently
EffecUve
'1"ariff Rate(3)
Minimum Maximum
Rate Schedule TP-1 (4) (5)
Reservation
(Large C\latomer)
System- W1.de 00000 37984 00000 37'84
lS Year Evergreen Exp.00000 38101 00000 38101
25 Year Evergreen Exp.00000 36445 00000 3EO445
Volumetric
(La~ge C\lstomer)
system-Wide 00756 03000 00160 00916 03160
lS Year Evergreen Exp.0036 00369 00160 0052'00529
25 Year Evergreen Exp.0036'9 00369 00160 00529 00529
(Small Customer)(Ei)00756 67209 00160 00916 673n
Scheduled OVerrun 00756 40984 00160 00916 41144
~te Schedule TF-2 (4) (5)
Reservation 00000 37984 00000 37984volumetric00756030000075603000
Scheduled Daily OVerrun 00756 40984 00756 40994
Annual OVerrun 00756 40984 00756 40984
~te Schedule TI-l
Volumetric (7)
Scheduled OVerrun
00756
00756
. "'0994
40984
00160
00160.
00916
00916
41144
41144.
baaed bf; Larm M.Ger1Kb, DandCll'
Inued GO: April!', 1007
. FDed to CODI.pq with order of the FaIer.1 Etael'lY Regulatory CommialoD,
Doeket No. RJ'O6.416.QOO t Ittued Mardi 30, 1007
Effective; Jaauary It 2007
118 FERC, 61,272 (2007)
Northwest Pipeline Corporation
FERC Gal TarHl
ThIrd Reviled Val.me No.
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 7 of 47
S..b Third Revised Sheet No. 5-B
SopenediD*
Second Reviled Sheet No. !-B
STATEMENT OF RATES (Continued)
Effective katea Applicable to Rate Schedules TP-1, TP-2 and TI-1 (Continued)
(Oollars per Dth)
P'ootnotea (Continued)
(3 )The currently effective tariff rate is
and the applicable $1.U"charges. To the
the maximum currently effective tariff
applied on a non-diacrimi~tory basis.
No. 497.
the sum of the base tariff rate
extent Transporter discounts
rate, such discounts ~ill be
subject to the policies of Order
Shippers receiving service under these rate schedules are required to
furnish fuel reimbursement in-kind at the rates apecified on Sheet
No. 14.
A "Facility Cost-or-service Charge," as defined in Section 21 of theGeneral Te~8 and Conditions, is payable in addition to all other rates
and charges if such a charge is included in Exhibit C to a Shipper I
Transportation service Agreement.
In addition to the reservation rates and surcharges shown on Sheet
No.5, Shippers who contract for Colwnbia Gorge Expan"ion Project
capacity are subject to a Facilities Reservation Surcharge pursuant to
Section 3.4 of Rate Schedule TF-l. The Facilities Charge used in
deriving the Columbia Gorge Expansion project Facilities Reservation
Surcharge has a minilllum rate of $0 and a maximum rate during
indicated months or calendar years as follows:
Year Rate Year Rate Year Ra tEl
2007 $0.15448 2013 $0.11654 2019 $0.08921
2008 $0.14830 2014 $0.11.010 2020 $0.08504
20Q!j $0.14228 2015 $0.10492 2021 $0.08135
2010 $0.13584 2016 $0.10072 2022 07741
2011 $0.12941 2017 $0.09706 2023 $0.07348
20:1.2 $0.12264 2018 $0.09314 2024 $0.06936
January 1, 2025 March 31, 2025 $0.06834
lulled by: Lareo M.GertKh, Director
IlIUM oa: AprD 10. 1007
FIled to comply with order or the Federal Energy Rqulatory COl'll~oa,
Doc:kd No. RPO6-416-000 , IllUed Marda 3Os.:z007
Efreedve; Jan~RfY I, 2007
118 FERC, 61,112 (2007)
Northwest Pipelhie CorpOl'ati(JD
FERC Ga. Tariff
Third RevIled Volume No.
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 8 of 47
2nd S\lb Sixth Revised Sheet N(J. 5-C
SlipenedInJ
Fifth Rmsed Sheet No. S-C
STATEMENT OF RATE~ (continued)
Effective Rates Applicable to Rate Schedu1es TF-l , TF-2 ~d TI-l (Continued)
(Dollars per Dth)
FOOtnote~ (Continued)
(4)All reservation rates are ~ily rates computed on the basis of 365 days
per year, except that such rates for leap year,.. are computed on the
basis of 366 days.
For Rate Schedule TF-l , the lS~Yaar and 2S~Yea~ Evergreen Expansion
reservation and volumetric rates apply to Shippers receiving service
under Rate schedule TP-l Evergreen Expansion service ~greements. The
System-Wide reservation and volumetric rates apply to Shippers receiving
service under all other Rate Schedule TF-l service agreements.
For Rate schedule TF-l, the 15-Year and 2S-Year Evergreen Expansion
maximum base tariff ~eservation rates are comprised of $0.37610 and
$0.35954 for transmission costs and $0.00491 and $0.004'1 fOr storage
costs, respectively. The System-Wide maximum base tariff reservation
rates for Rate Schedule TF-l and the maximum. base tariff reservation
rates for RAte Schedule TF-2 are comprised of $0.37493 for transmission
costs and $0.00491 for storage costs.
For Rate schedule TF~l (Large Customer). the max~mum base tariff
volumetric rates applicable to Shippers receiving service under Rate
Schedule TF-l Evergreen Expanaio~ service agreements are comprised
$0.00344 for transmission coat a and $0.00025 for storage costs. The
maximum base tariff volumetric ratea for all other services under Rate
Schedule TF-1 (Large Customer) and for services under Rate Schedule TF-2
are cOmprised of $0.02975 for transmission costa and $0.00025 forstorage costs.
(5)Rates for Rate Schedules TF-l and TP-2 are also applicable to capacity
release service. (Section 22 of the General Terms and Conditions
describes how bids for capacity release will be eva1uated.The
reservation rate is the comparable volumetric bid reservation charge
applicable to Replacement Shippers bidding for capacity released on a
one-part volumetric bid basis.
lM.cd 111: Lareu M.Gertsch, DIrector
mlltd OIII~ April 10. 2007
FDed tD t:OIIIpIy with order aI'tII, Federal EDel1)' ~lIIatory CmwnlulOIIt
Doekd No. RPO6-416-000 . I_at Mareh 30, 1007
Effective: JulW1lt 2007
118 FERC , 61,272 (2007)
Northwest Pipeline Corporation
RRC C.. Tariff
Third Revi8ed Voln.me No. ).
Exhibit No.
Case No. INT-O7-
Intermountain Gas Ccrnpn!lY
Page 9 of 47
2nd Sub Fbt Revised Sheet No. 5-D
Supenedfaa
Orl2lnal Sheet No. S-D
STATEMENT OF RATBS (Continued)
Effective Rates ~licable to Rate Schedules TP-l. TF-2 and TI-l (Continued)
(Dollars per Dth)
Footnotes (Continued)
(6)Por Rate Schedule TP-l (Small CUstomer), the maximum base tariff rate is
comprised of $0.66202 for transmission coats and $0 - 01007 for storagecosts. Transporter will not transport gas for delivery for Small
customers subject to this Rate Schedule TP-l under ' any interruptible
Service Agreement or under any capacity release Service Agreement Unless
such Small Customer haa exhausted ita daily levels of firm service
entitlement for that day.
(7 )Rate Schedule TI-l maximum base tariff volumetric rate is comprised of
$0.40468 for transmission costs and $0.00516 for storage costs.
(8)Applicable to Rate Schedules TF-l, TF-2 and TI-l pursuant
15.of the General Terms and Conditions.
Section
Juued by: L.... M.CertKh. Director
-"...ed on= AprD 18, 2007
Flied to eompIy with Order or tt., FedenJ Eaergy Retlal.tory CommhliOllo
Doc:ket No. RPO6-416-000 , blued March 30.. 2007
Efrecdve; Jao~.ry I, 2007
118 FER(: 1 ~1,27Z (::tOO7)
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 10 of 47
Northw..,.t PipeUne Corporation
FERC Gas Tariff
Third Revised Volume No.
2nd Sub Fourteenth Revised Sheet No.
SupenecfJDs
ht Rev ThIrteenth hviIed Shed No. 6
ST~'rEM8HT 011' RATES (Continued)
Bffective Rates Applicable to Rate Schedules DBX-l and PAL
(Dollars per Dth)
Type of Rate
CUrrentlyBaee EffectiveTariff Rate Tariff Rate(3)
Minimum Maximum ACA(2) Minimum Maximum
Rate Schedule DBX-l (4)
Deferred Exchange 00000 40984 00160 00160 41144
Rate Schedule PAL
Park and Loan 00000 40984 00000 40984
Footnotef:l
(1)Reserved.
(2)Section 16 of the General Terms and Conditions describes the basis aDd
applicability of the ACA surcharge.
(3 )The currently effective tariff rate is the sum of the base tariff rate
and the applicable surcharges. To the extent Transporter discounts themaxi~ currently effective tariff rate; such discounts will be applied
on a non-discriminatory basis. subject to the policies of Order No. 497-
(4 )Shippers receiving service under this" rate schedule are required to
furnish fuel reimbursement 1n-kind at the rates specified on Sheet No.
141 except as provided in Section 4 of Rate Schedule DSX-l.
I..ued. by: La.... M.Gerbeh, Diremn-
lined 011: April 10,2007
Filed to comply willi order I;Jfthe Fedml EDef"IY Regulatory CommiRloa,
Docket No. RPO6-416-GOO ,lined March 30. 2007
Effective: JanDaI")' It 2007
118 FDC , 61,,271 (1007)
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 11 of 47
Northwest Pipeline Corporation
FERC Ca. TarJff
ThIrd RevIled Volume No.
Sub Fifteenth Revised Sh~t Nt,). 7
Supenedfng
Jl'ourteeuth Revised Shed No.
. STATRMRNT OP RATES (Continued)
Effective Rates Applicable to Rate Schedules SGS-2F and SGS-2I
(Dollars per Dth)
Rate Schedule and
Type of R8.ta
CUrrently Bffective
Tariff R$.te (1)
Minimum Maximum
Rate Schedule SGS-2F (2)
Demand Charge
Capacity Demand Charge
00000
00000
01551
00056
volumetric Bid Ratea
Withdrawal Charge
Storage Charge
0 .00000
o. 00000
01551
0 . 00056
Rate Schedu1e SGS-
VolWletric 0 .00000 00113
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)R~tea ~~e 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 re1ease 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.
Issued by: Larea M.Geruch, Dlredor
Jmled 011; AprU 10. 2007
FlIed to c:omplJ with otder of the Fedenl Eneaw RA!2l1latol')' CODUIIftdoa.
Docket No. 1U'O6-416-000 . Iuued Mud 30. 2007
Effective; lan.ity 1, 2007
118 FERC 1 61;272 (:ZOO7)
Northwest PipeUne Corporation
FERC Ga. Tariff
Third RevIAed Volume No. 1
Exhibit No.
Case No. INT-O?-
Intermountain Gas Company
Page 12 of4?
Sub Seventeenth Revised Sheet No. 8
SlIpenediaa
Shteenth RevIled Sheet No. 8
STATEMENT OF RATES (Continued)
Effeotive Ratea Applicable to Rate Schedule LS-1
(Dollars per Dth)
Type of Rate
CUrrently EffectiveTariff Rate (1)
Demand Charge (2)
Capacity Charge (2)
03062
00391
Liquefaction
Vaporization 0 . 64110
0 . onu
Footnotes
(1)Shipper$ receiving service under this rate schedule are required to
furnish fuel reimbursement in-kind at the rate specified Ofi Sheet No.
14.
(2)Rate~ are daily rates computed on the basis of 365 days per . year, except
that rates for leap years are comp\lted on the basis of 366 days.
IRaN by: LIII'CD. M.Gertse", DIrector
1.lIed oa: AprD l' 2007
FUed to eompt)' wldl.order or the Federal EBert)' Replatory
No. RJ'O6.4160000 . Iuued Martb 30. 2007
Effective: ",Pilary 1, 2007
118 FERC , 61.272 (.2007)
Northwest Pipeline Corporation
FERC Gall Tariff
Third Revised Vol~ No.
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 13 of 47
Sub Fifteenth Revised Sheet No. 8.
SUl"'nediDaFo~th RevJnd Sheet No. 8.
STATEMENT OF RATBS (Continued)
Effective Rates A~plicable to Rate schedules LS-2F and LS-21
(Dollars per nth)
RAte schedule and
Type of Rate
CUrrently Effective
Tariff RAte (1)
Minimum Maximum
Rate Schedule LS-2F (3)
Demand Charge (2)
Capacity Demand Charge (2)
o. 00000 03062
00000 00391
00000 03062
00000 O. 0O3~1
64110 0 .6U10
04184 o. 041S4
Volumetric Bid Rates
Vaporization Demand-Related Charge (2)
Storage Capacity Charge (2)
Liquefaction
vaporization
R~te Schedule LB-2I
Volumetric 00000 0 - 00783
Liquefaction
Vaporization 64110
04194
64110
04184
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. (S~ction 22 of
the General Terms and Conditiona describes how bids for capacity re1ease
w~ll 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 ~Si8.
(HUed by; I.IIrm M.Gemcb., DlI'cetor
lauecl OD: AprD 10; 200'1
FUed to comply 'WItb order uribe F'edend Eoerg)' Regulatol'y CommfuloD,
~ket No. 1tf'06.416-000 t matd Mardi 311t 2007
EfrecUve: J8DU8ry 1, 2007
118 FERC, 61,272 (2007)
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 14 of 47
TransCanada Pipelines Alberta System or
Nova Gas Transmission ("Nova
Applicable Filings, Tariffs and Rate Schedules
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 15 of 47
FERC GAS TARIFF
THIRD REVISED VOLUME NO. 1-
GAS TRANSMISSION NORTHWEST CORPORATION
FILED WITH THE
FEDERAL ENERGY REGULATORY COMMISSION
Communications Concerning This Tariff
Should Be Addressed To:
John A. Roscher, Director
Rates and Regulatory Affairs
Gas Transmission Northwest Corporation
1400 SW Fifth Avenue
Suite 900
Portland, OR 97201
Telephone: [phone]
Facsimile: [phone]
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 16 of 47
Gas Transmission Northwest Corporation
FERC Gas Tariff
Third Revised Volume No. 1-
First Revised Sheet No.
Superseding
Original Sheet No.
TABLE OF CONTENTS
Third Revised Volume No. 1-Sheet No.
Preliminary Statement
Map
Statement of Effective Rates and Charges for
Transportation of Natural Gas
Rate Schedules:
FTS-Firm Transportation Service
LFS-Limited Firm Transportation Service
ITS-Interruptible Transportation Service
USS-Unbundled Sales Service
PS-Parking Service
AIS-Authorized Imbalance Service
Transportation General Terms and Conditions 100
Form of Service Agreements:
FTS -Firm Transportation Service 250
Electronic Signature for
Capacity Release 259
"",
ITS-Interruptible Transportation Service 270
PS-Parking Service 280
AI S-Authorized Imbalance Service 290
LFS-Limited Firm Transportation Service 320
Issued by: John A Roscher, Director of Rates & Regulatory Affairs
Issued on: August 4, 2004 Effective on: September 3, 2004
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 17 of 47
Gas Transmission Northwest Corporation
FERC Gas Tariff
Third Revised Volume No. 1-
Original Sheet No.
PRELIMINARY STATEMENT
Gas Transmission Northwest Corporation (GTN) is a natural gas
company which owns and operates a natural gas pipeline system extending
from the International Boundary in the vicinity of Kingsgate, British
Columbia, through parts of Idaho, Washington and Oregon to the California
boundary.
GTN offers open access transportation service under Part 284 of
the Commission's regulations in Third Revised Volume No. 1-A of this
FERC Gas Tariff. These services include transportation services
authorized by the Federal Energy Regulatory Commission as listed in the
Table of Contents.
Prior to January 1, 1998, GTN was known as "Pacific Gas
Transmission Company" or "PGT.References to Pacific Gas
Company or PGT within GTN's existing Service Agreements or
documents shall be deemed to refer to GTN.
Transmission
similar
The transportation of natural gas is undertaken by GTN only under
written service agreements acceptable to GTN after consideration
of its commitments, delivery capacity, and other pertinent factors.
This FERC Gas Tariff is filed in compliance with Part 154, Subpart E,
Title 18 of the Code of Federal Regulations.
Issued by: John A Roscher, Director of Rates & Regulatory Affairs
Issued on: October 7, 2003 Effective on: October 6, 2003
Exhibit No.
Case No. INT 07 -
Intermountain Gas Company
Page 18 of 47
Gas Transmission Northwest CorporationFERC Gas Tariff Third Substitute Ninth Revised Sheet No.
Third Revised Volume No. 1-Superseding
Second Substitute Ninth Revised Sheet No.
STATEMENT OF EFFECTIVE RATES AND CHARGES FOR
TRANSPORTATION OF NATURAL GAS
Rate Schedules FTS-1 and LFS-
RESERVATION
DAILY
MILEAGE (a)
(Dth-MILE)
DAILY
NON-MILEAGE (b)
(Dth)
DELIVERY (c)
(Dth-MILE)
FUEL (d)
(Dth)
MAXIMUM MINIMUM MAXIMUM MINIMUM MAXIMUM MINIMUM MAX I MUM MINIMUM
BASE 000612 0 . 000000 049912 000000 000037 000037 0050%0000%
STF(e)001530 000000 124780 000000 000037 000037 0050%0000%
EXTENSION CHARGES
MEDFORD
1 (f)003916 000000 014747 000000 000024 000024
2(g) 0-006517
(WWP)
000000 000000 0.000000
2 (h) 0.002972 0.000000
(Diamond 1)
000000 0.000000
2 (h) 0.001166 0.000000
(Diamond 2)
000000 0.000000
COYOTE SPRINGS
3 (i) 0.001877 0.000000 0.003652 0.000000 000000 000000
OVERRUN CHARGE (j )
SURCHARGES
ACA (k)001600 001600
Issued by: John A Roscher, Director of Rates & Regulatory Affairs
Issued on: December 29, 2006 Effective on: January 1, 2007
Filed to comply with order of the Federal Energy Regulatory Commission, Docket
No. RP06-407, issued July 31, 2006, 16 FERC ~ 61,109
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 19 of 47
Gas Transmission Northwest CorporationFERC Gas Tariff Substitute Fourth Revised Sheet No.
Third Revised Volume No. I-Superseding
First Revised Third Revised Sheet No.
STATEMENT OF EFFECTIVE RATES AND CHARGES FOR
TRANSPORTATION OF NATURAL GAS (a)
Rate Schedule ITS-
MILEAGE (n)
(Dth-Mile)
NON-MILEAGE (0)
(Dth)
FUEL (d)
(Dth)
MAXIMUM MINIMUM MAXIMUM MINIMUM MAXIMUM MINIMUM
BASE 0 . 001567 000037 124780 000000 0050%0000%
EXTENSION CHARGES
MEDFORD
(Medford)(f)
0 - 003940 000024 014747 000000
COYOTE SPRINGS
(Coyote Springs)(i)
001877 000000 003652 000000
SURCHARGES
ACA (k)
001600 001600
(Continued)
Issued by: John A Roscher, Director of Rates & Regulatory Affairs
Issued on: December 29, 2006 Effective on: January I, 2007
Filed to comply with order of the Federal Energy Regulatory Commission, Docket
No. RP06-407 , issued July 31, 2006, 16 FERC ~ 61,109
Exhibit No.
Case No. INT-07-
Intermountain Gas Company
Page 20 of 47
Gas Transmission Northwest Corporation
FERC Gas Tariff
Third Revised Volume No. I-
Eighth Revised Sheet No.
Superseding
Seventh Revised Sheet No.
STATEMENT OF EFFECTIVE RATES AND CHARGES
FOR TRANSPORTATION OF NATURAL GAS
Notes:
(a) The mileage component shall be applied per
transported by GTN for delivery to shipper
and delivery points in Shipper's contract.
Sheet 3 for receipt and delivery point and
pipeline
based on
Consul t
milepost
mile to gas
the primary receipt
GTN' s system map on
designations.
(b) The non-mileage component is applied per Shipper s MDQ at Primary
Point (s) of Delivery on Mainline Facilities.
(c) The delivery rates are applied per pipeline mile to gas transported by
GTN for delivery to shipper based on distance of gas transported.
Consul t GTN' s system map on Sheet No.3 for receipt and del i very point
and milepost designations.
(d) Fuel Use: Shipper shall furnish gas used for compressor station fuel,
line loss, and other utility purposes, plus other unaccounted-for gas
used in the operation of GTN' s combined pipeline system in an amount
equal to the sum of the current fuel and line loss percentage and the
fuel and line loss percentage surcharge in accordance with Paragraph
of this tariff, multiplied by the distance in pipeline miles transported
from the receipt point to the delivery point multiplied by the
transportation quantities of gas received from Shipper under these rate
schedules. The current fuel and line loss percentage shall be adjusted
each month between the maximum rate of 0.0050% per Dth per pipeline mile
and the minimum rate of 0.0000% per Dth per mile. The fuel and lineloss percentage surcharge is 0.0000% per Dth per pipeline mile. No fuel
use charges will be assessed for backhaul service. The incremental fuel
surcharge, initially established for Shippers utilizing capacity
constructed as part of GTN's 2002 Pipeline Expansion Project at
000854% per Dth per pipeline mile, shall be adjusted downward as new
long-term Shippers take capacity that is subject to the incremental fuel
surcharge pursuant to Paragraph 38 of GTN's General Terms andConditions. Currently effective fuel charges, including GTN's currently
effective incremental fuel surcharge, may be found on GTN's Internet
website under Informational Postings.
(e) Maximum reservation rates for Short-Term Firm service under Rate
Schedule FTS-l are equal to two and one-half times the applicable non-
mileage and mileage FTS-l Base Reservation components.
(f) Applicable to firm service on GTN's Medford Extension.
(Continued)
Issued by: John A Roscher, Director of Rates & Regulatory Affairs
Issued on: June 30, 2006 Effective on: August 1, 2006
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 21 of 47
Gas Transmission Northwest Corporation
FERC Gas Tariff
Third Revised Volume No. 1-
First Revised Sheet No.
Superseding
Original Sheet No.
STATEMENT OF EFFECTIVE RATES AND CHARGES
FOR TRANSPORTATION OF NATURAL GAS
Notes:(Continued)
(g)
Under the terms of the July 29, 1994 Agreement (Agreement)
between GTN and The Washington Water Power Company (WWP)
(expressly incorporated herein), the initial negotiated rate is
$0.163955 per Dth-mile, which is designed by dividing first-year
annual revenues of $3.9 million by Dth-mile demand billing
determinants of 23,787,000 (22,500 Dth/d x 12 months x 88.1 miles) .
Each year thereafter , until the end of the primary term of the
Agreement, the rate shall increase or decrease by the same overall
percentage increase or decrease in a "Benchmark" rate based on
PacifiCorp I s average electric rate in effect during the preceding
contract year under its Residential Rate Schedule 4, or superseding
Rate Schedule (or those of its subsidiaries, successors, assigns, or
of substitute service providers) applicable to residential heating
service for a residential customer utilizing 1,000 kilowatt hours permonth. That Benchmark rate shall encompass all of . the rate components
of the aforementioned Rate Schedule. The Agreement provides forrecovery of any "deficiency " amounts (plus carrying costs at GTN'
allowed rate of return on investment for the applicable
period) over the primary term of the Agreement to the extent permitted
by increases in the foregoing electric rates. WWP r s first-year
deficiency amount of $3.394 million is equal to WWP's revenue
responsibility at the maximum E-(Medford) rates, or $7.294 million
((22,500 Dth/d x 12 months x 88.1 miles x maximum Reservation Charge)
+ (22,500 Dth/d x 365 days x 88.1 miles x 95% load factor x maximum
Delivery Charge)), less WWP I s first-year revenue responsibility of
$3.9 million. For each contract year after the end of the primary
term of the Agreement, the rate shall equal GTN '
then-effective rate as set forth in the applicable tariff for firm
transportation service on the Medford Extension. In the event that
GTN recovers the "deficiency " amounts of the Firm
Transportation Service Agreement during the primary term, WWP shall
pay the then-applicable tariff rate for firm transportation service
on the Medford Extension (E-1) or successor rate. GTN shall
file an annual report with the Commission specifying (a) the
calculation of the Medford Extension cost-of-service; (b) the
revenues collected under the Medford (E-2) Rate; (c) the deferred
cost recovery mechanism account balance, including carrying charges;
and (d) workpapers detailing the computations.(h) Applies to Diamond Energy service, which commences 1998.
Rate is negotiated reservation charge of $0.002972 per Dth per day for
first 45,000 Dth/d and $0.001166 per Dth per day for the second 45,000Dth/d. Revenues will be applied to annual revenue requirement on the
Medford Extension.
(Continued)
Issued by: John A Roscher, Director of Rates & Regulatory Affairs
Issued on: November 30, 2006 Effective on: January 1, 2007
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 22 of 47
Gas Transmission Northwest Corporation
FERC Gas Tariff
Third Revised Volume No. 1-
Fifth Revised Sheet No.
Superseding
Fourth Revised Sheet No.
STATEMENT OF EFFECTIVE RATES AND CHARGES
FOR TRANSPORTATION OF NATURAL GAS
Notes: (Continued)(i) Applicable to firm service on GTN's Coyote Springs
Extension.
(j)
The Overrun Charge shall be equal to the rates and charges
set forth for interruptible service under Rate Schedule ITS-(k) In accordance with Paragraph 22 of the Transportation General
Terms and Conditions of this FERC Gas Tariff, Third Revised Volume
No. 1-A, all Transportation services that involve the physical movement of
gas shall pay an ACA unit adjustment of $0.0016 per Dth. This adjustment
shall be in addition to the Base Tariff Rate (s) specified above.
(1)Daily reservation charges will be reset for leap years.
(m)Reserved.
(n) The Rate Schedule ITS-1 Mileage Component shall be
applied per pipeline mile to gas transported by GTN
based on the distance of gas transported. Consult GTN' s
system map on Sheet No.3 for receipt and deliverypoint and milepost designations.
(0) The Rate
applied .per Dth
delivery to thefacility
Schedule ITS-1 Non-Mileage Component shall be
of gas transported by GTN for immediate
facilities of another entity or an extension
(Continued)
Issued by: John A Roscher, Director of Rates & Regulatory Affairs
Issued on: November 30, 2006 Effective on: January 1, 2007
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 23 of 47
Gas Transmission Northwest ("GTN"
Applicable Tariffs and Rate Schedules
NOVA Gas Transmission Ltd.
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 24 of 47
GAS TRANSPORTATION TARIFF
NOVA GAS TRANSMISSION LTD.
TARIFF Effective Date: November 1, 2005 as per EUB Order U2005-391
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 25 of 47
NOVA Gas Transmission Ltd.Page i
GAS TRANSPORTATION TARIFF
NOVA GAS TRANSMISSION LTD.
Please address communications concerning this Tariff to:
Nay A Gas Transmission Ltd.
450 First Street S.
Calgary, Alberta
TIP 5Hl
Attention:Greg Szuch
TARIFF Effective Date: November 1 2005 as per EUB Order U2005-391
NOVA Gas Transmission Ltd.
Exhibit No.
Case No.fNT-O7-
Intermountain Gas Company
Page 26 of 47
Page ii
Tab 1
Tab 2
Tab 3
Tab 4
TABLE OF CONTENTS
Table of Rates, Tolls and Charges
Rate Schedules
Rate Schedule FT-
Rate Schedule FT-
Rate Schedule FT-
Rate Schedule FT-
Rate Schedule FT.;A
Rate Schedule FT - X
Rate Schedule STFT
Rate Schedule FT-
Rate Schedule LRS
Rate Schedule LRS-
Rate Schedule LRS-
Rate Schedule IT-
Rate Schedule IT-
Rate Schedule IT-
Rate Schedule FCS
Rate Schedule
Rate Schedule CO2
Rate Schedule PT
Firm Transportation - Receipt
Firm Transportation - Receipt Non-Renewable
Firm Transportation - Delivery
Firm Transportation - Delivery Winter
Firm Transportation - Alberta Delivery
Firm Transportation - Extraction
Short Term Firm Transportation - Delivery
Firm Transportation - Alberta Points to Point
Load Retention Service
Load Retention Service - 2
Load Retention Service - 3
Interruptible - Receipt
Interruptible - Delivery
Interruptible - Access to Storage
Facility Connection Service
Other Service
CO2 Management Service
Pressure / Temperature Service
General Terms and Conditions
Appendices
Appendix A
Appendix B
Appendix C
Appendix D
Appendix E
Appendix F
Appendix G
Appendix H
Terms and Conditions Respecting Access to
Transportation Service at Export Delivery Points
Terms and Conditions Respecting Relief for
Mainline Capacity Restrictions
Terms and Conditions Respecting Title Transfers
Terms and Conditions Respecting Customer
Inventories and Related Matters
Criteria for determining Primary Term
Notice of Schedule for Electronic Commerce
Terms and Conditions Respecting Allocation of Gas
as Emergency Response Compensation
Terms and Conditions Respecting CO2
Management Service
TARIFF Effective Date: November 1, 2005 as per EUB Order U2005-391
NOVA Gas Transmission Ltd.
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 27 of 47
Table of Rates, Tolls and Charges
TABLE OF RATES, TOLLS & CHARGES
Service Rates, Tolls and Charges
Rate Schedule FT-Refer to Attachment "1" for applicable FT-R Demand Rate per month & Surcharge for
each Receipt Point
Average Finn Service Receipt Price (AFSRP)$158.09/103
Rate Schedule FT-Refer to Attachment "1" for applicable FT-RN Demand Rate per month & Surcharge
for each Receipt Point
Rate Schedule FT-FT-D Demand Rate per month 18/GJ
Rate Schedule STFT STFT Bid Price.Minimum bid of 100% ofFT-D Demand Rate
Rate Schedule FT-FT-DW Bid Price.Minimum bid of 125% ofFT-D Demand Rate
Rate Schedule FT-FT-A Commodity Rate 0.47/1O3
Rate Schedule FT-Refer to Attachment "2" for applicable FT-P Demand Rate per month
Rate Schedule LRS Contract Tenn Effective LRS Rate ($/1O3 /day)
5 years
10 years
15 years 7.41
20 years 6.57
Rate Schedule LRS-LRS-2 Rate per month $50 000
10. Rate Schedule LRS-LRS-3 Demand Rate per month $129.55/l03
11. Rate Schedule IT-Refer to Attachment "1" for applicable IT-R Rate & Surcharge for each Receipt Point
12. Rate Schedule IT-IT-D Rate 1513/GJ
13. Rate Schedule FCS The FCS Charge is determined in accordance with Attachment "1" to the applicable
Schedule of Service
14. Rate Schedule PT Schedule No PT Rate PT Gas Rate
9006-01000-12.37/d 1.0 1O3
15. Rate Schedule OS Schedule No.Charge
2003034359-899./ month
2007262666-434./ month
2007262711-/ month
2007262709-303./ month
2007262728-859./ month
2007262705-220./ month
2007263949-46./ month
2007262175-437./ month
2007262669-95./ month
2007262602-/ month
2007262701-/ month
2007262727-17./ month
2007262698-43./ month
2007262609-/ month
2007262668-19./ month
2007262697-760./ month
2007263948-90./ month
2003004522-83,333./ month
16. Rate Schedule CO2 Tier CO, Rate ($/1O3
606.
484.
335.49
TARIFF Effective Date: April 1 , 2007 as per EUB Order U2007 -
Exhibit No.
Case No. INT-07-
Intermountain Gas Company
Page 28 of 47
~EUBAIbertaEnergvandUtilitieSBoard Miscellaneous Rates Non-Routine
Order U2007 - 76
MADE at the City of Calgary, in the
Province of Alberta, on
21 st day of March 2007.'ff\JJV~
ALBERTA ENERGY AND UTILITIES BOARD
NOVA Gas Transmission Ltd. (NGTL)
Application for 2007 Final Rates, Tolls and
Char es lication No. 1504975
INTRODUCTION
NOVA Gas Transmission Ltd. (NGTL) filed an application (the Application), dated March 1
2007 , with the Alberta Energy and Utilities Board (Board), for the approval of 2007 final rates,
tolls and charges (2007 Final Rates) for the Alberta System services provided by NGTL from
Apri11 , 2007 to December 31 2007 (the Application). NGTL had been providing services under
2007 Interim rates, tolls and charges (2007 Interim Rates) approved by the Board in
Order U2006-334. In that Order, the Board stated that the 2007 Interim Rates would be effective
January 1 , 2007 until NGTL's 2007 Final Rates were approved by the Board.
PARTICULARS OF THE APPLICATION
In Decision 2005-057, the Board approved NGTL's Revenue Requirement Settlement for 2005
2006 and 2007 (the Settlement), whereby the 2007 revenue requirement was to be calculated
based on certain costs fixed pursuant to the Settlement and a forecast of remaining costs that
would flow through, adjusted for appropriate deferral account balances.
NGTL submitted that the applied for 2007 Final Rates are reasonable as they were based on:
. A 2007 revenue requirement of $1 ,127.9 million detennined in accordance with the
Settlement (calculation included in the Application as Attachment A);
Forecast 2007 contract demand quantities and throughput (included in the Application as
Attachment B);
The rate design approved by the Board in Decision 2006-010 (illustrative calculation
included in the Application as Attachment C); and
2007 annual rates adjusted to account for three months of 2007 Interim Rates charged
from January 1 to March 31 , 2007 (schedule included in the Application as
Attachment D).
EUB Order U2007.Page 1 of 2
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 29 of 47
NGTL filed a revision to the Application (Amended Application), dated March 13 2007 , as a
result of determining that the final rates for a few receipt meter stations, shown in Appendix E of
the Application, did not reflect the floor and ceiling rates for Ff-R service and needed to be
adjusted by less than $O.OOl/Mcf/d. NGTL filed the amended Table of Rates, Tolls and Charges
in an attachment to the Amended Application.
In the Notice of Application, issued on March 7 2007, the Board requested that interested parties
provide submissions with respect to the Application by March 14, 2007 and that NGTL provide
any responses to those submissions by March 19, 2007.
Submissions were made by the BP Canada Energy Company, the Consumers Coalition of
Alberta, Gas Alberta Inc. and by Bryan & Company on behalf of Alberta Urban Municipalities
Association, the City of Edmonton and the Office of the Utilities Consumer Advocate. These
parties registered as interested parties in the proceeding, but none identified any concerns with
the Amended Application or otherwise objected to the 2007 Final Rates. By way of a letter
dated March 16 2007, NGTL requested that given the absence of any intervener concerns or
objections, the Board continue to process and approve the Amended Application as filed, to
enable the applied for 2007 Final Rates to be effective April I, 2007.
VIEWS OF THE BOARD
The Board finds that the 2007 revenue requirement proposed in the Application was determined
in accordance with the 2005-2007 Settlement approved by the Board in Decision 2005-057 and
the 2007 Final Rates were determined based on the rate design approved by the Board in
Decision 2006-010. The applied for 2007 revenue requirement of $1,127.9 million is based on
the latest estimate of costs for 2007, and is $48.2 million, or 4.5%, higher than the 2006 revenue
requirement. In addition, NGTL submitted that the contract and volume information is based on
the most recent information available for 2007. The applied for final 2007 average Ff-R and
Ff-D services rates, effective April 1 , 2007, will be $0. 146/Mcf/d and the applied for average
final 2007 export rate will be $0.292/Mcf/d. The forecast Ff-R and Ff-D rates are
approximately 12% higher than the previously approved 2006 Final Rates.
The Board notes that there are no objections to the Amended Application. From this it can be
generally accepted that the Application is within the public interest. The Board is satisfied that
NGTL has included all necessary supporting schedules for the Board to make its final
determination respecting NGTL's 2007 Final Rates. Based upon a review of the schedules, the
Board agrees with NGTL that the 2007 Final Rates proposed in the Application are just and
reasonable. Therefore, the Board approves NGTL's 2007 Final Rates as of April 1 , 2007.
ORDER
(1)The 2007 final rates, tolls and charges of NOY A Gas Transmission Ltd., attached as
Appendix 1 to this Order, and filed with the Amended Application, are approved as filed
and come into effect on April 1, 2007.
END OF DOCUMENT
Page 2 of 2 EUB Order U2007.
Exhibit No.
Case No. INT-07-
Intermountain Gas Company
Page 30 of 47
2007 Final Rates, Tolls and Char Effective April 1, 2007
TABLE OF RATES, TOLLS & CHARGES
Service Rates, Tolls and Charges
Rate Schedule FT-Refer to Attachment "I" for applicable FT-R Demand Rate per month & Surcharge for
each Receipt Point
Average Finn Service Receipt Price (AFSRP)$ 158.09/1O3
Rate Schedule FT-Refer to Attachment "1" for applicable FT-RN Demand Rate per month & Surcharge
for each Receint Point
Rate Schedule FT-FT-D Demand Rate per month 18/GJ
Rate Schedule STFT STFT Bid Price.Minimum bid of 100% ofFT-D Demand Rate
Rate Schedule FT-FT-DW Bid Price.Minimum bid of 125% ofFT-D Demand Rate
Rate Schedule FT-FT -A CommoditY Rate 0.47/l0
Rate Schedule FT-Refer to Attachment "2" for applicable FT-P Demand Rate per month
Rate Schedule LRS Contract Tenn Effective LRS Rate ($/1O3 /day)
5 years
10 years
15 years 7.41
20 years
Rate Schedule LRS-LRS-2 Rate per month $50 000
10. Rate Schedule LRS-LRS-3 Demand Rate per month $ 129.55/103n?
11. Rate Schedule IT-Refer to Attachment "I" for applicable IT-R Rate & Surcharge for each Receipt Point
12. Rate Schedule IT-IT-D Rate 0.1513/GJ
13. Rate Schedule FCS The FCS Charge is detennined in accordance with Attachment "I" to the applicable
Schedule of Service
14. Rate Schedule PT Schedule No PT Rate PT Gas Rate
9006-01000-12.37/d 1.01O
15. Rate Schedule OS Schedule No.Charge
2003034359-899./ month
2007262666-434./ month
2007262711-/ month
2007262709-303./ month
2007262728-859./ month
2007262705-220./ month
2007263949-46./ month
2007262175-437./ month
2007262669-95./ month
2007262602-/ month
2007262701-/ month
2007262727-17./ month
2007262698-43./ month
2007262609-/ month
2007262668-19./ month
2007262697-760./ month
2007263948-90./ month
2003004522-333./ month
16. Rate Schedule CO2 Tier CO, Rate ($/10
606.
484.
335.49
EUB Order U2007-76
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 31 of 47
NOVA Gas Transmission Ltd.
Appendix 1 . Attachment 1
2007 Final Rates, Tolls and Charges Page 1
Effective April 1, 2007
Receipt R Demand RN Demand IT-R Rate
Point Rate per Month Rate per Month per Day
Number Recei t Point Name ($/10 ($/10 $/10
1337 ABEE 244.268.
1631 ACADIA EAST 108.119.
1613 ACADIA NORTH 109.120.
1424 ACADIA VALLEY 155.171.
3880 AECO INTERCONNECTION 71.78.
1526 AKUINU RIVER 244.46 268.
1681 AKUINU RIVER W.244.46 268.
3868 ALBERTA MONTANA BORDER 89.98.
2000 ALBERTA-C. BDR (CHART ACCO 71.78.
2109 ALDER FLATS 91.100.
2200 ALDER FLATS S.89.98.
1075 ALDERSON 78.86.46
1208 ALDERSON NORTH 80.88.
1103 ALDERSON SOUTH 78.86.
5026 ALGAR LAKE 244.46 268.
1851 AMISK SOUTH 213.235.
1469 ANDREW 157.173.49
1573 ANSELL 124.136.
2136 ANTE CREEK S.244.46 268.
1567 ARMENA 244.46 268.
1770 ARMSTRONG LAKE 244.46 268.
2708 ASSUMPTION 244.46 268.
2734 ASSUMPTION #2 244.46 268.
1326 A THABASCA 230.253.
1368 ATHABASCA EAST 220.243.
1009 ATLEE-BUFFALO 71.78.89 .
1116 ATLEE-BUFFALO E 71.78.
1098 ATLEE-BUFFALO S 71.78.
1297 ATMORE 207.227.
1792 ATUSIS CREEK E 71.78.
3489 ATUSIS CREEK SL 71.78.
1275 BADGER EAST 71.78.
1649 BADGER NORTH 89.98.
2744 BALLA TER #2 244.46 268.
1100 BANTRY 71.78.
1296 BANTRY N.71.78.
1181 BANTRY N.71.78.
1122 BANTRY NORTH 71.78.
1398 BAPTISTE 236.260.
1339 BAPTISTE SOUTH 244.46 268.
1497 BARICH 244.46 268.
1329 BASHAW 113.124.
1393 BASHAW B 113.124.
1330 BASSANO SOUTH 90.99.
1794 BASSANO SOUTH 2 90.99.
2761 BASSET LAKE 244.46 268.
2085 BASSET LAKE S.244.46 268.
2066 BASSET LAKE W.244.46 268.
1197 BAXTER LAKE 244.46 268.
1334 BAXTER LAKE B 244.46 268.
1382 BAXTER LAKE NW 244.46 268.
1231 BAXTER LAKE S.244.46 268.
1198 BAXTER LAKE W.244.268.
2143 BAY TREE 244.268.
2222 BEAR CANYON W.216.45 238.
2132 BEAR RIVER 244.46 268.
1459 BEAUVALLON 244.46 268.
EUB Order U2007.
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 32 of 47
TransCanada Pipelines B.C. System
or Foothills Pipeline System ("Foothills
formerly Alberta Natural Gas (" ANG"
Applicable Filings , Tariffs and Rate Schedules
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 33 of 47
TRANSCANADA PIPELINES LIMITED
GAS TRANSPORTATION SERVICE DOCUMENTS
FOR THE B.C. SYSTEM
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 34 of 47
National Energy
Board
Office national
de I'energie
File OF-FAC-GAS-F111-2006-0101
21 March 2007
Ms. Kristine Delkus
Deputy General Counsel
TransCanada PipeLines Limited
450 - 1 st Street S.
Calgary, AB T2P 5H1
Facsimile 403-920-2409
Dear Ms. Delkus:
TransCanada PipeLines Limited (TransCanada)
Foothills Pipe Lines Ltd. (Foothills)
Foothills Pipe Lines (South B.C.) Ltd. (Foothills South B.C.
TransCanada B.C. System (B.C. System)
Application for Leave to Transfer Ownership of the B.c. System and Related
Approvals
Further to the Board's letter dated 9 February 2007 and your letter dated 6 March 2007, attached
is Order TG-03-2007, which reflects the Board's approvals relating to tolls, tariffs, depreciation
rates, service agreements and the Foothills Settlement.
TransCanada is reminded to provide confirmation once the sale and conveyance is complete.
The Board will then amend and seek Governor in Council approval with respect to the
Certificates of Public Convenience and Necessity.
The Applicants are directed to serve a copy of this letter on all B.C. System and Foothills
shippers and interested parties.
Yours truly,
Michel L. Mantha
Secretary
Attachment
444 S$verilh Avenue SW
Ca:1gary,.Alberta T2POX6
4#, SeptiemeAvenueS.-O.
Calgary (Alberta)T2P oXa Canada
TeJephorieITelephone: 403-292.4800
FacsirnilelTelecopieUr :4o34.92.S5Q3
http1l www,I'Ie/J-:one .gc.
Te!ephonelTelephone: 1-aOO-a~9"126$
FacsimileITeleoopieur: 1-a77"28a43a.Q3
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 35 of 47
National Energy
Board
Office national
de I'energie
ORDER TG-O3-2007
IN THE MA TIER OF the National Energy Board Act and the
regulations made thereunder; and
IN THE MATTER OF an application by Foothills Pipe Lines Ltd.
(Foothills) dated 21 December 2006 for approval of final rates for
Foothills Zones 6, 7 8 and 9 effective 1 Apri12007 pursuant to Part IV
of the Act and related orders filed with the National Energy Board
under file OF-FAC-GAS-FIII-2006-01O1;
BEFORE the Board on 9 February 2007.
WHEREAS the Board issued Order TG-02-2007, for Foothills fmal rates effective
1 January 2007;
AND WHEREAS Foothills on 21 December 2006 filed an application for revised final rates
effective the Closing Date of the transfer of TransCanada s B.C. System to Foothills (Closing
Date);
AND WHEREAS by letter dated 6 March 2007, TransCanada advised the Board that the Closing
Date will be 1 April 2007;
AND WHEREAS Foothills has provided copies of this application to its shippers;
AND WHEREAS the Board letter of 11 January 2007 sought comments from interested parties
on the application;
AND WHEREAS no party has opposed the application;
AND WHEREAS the Board has found that the applied-for rates are just and reasonable;
IT IS ORDERED THAT effective the Closing Date:
1. The amendment of the Foothills Settlement approved by the Board on 6 March 2003, in
accordance with the provisions of the Integration Settlement, is approved.
2. The depreciation rates contained in Appendix C of the application are approved pursuant
to subsection 55(1) of the Gas Pipeline Uniform Accounting Regulations.
3. The amendments, as proposed in Appendix D of the application, to the Foothills Gas
Transportation Tariff are approved.
.. ./2
Canada
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 36 of 47
- 2-
4. The B.c. System transportation service agreements assigned to Foothills by TransCanada
are deemed to be amended as required to align with the Foothills Tariff.
5. The applied for rates shown in Appendix "B" of the 6 March 2007 letter are approved.
6. Foothills is authorized to refund or recover any variances between revenue received and
costs of service incurred for the B.C. System and Foothills South B.C. System from 2006
to the Closing Date.
7. Foothills shall be regulated on a complaint basis and interested parties shall, within 15
days of being served with proposed rates, notify the Board and Foothills whether they
wish to make representation to the Board respecting said submission.
8. Amendments to the Foothills Subsidiary Company Tariffs necessary to align those tariffs
with the Foothills Gas Transportation Tariff are approved pursuant to section 59 of the
Act.
NATIONAL ENERGY BOARD
Michel L. Mantha
Secretary
TG-O3-2007
Foothills Pipe Lines Ltd.
PHASE I
GAS TRANSPORTATION TARIFF
FOOTIDLLS PIPE LINES LTD.
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 37 of 47
Page 1
This Gas Transportation Tariff is subject to the National Energy Board Act, is available for
inspection during normal business hours and is also available electronically at
www.transcanada.com. Communications concerning this Gas Transportation Tariff should be
addressed to:
Foothills Pipe Lines Ltd.
450 First Street S.
Calgary, Alberta
T2P 5Hl
Attention: Greg Szuch
TARIFF - PHASE I Effective Date: April!, 2007
Foothills Pipe Lines Ltd.
Tab 1
TABLE OF CONTENTS
Foothills Pipe Lines Ltd.
Description of Company and Services Rendered
Map of Foothills Gas Transportation System - Phase I
Summary of Rate Schedules
Tab 2 Table of Effective Rates
Tab 3 Capacity Allocation Procedures
Tab 4 Rate Schedules
STFT
SGS
TabS
Firm Transportation Service
Short Term Firm Transportation Service
Overrun Transportation Service
Small General Service
Interruptible Transportation Service
General Terms and Conditions
Tab 6 Pro Forma Service Agreements
STFT
SGS
Supplement I:
Supplement ll:
Supplement ill:
Firm Transportation Service
Short Term Firm Transportation Service
Small General Service
Interruptible Transportation Service
FOOTHILLS PIPE LINES (ALTA.) LTD.
FOOTHILLS PIPE LINES (SOUTH B.C.) LTD.
FOOTHILLS PIPE LINES (SASK.) LTD.
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 38 of 47
e 2
TARIFF - PHASE I Effective Date: April 1, 2007
Foothills Pipe Lines Ltd.
TABLE OF EFFECTIVE RATES
1. Rate Schedule FT, Firm Transportation Service
Demand Rate
($/GJ/Km/Month)
0055477708Zone 6
Zone 7 0078623962
0133106152Zone 8*
Zone 9 0097795647
2. Rate Schedule OT, Overrun Transportation Service
Commodity Rate
($/GJIKm)
0002006317
0002843387
Zone 6
Zone 7
3. Rate Schedule IT, Interruptible Transportation Service
Commodity Rate
($/GJ/Km)
0004813702
0003536719
Zone 8*
Zone 9
*For Zone 8, Shippers Haul Distance shall be 170.7 kill.
Exhibit No.
Case No. INT -07 -
Intermountain Gas Company
Page 39 of 47
Page 1
TARIFF - PHASE I Effective Date: Aprill, 2007
6- "h; TransCanada
" .u In bInin~ to
Exhibit No.
Case No. INT-07-
Intermountain Gas Company
Page 40 of 47
TransCanada - Customer Express - Pricing & Tolls - BC System
TransCanada Home ~ Gas Transmission ~ Customer Express
Pricing & Tolls - Foothills-BC
Notice: On April 1 , 2007, TransCanada integrated the B.C. and Foothills pipeline systems. As a result of the integration, the content
the B.C. and Foothills pages on Customer Express will be changing over the next few months. This change may affect any existi
bookmarks you currently have to these pages. More...
TransCanada s - Foothills-BC Rates
2007 Final Rates Effective April 1, 2007
"'i'customerExpress
Your tnnnttttion to
comnuntial information
Service Tariff Rate Information Purposes
rt/GJ/d
(Cdn)
I/:/Mcf/d
(Cdn)
I/:/MMBtu/d
(US)
Firm Service (A/BC to Kingsgate)
FT Rate 0133106152 ($/GJ/Month/Km)
Interruptible Service (A/BC to Kingsgate)
IT Rate 0004813702 ($/GJ/Km)
1. For information purposes, the maximum Shipper s Haul Distance used in the Shipper s monthly charge for Service calculation is
170.7 km.
2. Rates are payable in Canadian dollars and GJ units are used for billing purposes. Met and MMbtu units are provided for
information purposes only.
3. Conversion Factors below have been used to calculate the rates provided for information purposes:Cdn$/US$ 1.15 - subject to change (updated Mar 2/06)q:/GJ to ct/MMBtu x 1.0550564. Rates do not include G.
5. Inquiries regarding the BC System may be directed to:
Bruce Newberry at 403.920.5579
Dan Morrison at 403.920.6139
Other information for TransCanada s BC System:
Current
Fuel Rates & Heating Values
Archives
.. Rates: 2006 "\II 2005 ill 2004 "\I
.. AB Border Heat Values
..
Fuel Rates & Heating Values
..
AB Border Heat Values
Disclaimer:'rt dng al14 taUs infermatioti inckIdOd imthisweI!Sitt!is inbm. ded to be . tid for piart il1ll Pll~
(!(~
nrtly ,ant! "'fthoupTriU11i&tiada endeavours to mailitldn ttm ii'ifannatian irtSlle!\ a way that is a~W"at~ and: tcuf't1Wtt1 it may I1IOt provldaacturirtEi resmt\!l. USe Of tlits infun'ita:tl:Cn is ~t USer s sOIa risk and TranSCalliiildasl'i~1 not be; liable for I.f!i;er s 1.100, IOf rnlianceon any re!lsutt& obtaitN!1d ff1:lm it.
http://www.transcanada.com/Customer Exoress/oricina tolls/bc.html 7/27/2007
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 41 of 47
Questar Pipeline Company ("Questar
Applicable Tariffs and Rate Schedules
Exhibit No.
Case No. INT-O7-
Intermountain, Gas Company
Page 42 of 47
FERC GAS TARIFF
FIRST REVISED VOLUME NO.
(SUPERSEDES ORIGINAL VOLUME NOS. 1, 1-A, 2 AND 2-
QUE STAR PIPELINE COMPANY
Filed with
FEDERAL ENERGY REGULATORY COMMISSION
CommuniGations regarding this tariff should be addressed to:
L. G. Wright, Director, Regulatory Affairs
Questar Regulated Services Company
180 East 100 South
P. O. Box 45360
Salt Lake City, Utah 84145-0360Telephone: [phone]FAX: [phone]
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 43 of
Questar Pipeline Company
FERC Gas Tariff
First Revised Volume No.
Third Revised Sheet No.
Superseding
Second Revised Sheet No.
PRELIMINARY STATEMENT
Questar Pipeline Company (Questar) is a natural-gas transmission
company that provides transportation and storage services in Utah, Colorado
and Wyoming.
This Federal Energy Regulatory Commission (FERC) Gas Tariff, First
Revised Volume No.1 (tariff) includes general terms and conditions, rate
schedules and forms of agreements for the transportation services provided by
Questar, according to 18 C.R. Part 284, Subparts Band G, under Rate
Schedules T-1, NNT, and T-2; open-access storage services at Questar's peaking
and Clay Basin storage fields under Rate Schedules PKS, FSS and ISS and park
and loan service under Rate Schedules PALl and PAL2.
Issued by: R. Allan Bradley, President and COO
Issued on: May 19, 2005 Effective on: June 21, 2005
Questar Pipeline Company
FERC Gas Tariff
First Revised Volume No.
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 44 of 47
Forty-First Revised Sheet No.
Superseding
Fortieth Revised Sheet No.
STATEMENT OF RATES
Rate Schedule/
Type of Charge
(a)
TRANSPOR TATION
FIRM TRANSPORTATION - T-
Systemwide Monthly Reser vation
Maximum
Minimum
SSXP Mon thly Reservation Charge ~/
Maximu m
Minimum
Charge
Usage Charge
Maximum
Minimum
Systemwide Authorized Overrun Charge
Maximu m
Minimum
Systemwide Unauthorized Overrun Charge
Critical
Non-Critical
SSXP Authorized Overrun Charge
Maximum
Minimum
SSXP Unauthorized Overru n Charge
Critical
Non-Cr itical
PARKING AND LOANING SERV ICE - PAL2
Initiation Charge
Maximum
Minimum
Daily Inventory Charge
Maximum
Minimum
NO-NOTICE TRANSPORTATION - NNT
Monthly Reservation Char ge
Maximum
Minimum
INTERRUPTIBLE TRANSPORTA TION- T-
Systemwide Usage Charge
Maximu m
Minimum
Systemwi de Unauthorized Overrun ChargeCritical
Non-Critical
SSXP Usage Charge ~/
Maximum
Minimum
SSXP Unauthorized Overru n Charge
Critical
Non-Critical
Base
Tariff
Rate ($)
(b)
Annual
Charge
Adjustment 1/ ($)
(c)
28804
00000
82712
00000
00267
00267
00165
00165
17652
00267
00165
00165
10.00000
35304
26000
00267
00165
00165
10.00000
52000
20846
03276
17570
00000
86753
00000
17652
00267
00165
00165
10.00000
35304
26000
00267
00165
00165
10.00000
52000
for Rate Schedules T-l and T-2. FUEL REIMBURSEMENT - 1.94% in-kind
OPTIONAL VOLUMETRIC RELE ASES
FIRM TRANSPORTATION - T-
Systemwide Volumetric Ch arge
Maxim urn
Minimum
SSXP Vol umetric Charge
Maximum
Minimum
Pipeline Usage Charges A pplicable to Vol umetric Releases
Maximum
Minimum
17385
00000
25733
00000
00267
00267
00165
00165
Currently
Effective
Rate ($)
(d)
28804/0th
o. OOOOO/Dth
82712/Dth
O. OOOOO/Dth
00432/Dth
o. 00432/Dth
17B17/Dth
00432/Dth
10. OOOOO/Dth
35304/Dth
26165/Dth
O. 00432/Dth
10. OOOOO/Dth
52000/0th
20B46/Dth
O. 03276/Dth
17S70/Dth
o. OOOOO/Dth
86753/Dth
o. OOOOO/Dth
17B17/Dth
00432/Dth
10. OOOOO/Dth
35304/Dth
26165/Dth
o. 00432/Dth
10. OOOOO/Dth
52000/Dth
1738S/Dth
OOOOO/Oth
25733/0th
OOOOO/Dth
00432/Dth
O. 00432/Dth
Issued by: R. Allan Bradley, President and CEOIssued on: January 18, 2007 Effective on: February
Filed to comply with order of the Federal Energy Regulatory Commission,
No. RP04-91-000, et al., issued July 26, 2005, 12 FERC ~ 61,119
2007
Docket
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 45 of 47
Questar Pipeline Company
FERC Gas Tariff
First Revised Volume No.
Nineteenth Revised Sheet No. SA
Superseding
Eighteenth Revised Sheet No. SA
STATEMENT OF RATES
(Continued)
OTHER CHARGES:
Marketin Fee: - As negotiated between Questar and shipper when Questar
actively markets shipper I s released capacity.
uest for Firm Service Char e: According to ~ 5 of the General Terms and
Conditions.
Imbalance Char e: According to ~ 12 of the General Terms and Conditions.
Imbalance Tradin Fee: - 29/Dth with a $500 minimum if Questar actively
markets and facilitates the trade.
Footnotes
!/
Annual charge adjustment (ACA) as specified by the Commission and
subject to ~ 17 of the General Terms and Conditions of Part 1 of this tariff.
2/ The SSXP charges are applicable to Rate Schedule T-1 and T-2 service
made possible by capacity created through Questar' s Southern System Expansion
approved in Docket No. CP05-5-000.
l/ Pursuant to the Settlement Order dated July 26, 2005, (112 FERC ~
61,119 (2005)) in Docket Nos. RP04-91-000 and RP05-104-000, et al., Questar'
FGRP provlsions in ~ 12.15 of the General Terms and Conditions in this tariff
are suspended through December 31, 2007. The Settlement also sets forth the
procedure for calculating the FGRP for calendar years 2006 and 2007.
!/Released capacity may be sold at a volumetric rate. Shippers releasing
capacity on a volumetric basls must specify a rate between the maximum and
mlnimum volumetrlc rate stated on this Statement of Rates and notify Questar
of the criteria by which bids are to be evaluated.
~/Pipeline usage charges are applicable to transportation services that
are released at a volumetric rate and will be billed according to ~ 18.2 of
the General Terms and Conditions of Part 1 of this tariff. The GRI surcharge
applicable to a release at a volumetric rate is calculated by multiplying the
applicable GRI charge by 12 months and dividing that number by 365 days.
NOTE: The monthly rates stated on Questar I s Statement of Rates may be
converted to a daily rate by mul tiplying the monthly base tariff rate times
the number of months in the rate period and dividing the result by the numberof days ln the rate period. The result is rounded to the fourth decimal
place.
Issued by: R. Allan Bradley, President and COO
Issued on: November 29, 2005 Effective on: January 1, 2006
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 46 of 47
Questar Pipeline Company
FERC Gas Tariff
First Revised Volume No.
Twentieth Revised Sheet No.
Superseding
Nineteenth Revised Sheet No.
STATEMENT OF RATES
Base
Rate Schedule/
Type of Charge
(a)
Annual
Tariff
Rate
(b)
Currently
Charge
Adjustment
(c)
Effective
(d)
PEAKING STORAGE
Monthl y Reservation Ch arge
Maximum
Minimum
Usage Charge
Inj e ction
Withdrawal
87375
00000
87375/Dth
OOOOO/Dth
03872
03872
03872/Dth
03872 /Dth
CLAY BAS IN STORAGE
Firm Storage Service - 1'SS
Monthl y Reservation Ch arge
Deli verability
Maximum
Minimum
Capacity
Maximum
Minimum
85338
00000
85338/Dth
OOOOO/Dth
02378
00000
02378/Dth
OOOOO/Dth
Usage ChargeInjection
Withdrawal
Authorized OVerrun Cha rge
Maximum
Minimum
Interrup tible Storage Se rvice - J:SS
Usage Charge
Inventory 1/
Maximum
Minimum
Injection
Withdrawal
01049
01781
00165 O. 01214/Dth
01781/Dth
30315
01781
00165
00165
30480/Dth
01946/Dth
05927
00000
01049
01781
00165
05927/Dth
OOOOO/Dth
01214/Dth
01781/Dth
OPTJ:ONAL VOLUMETRJ:C RELE ASES
Peaking Storage Service - PKS
Maximum
Minimum
Firm Storage Service - F SS
Maximum
Minimum
40890
00000
40890/Dth
OOOOO/Dth
Storage Usage Charges Ap plicable
Peaking Storage Service - PKS,Injection
Withdrawal
Clay Bas in Storage servi ce - FSS,
Injection
Withdrawal
57068
00000
to Volu metric Releases 3
57068/Dth
OOOOO/Dth
03872
03872
03872/Dth
03872 /Dth
01049
01781
00165 01214/Dth
01781/Dth
PARK AND LOAN SERVJ:CE - PALl
Daily Charge
Maximum
Minimum
Delivery Charge
30315
00000
02830 00165
30315/Dth
OOOOO/Dth
02995/Dth
FUEL REJ:MBURSEMENT - 2.0% (0.2% utility and 1.8% compressor fuel) for Rate Schedule PALl
Issued by: R. Allan Bradley,
Issued on: August 16, 2006
President and CEO
Effective on: October 2006
Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 47 of 47
Questar Pipeline Company
FERC Gas Tariff
First Revised Volume No.
Eleventh Revised Sheet No. 6A
Superseding
Tenth Revised Sheet No. 6A
FOOTNOTES
!/Applied to the average monthly working gas balance.
~/Released capacity may be sold at a volumetric rate. Shippers releasing
capacity on a volumetric basis must specify a rate between the maximum and
minimum volumetric rate stated on this Statement of Rates and notify Questar
of the criteria by which bids are to be evaluated.
l/Storage usage charges are applicable to storage services that are
released at a volumetric rate and will be billed to the replacement shipper
according to ~ 18.2 of the General Terms and Condi t ions of Part 1 of thi stariff.
!/The annual charge adjustment (ACA) as specified by the Commission will
be billed according to ~~ 4 (f) and 3 (d) of Rate Schedule FSS and ISS,
respectively, and ~ 17 of the General Terms and Conditions of Part 1 of thistariff.
NOTE: The monthly rates stated on Questar I s Statement of Rates may be
converted to a daily rate by multiplying the monthly base tariff rate times
the number of months in the rate period and dividing the resul t by the numberof days in the rate period. The result is rounded to the fourth decimal
place.
Issued by: R. Allan Bradley, President and COO
Issued on: June 23, 2005 Effective on: July 25, 2005
EXIllBIT NOS. 4-
CASE NO. INT-G-07-
INTERMOUNTAIN GAS COMPANY
Idaho Pu~lic Utilities
OffIce of the CommisSion
R Ec E I v~~tary
AUG 1 6 2007
Boise, Idaho
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Exhibit No.
Case No. INT-O7-
Intermountain Gas Company
Page 1 of
INTERMOUNTAIN GAS COMPANY
Proposed Temporary Surcharges (Credits) - Variable Costs
Line
No.Description
(a)
Amount
(b)
Account 1860 Variable Amounts Which Apply to RS-, RS-, GS-1 J and L V-
Account 1860 Variable Costs (1)(1,478 528)
Normalized Sales/CD Vols. (10/1/05 - 9/30/06)291 558 801
Proposed Temporary Surcharge(Credit) - Variable Costs (0.00507)
Lost and Unaccounted For Gas Amounts Which Apply to RS-, RS., and GS.
Lost and Unaccounted For Gas (Over)/Under Collection (2)199 834
Normalized Sales/CD Vols. (10/1/05 - 9/30/06)289 061,489
Proposed Temporary Surcharge(Credit) . Lost and Unaccounted For Gas Costs 00415
Lost and Unaccounted For Gas Amounts Which Apply to LV., T., T., T.3 and T.
Lost and Unaccounted For Gas (Over)/Under Collection (3)399 945
Normalized Sales/CD Vols. (10/1/05 - 9/30/06)208 861 310
Proposed Temporary Surcharge(Credit) - Lost and Unaccounted For Gas Costs 00191
(1) See Workpaper No., Page 1 , Line 17, Column (D
(2) See Workpaper No., Page 1 , Line 17, Column (c)
(3) See Workpaper No., Page 1 , Line 19, Column (c)
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WORKPAPERNOS.
CASE NO. INT-07-
INTERMOUNTAIN GAS COMPANY
(11 pages)
Idaho Public Utilities Commiss;o
Office of the SecretaryRECEIVED
AUG 1 6 2007
Boise, Idaho
Workpaper No.
Case No. INT-O7-
Intermountain Gas Company
Page 1 of
INTERMOUNTAIN GAS COMPANY
Summary of Northwest Pipeline TF-1 Full Rate Demand Costs
Line INT -06-INT -06-INT -06-
No.Trans ortation Annual Therms Prices Annual Cost
(a)(b)(c)(d)
TF-1 Demand 1 Contract #1 412 537 600 040362 650 843
TF-1 Demand 1 Contract #2 550 000 040224 027 723
TF-1 Demand 1 Contract #3 000 000 040027 921 971
TF-1 Demand 1 Contract #4 542 500 039691 934,425
TF-1 Demand 1 Contract #5 750 000 039906 184 854
TF-1 Demand 1 Contract #6 500 000 039992 1,459 708
Total Annual Cost 625 880 100 040231 179 524
Line INT-07-INT -07 -INT-07-
No.Trans ortation Annual Therms Prices Annual Cost
(a)(b)(c)(d)
TF-1 Demand 1 Contract #1 412 537 600 038844 024 611
TF-1 Demand 1 Contract #2 550 000 038414 981,478
TF-1 Demand 1 Contract #3 000 000 038414 804 222
TF-1 Demand 1 Contract #4 542 500 037984 894 238
TF-1 Demand 1 Contract #5 750 000 038414 103 167
TF-1 Demand 1 Contract #6 500 000 038414 1,402 111
Total Annual Cost 625 880 100 038681 209 827
Total Annual Cost Difference (Row 14 minus Row 7)(969,697) (1)
(1) See Exhibit 4, Line 3, Column (h)
Workpaper No.
Case No. INT-O7-
Intermountain Gas Company
Page 1 of 1
INTERMOUNTAIN GAS COMPANY
Summary of Northwest Pipeline TF.1 Discounted Demand Costs
Line INT-O6-INT-O6-INT -O6-
No.Trans ortation Annual Therms Prices Annual Cost
(a)(b)(c)(d)
TF-1 Demand 1 Contract #1 680 000 035650 557 192
TF-1 Demand 1 Contract #2 28,470 000 023810 677 871
TF-1 Demand 1 Contract #3 29,404,400 021090 620 139
TF-1 Demand 1 Contract #4 650 000 037270 844 166
TF-1 Demand 1 Contract #5 500 000 023810 869 065
TF-1 Demand 1 Contract #6 500 000 027780 013 970
Total Annual Cost 197 204,400 028308 582,403
Line INT-O7-INT-O7-INT-O7-
No.Trans ortation Annual Therms Prices Annual Cost
(a)(b)(c)(d)
TF-1 Demand 1 Contract #1 680 000 037980 658 966
TF-1 Demand 1 Contract #2 28,470 000 022790 648 831
TF-1 Demand 1 Contract #3 29,404,400 020690 608 377
TF-1 Demand 1 Contract #4 650 000 037980 860 247
TF-1 Demand 1 Contract #5 500 000 022790 831 835
TF-1 Demand 1 Contract #6 500 000 026590 970 535
Total Annual Cost 197 204,400 028289 578 791
Total Annual Cost Difference (Row 14 minus Row 7)(3,612) (1)
(1) See Exhibit 4, Line 4, Column (h)
Workpaper No.
Case No. INT-O7-
Intermountain Gas Company
Page 1 of
INTERMOUNTAIN GAS COMPANY
Summary of Upstream Capacity Costs
Line INT-06-INT-06-INT-06-
No.Trans ortation Annual Therms Prices Annual Cost
(a)(b)(c)(d)
Upstream Agreement #1 197 567 200 012525 2,474 529
Upstream Agreement #2 155,624 370 006641 033,501
Upstream Agreement #3 155 025 220 019310 993,537
Upstream Agreement #4 192 891 550 012525 2,415 967
Upstream Agreement #5 189 573 700 006637 258,201
Upstream Agreement #6 163,572,400 017131 802 159
Total Annual Cost 977 894
Estimated Upstream Capacity Release Credits (500,000) .
Total Annual Cost Including Capacity Release Credits 12,477 894
Line INT -07 -INT-07-INT-07-
No.Trans ortation Annual Therms Prices Annual Cost
(a)(b)(c)(d)
10 Upstream Agreement #1 199,158 600 013629 714,333
Upstream Agreement #2 155,624,370 007413 153 643
12 Upstream Agreement #3 155 025 220 021966 3,405,284
13 Upstream Agreement #4 300 325 650 013629 093,138
14 Upstream Agreement #5 292 197 100 007408 164 596
15 Upstream Agreement #6 191 172,400 018662 567 659
16 Total Annual Cost 098,653
17 Estimated Upstream Capacity Release Credits (500 000)
18 Total Annual Cost Including Capacity Release Credits 16,598 653
19 Total Annual Cost Difference (Row 18 minus Row 9)120,759 (1)
(1) See Exhibit 4, Line 5, Column (h)
Workpaper No.
Case No. INT-O7-
Intermountain Gas Company
Page 1 of
INTERMOUNTAIN GAS COMPANY
Summary of Other Storage Facility Costs
INT -06-
Line Monthly INT-06-INT -06-INT -06-
No.Stora e Facilities Billina Determinant Prices Monthly Cost Annual Cost
(a)(b)(c)(d)(e)
Demand Costs -
Clay Basin I Reservation 266,250 (1)285338 75,971 911 652
Clay Basin II Reservation 221 840 (1)285338 63,299 759 588
Clay Basin III Reservation 213,010 (1)285338 60,780 729 360
Clay Basin I Capacity 950 000 (2)002378 977 911 724
Clay Basin II Capacity 625 000 (2)002378 63,314 759,768
Clay Basin III Capacity 560 000 (2)002378 782 729 384
AECO Demand 064 970 (2)001634 590 511 080
Total Demand Costs 110,199,970 (3)442 713 312 556
Cycling Costs -
Clay Basin I & II Cycling Costs 58,575,000 001196 70,060 840,715
Clay Basin III Cycling Costs 25,560 000 001187 339 364 062
AECO Cycling Costs 064 970 002227 039 696,465
Total Cycling Costs 110 199 970 158,438 901 242
Storage Demand Charge Credit 393 273)
Total Costs Including Storage Credit 820 525
INT-07-
Monthly INT-07-INT-07-INT-07-
Stora e Facilities Billina Determinant Prices Monthly Cost Annual Cost
(a)(b)(c)(d)(e)
Demand Costs -
Clay Basin I Reservation 266 250 (1)285338 971 911 652
Clay Basin II Reservation 221 840 (1)285338 299 759,588
Clay Basin III Reservation 213 010 (1)285338 780 729 360
Clay Basin I Capacity 950,000 (2)002378 75,977 911 724
Clay Basin II Capacity 26,625,000 (2)002378 314 759 768
Clay Basin III Capacity 560 000 (2)002378 782 729,384
AECO Demand 064 970 (2)001747 45,536 546,432
Total Demand Costs 110,199,970 (3)445 659 347 908
Cycling Costs -
Clay Basin I & II Cycling Costs 58,575,000 000877 362 616,340
Clay Basin III Cycling Costs 560 000 000878 22,448 269,378
AECO Cycling Costs 064 970 002192 129 685,542
Total Cycling Costs 110 199 970 130 939 571 260
Estimated Storage Demand Charge Credit (2,404 586)
Total Costs Including Storage Credit 514 582
Total Annual Cost Difference Including Storage Credit (Row J2 minus Row 16)(J05 943) (4)
111 Charge Based on Maximum Daily Withdrawal
(2) Charge Based on Maximum Contractual Capacity
13) Non Additive Billing Determants; Includes only Capacity Volumes
(4) See Exhibit 4, Line 19, Column (h)
Workpaper No.
Case No. INT-O7-
Intermountain Gas Company
Page 1 of 1
INTERMOUNTAIN GAS COMPANY
Analysis of Peak Day Demand Allocators in Case No. INT-O7-
Core Firm Transportation
Line Subtotal Subtotal
.liQ,Descri tion RS.RS-GS.Core Firm Transportation Total Peak
(a)(b)(c)(d)(e)(f)
(g)
(h)(i)
DEMAND ALLOCATORS PER CASE NO.INT-O6.04:
Peak Day Therms 444 107 960 062 157 978 562 147 140 552 070 195 622 757,769
Percent oITotal Peak 94.79420%374030%20580%
PROPOSED DEMAND ALLOCATORS PER CASE NO. INT O7.03 :Peak Day Therms (Line 2) 444 107
Customers Embedded within Line 2 61 596
Peak Day Usage Per Customer (Line 5 divided by Line 6)
January 2007 Actual Customers 61,754
INT-06-04 Peak Day Therms (Line 7 mulitplied by Line 8)445 246
Percent oITota! Peak
(1) FY08 Forecast Contract Therms
7.21
960,062 157 978 562 147
189 378 169 277 143
10.35 44.
200 625 590 288 969
076,469 176 608 698 323 136 237 55,070 191 307 (1)889630
95.08161%141582%91839%
Detail Detail Amounl Sub-Total Total
(b)(c)(d)(e)(ij
136,239.
(13245764.90)
20,358,729
04906 998799.
(14244564.14)
(108324.60)
282289.
111 195.87)
036310.92)
865217.12)
028.
435 592.
392.
495 014.
INTERMOUNTAIN GAS COMPANY
Analysis of Account 1860 Surcharges (Credits)
Estimated September 30, 2007
LIne
Description
(e)
ACCOUNT 1860 VARIABLE AMOUNTS:
Net Cumulative Deferred Gas Balance In 1860.2010 as of 10/1106
Amortization in 1860.2020 as of 6/3IJ/07
Estimaled Therm Sales 711 through 9/3IJ1O7
Amortization Rate
Estimated Amortization in 1860.2020 at 9/3IJI07
Estimaled Balance In 1860.2010 al 9/30/07
Deferred Gas Costs From Produce../Supplle.. In 1860.2180 at 1011106
Deferred Gas Costs From Producers/Suppliers in 1860.2180 through 6131J/07
Estimated Deferred Costs in 1860.2180 ~om 7/1 through 9131J/07
Estimated Belance in 1860.2180 al 9/30/07
Daily Gas Excess Sales Deferred In 1860.2240 al 6130107
Interest Deferred in 1860.2340 al 10/1106
Deferred Interestin 1880.2340 through 6/3IJ1O7
Estimated Interest ~om 7/1 through 9/3IJ/07
Estimated Balance In 1860.2340 at 9/30/07
ESTIMATED ACCOUNT 1860 VARIABLE BALANCE AT 9/30/07
ACCOUNT 1860 FIXED AMOUNTS:
Net Cumulative Deferred Gas Balance In 1860.2050 al 1011106
(13994.08)
830.
519 115
003IJ8 598.
(31,145.64)
271543.
792481
00916 699.
346.
059,880.
541 089
01256 119836.
(499.00)
312773.
441826
01330 376.
165210
07841 954.
RS-1 Deferred Gas B~ance in 1860.2060 at 10/1106
Amortization for RS-1 in 1880.2060 at 6130107
Esllmated RS-1 Therm Sales 711 through 9130/07
RS-1 Amortization Rate
Estimaled RS-1 B~ance in 1860.2060 at9/3IJ/07
RS-2 Deferred Gas Balance in 1860.2070 at 10/1106
Amortization for RS-2 in 1860.2070 at6/3IJ/07
Estimaled RS-2 Therm S~es 7/1 through 9/3IJ1O7
RS-2 Amortization Rale
Estimated RS-2 Batance in 1860.2070 at 9/3IJ1O7
3IJ GS-1 Deferred Gas Balance in 1860.2080 at 10/1106
Amortization for GS-1 in 1860.2080 at 6/3IJ1O7
Estimated Therm Sales 7/1 through 913IJI07
GS.1 Amortization Rate
Estimated GS.1 Balance in 1860.2080 al 9/3IJ/07
Indus~ial Deferred Gas Balance in 1860.2090 at 10/1/06
Amortization for T-1 & T-2 in 1880.2090 a1613O/07
Estimated T-1 Block 1 & 2 Therm Sales 7/1 through 913IJI07
1 Amortization Rate
Estimated T-2 Con~act Demand Volumes 7/1 through 9/3IJ1O7
2 Amortization Rate
Estimated Indus~ial Balance in 1 B60.2090 at9/3IJ/07
Estimated Cumulative Balance in 1860.2050 at 9/30/07
Fixed Cost Collection Deferred in 1860.2200 al 10/1/06
Fixed Cost Collection Deferred In 1860.2200 through 6/3IJ/07
Estimated Fixed Cost Collection Deferred ~om 7/1 through 9/3IJ/07
Estimated Balance in 1860.2200 al 9130107
T-4 Exit Fee Adjustment Deferred In 1860.2210 at 10/1106
4 Exit Fee Adjustment Deferred in 1860.2210 through 6130/07
Estimaled T.4 Exit Fee Adjustment Deferred ~om 7/1 through 9130/07
Estimated Balance in 1860.2210 at 9/30/07
Statoil Revenue Deferred In 1860.2260 at 1011/06
Statoil Revenue Deferred in 1880.2260 through 6130/07
Estimated Statoil Revenue Deterred ~om 711 through 913IJI07
Estimaled Balance in 1860.2260 at 9/30/07
Capacity ReleasedlPurchased Deferred In 1860.2320 al 6/30/07
Interest Deferred in 1860.2420 at 10/1/06
Deferred Interest in 1880.2420 through 6I3IJ/07
Estimaled Interest ~om 7/1 through 9/3IJ1O7
Estimated Balance In 1860.2420 at 9/30/07
Interest in 1860.2430 at 10/1106
Deferred Interest in 1860.2430 through 6130/07
Estimated Interest from 7/1 through 9/3IJ/07
Estimated Balance In 1860.2430 al 9/30107
Workpaper No.
Case No. INT-O7-
Intermountain Gas Company
Page 1 of 2
(1,478527.72)
135008.17)
64,435.
330096.
208062.
397.605.
(13480B.49)
212,703.
745319.76)
860641.46
(671975.11)
(4.26)
142.64)
411.
558.52)
(112671.98)
(112671.98)
(536,467.74)
(29.77)
272.65)
88.
090.47)
(2,743.41)
(199265.91)
246.
(259255.60)
Uno
Description
(a)
Market Segmentation Deferred in 1860.2530 at 10/1106
Market Segmentation Deferred in 1860.2530 through 6/30/07
Estimated Deferral in 1860.2530 from 7/1 through 9/3O/07
Estimaled Baiance in 1860.2530 at 9/30/07
RS-1 Amortization in 1860.2540 aI6/3O/07
Estimated RS-1 Therm Sales from 7/1 through 9/30/07
RS-1 Amortization Rale
Estimaled RS-1 Amortization in 1860.2540 at 9/30107
RS-2 Amortization in 1860.2540 aI6/3O1O7
Estimaled RS-2 Therm Sales from 7/1 through 9/30107
RS-2 Amortization Rale
Estimaled RS-2 Amortization in 1860.2540 a19130/07
GS-1 Amortization in 1860.2540 aI6/3O1O7
Estimated GS Therm Sales from 7/1 through 9/30107
GS-1 Amortization Rate
Estimaled GS-1 Amortization in 1860.2540 aI9/3O/07
Estimated Core Amortization in 1860.2540 at 9/30/07
1 Amortization in 1860.2550 aI6/3O/07
Estimated T-1 8iock 1&2 Therm Saies from 7/1 through 9/30/07
1 Amortization Rale
Estimaled T-1 Amortization in 1860.2550 aI9/3O/07
2 Amortization in 1860.2550 aI6/3O/07
Estimated T -2 Contracl from 711 through 9/30/07
2 Amortization Rate
Estimaled T-2 Amortization in 1860.2550 at 9/30/07
Estimaled industriai Amortization in 1860.2550 at 9/30107
Estimated Baianceln 1860.2530 at 9/30107
ESTIMATED ACCOUNT 1860 FIXED BALANCE AT 9/30107
TOTAL DEFERRED ACCOUNT 1860 BALANCE
INTERMOUNTAIN GAS COMPANY
Analysis of Account 1860 Surcharges (Credits)
Estimated September 30, 2007
Detail
(b)
519 115
01176
792481
01204
541089
01130
441826
00492
165210
07848
Detail
(c)
(2,421836.29)
(852,411.28)
366887.
104.
372992.
796,235.
117901.47
914 136.
991835.
107814.
099649.
102176.
773.
128949.
887.
962.
849.
Amount
(d)
Workpaper No.
Case No. INT-O7-
Intermountain Gas Company
Page 2 of 2
Sub-Total
(e)
Total
(ij
274 242.76)
386779.
180799.
293,335.
(1,439,492.15)
918019.
INTERMOUNTAIN GAS COMPANY
Analysis of T.1 Tariff Block 1 J Block 2, and Block 3 Adjustments
Line
No.Description
(a)
Industrial Therm Sales (10/1/05 - 9/30/06)
Blocks 1 and 2 Therm Sales
Percent Therm Sales between Blocks 1 and 2
Proposed Adjustment to T-1 Tariff (1)
Industrial Therm Sales (10/1/05 - 9/30/06)
Annualized Adjustment (Line 4 multiplied by Line 5)
Annualized Adjustment (Line 4 multiplied by Line 5)
Percent Annualized Sales included in Block 1
Adjustment to Block 1 (Line 7 mulitplied by Line 8)
Block 1 Therms
Price AdjustmenUTherm Block 1 (Line 9 divided by Line 10)
Northwest Pipeline TF-1 Commodity Charge Change (2)
Total Price AdjustmenUTherm Block 1
Annualized Adjustment (Line 4 multiplied by Line 5)
Percent Annualized Sales included in Block 2
Adjustment to Block 2 (Line 14 multiplied by Line 15)
Block 2 Therms
Price AdjustmenUTherm Block 2 (Line 16 divided by Line 17)
Northwest Pipeline TF-1 Commodity Charge Change (2)
Total Price AdjustmenUTherm Block 2
Price AdjustmenUTherm Block 3 (3)
Northwest Pipeline TF-1 Commodity Charge Change (2)
Total Price AdjustmenUTherm Block 3
Work paper No.
Case No. INT-07-
Intermountain Gas Company
Page 1 of
Block 1 Block 2 Block 3
Therm Sales Therm Sales Therm Sales
(b)(c)(d)
772 182 771,491
772 182 771,491
79.046%20.954%
(1) See Exhibit No.4; Line 33, Col. (I) minus the difference of Line 22, Col. (D minus Line 22, Col. (c)
(2) See Exhibit No.4; Line 22, Col. (D minus Line 22, Col. (c)
(3) See Exhibit No.9, Line 12, Col. (b)
Total
(e)
543 673
543 673
100.000%
01645
543 673
453,093
453 093
79.046%
358 152
772 182
01645
00166
01811
453 093
20.954%
941
771,491
01645
00166
01811
00191
00166
00357
Line
No.
Workpaper No.
Case No. INT-07-
Intermountain Gas Company
Page 1 of 3
INTERMOUNTAIN GAS COMPANY
Analysis of Lost and Unaccounted for Gas ("L&U"
Description
(a)
Detail
(b)
Amount
(c)
Lost and Unaccounted for Gas per U-1034-122:
Lost and Unaccounted for Gas Volumes (Therms)
ODL-1 Commodity Rate
334 526
$0.33413
Cost of L&U Gas $445 905
Normalized Throughput 2 244 949 383
L&U Rate per Therm (Line 4 divided by Line 5)$0.00182
Lost and Unaccounted for Gas per INT-O7-
. Intermountain Estimated FY07 Throughput 3
L&U Rate per Therm per U-1034-122 (Line 6, Col (c))
513 583 000
$0.00182
FY07 Collection of L&U Gas $934,721
Projected FY07 L&U (Therms)
INT-06-04 WACOG/Therm
700 000
$0.68500
534 500Projected FY07 L&U
Projected L&U (Over)/Under Collection (Line 13 minus Line 10)599 779
15 Allocation of L&U (Over)/Under Collection
RS-, RS-2 and GS-1 Allocation
Core Allocation of L&U (Over)/Under Collection
75.00%
199 834
Industrial Allocation
Industrial Allocation of L&U (Over)/Under Collection
25.00%
$399 945
Total L&U (Over)/Under Collection 599 779
1 See Workpaper No.8 page 2 of 3
2 See Workpaper No.8 page 3 of 33 Projected FY07 Throughput (Therms)
RS-
RS-
GS-
Industrial
Total Throughput
614 058
159 015,492
518 287
224,435 163
513 583 000
Workpaper No.
Case No. INT-O7-
Intermountain Gas Company
Page 2
Intermountain Gas CompanY
Case No. U...iO34-122
Workp~per#RR...2S
CQ~T OF GAS
NORMALIZATION & COMPANY PROPOSED ADJUSTMENTS
l2 MONTHS ENDtro APRIL 30.. 1.9$$ .
.lZ Months Ended
12/3ij84
ACt;~~l .
'i'li.PQRC1IAS:$ .~$QyII~Ji1'1Er:rr? .Ga$$a).es
~QWM~yn$E; (12 months
~h4e~ 12/31/84)
Ub~ccounteil for Gas (12 months
nd.e4 91'JOf84)
Z59.H4.9Z2
637 ~410
. 1.)~4 .SlE!
2~1.14/5 .858
GOSTO:r' . GASPU~CaASED
.. .
$\ib~idJaiy . Purchases:
Inte.rex. Inc. (12 months
ended 12J3J184)
IGCProductlon Co.
lteqtdrement$
744yOQO
orthwestPtpeline Purthase$:
ODL-Demand 1.
))eiilanu 2
Go1l1t!\o!:iit;y
S~S-nemand
Seasonal De~n4
Co1iiIl1o4i!::y
LS-pe1l1ariQ
Capac;i;ty
t.lq~i;!:fM~#'In
Va,:P9t'l?~ti.(iI),
J3Qy 23?*
245.:007 .360*
232.$24 ,-437
aQ5,104*
J1 ,QQ5 . (HJ()*
oo$ .000
120.000*
705.100*
.1.877.000*
877,000:*
244.~73c..431
X~$t Y~~r EM~i:i 4/30/85
Nilt:mali~~t :!.QP Adju~t:m~ot
CO11PAl'!X):'lW;i10SED . ~Ju.STMEN'l':
. Elim!ria ficiri .of .i:::empo'6'trY .surchargesebedtiled
i:;oterminateonApTi1 1, 1986 (244.273,437 * .0072:6)
*'J1l:ip!'eSertts ttonc-a:4d1tive units
A:djl:1~t1JJeJlt
( 16.873..421)
(16 .$73.~ 1)
5/118$
;Rat~s
$.4JPOO
39690
02132
33413
t2~60
(11326
34660
OJU75
03420
. ()lOZO
00271
Te.st Year
13fJ l85
~Q:t1naU~~d
24Z,301.501
637,410
:n4.~26
444,.273..437
/UD.9urit
JIg ,920
383.083
5, 223,557
17., 693~390
489,188
1, 021,484:
814,333
265,6080
162 214
19.14~
087
97 .; 397.Q81
lOl. $31.508
$ (lQ.J34, 421)
$H (J,,17~..4~$1
Workpaper No.
Case No. INT-O7-
Intennountain Gas Company
Page 3 of 3
GAS SALES-- STAFFNORMAJ/IZAnON ADJUSTMENT
12 MONTHS ENJ)ED AP~rL 3(); 1985
(A)
Line
No.Deseription
M:tud 12Montb.$En~~d 12--31--$A
Thet:'1l\s Sales Adjustments:
We.atberNormCl:li~Cl:ti:onC~ntractCustom~r Cbang~s
65J)ay 13illing Adjustment
AdJustmen'f;, t;,o~eflectNQrmanzedSde$
Pric~4 atB:ates & Contracts in Effect 5-1-85
liminationofTemp . SUrcharges in Rates
10.Not1l'\altzed Sales fot:" TestYeatEndedAprt13o; 1985
(C)
Tberms Amount
259.174.922 $141.788.288
(13 114 . ()$Z)
( jOO.HE;)
. 810.881
14.:?ZS;S39
( 10. 573.028)
540 . 332
11 .113:360
244.949.383 $130.614.928
t'NTElUtOt.JNTA.IN GAS co..
CAstRO, U--'lO34-122staftEx. 113
Santos
m!! Thomas
MOFFATT THOMAS BARRETT ROCK & FIELDS, CHTD.
Boise
Idaho Falls
Pocatello
Twin Falls
Eugene C. Thomas
John W. Barren
R. B. Rock
Richard C. Fields
John S. Simko
John C. WardD. James Manning
Gary T. Dance
Larry C. Hunrer
Randall A. Pererman
J\hrk S. Prusynski
Srephen R. Thomas
Glenna M. Chrisrensen
Gerald T. Husch
Scorr 1. Campbell
Roberr B. Burns
Michael E. Thomas
Parricia M. Olsson
Bradley J Williams
Lee Radford
Michael O. Roe
David S. Jensen
James 1. MarrinC. Clayron Gill
Michael W. McGreaham
David P. Gardner
Julian E. Gabiola
Angela Schaer Kaufmann
Kimberly D. Evans Ross
Paul D. McFarlane
Jon A. Srenquisr
Tyler J. Henderson
C. Edward Carher III
Jason G. Murray
Mark C. Pererson
Andrew J. Waldera
Tyler J. Anderson
Dylan B. Lawrence
Russell G. Mercalf
Benjamin C. Rirchie
Rebecca A. Rainey
US Bank Plaza Building
RECEIVED 101 S Capitol Blvd 10th
PO Box 829
Boise, Idaho 83701 0829
Z031 AUG J b j 5: 11208 3'45 2000
August 16 1.007-. --: I j Ii' 800422 2889
\ ..,.,;, '/.:-', ,' ,
~~...?9.~q~5 5384 Fax
U I iL!! Ie;'; "'/'.'/Iij0~'1tJoffatt.com
Roben E. Bakes of counsel
Morgan W. Richards of counsel
W,Jlis C. Moffarr, 1907-1980
Kirk R. Helvie 1956-2003
Ms. Jean Jewell
Idaho Public Utilities Commission
472 West Washington
Post Office Box 83720
Boise, Idaho 83720-0074
Re:Intermountain Gas Company
IPUC Case No. INT-07-
MTBR&F File No. 11-500.0340
Dear Ms. Jewell:
Enclosed for filing please find Intermountain Gas Company s Workpaper No.
Intermountain Weighted Average Cost of Gas ("W ACOG") which relates to the above
numbered PUC case.
Pursuant to PUC IDAP A Rules 31.01.01.067, 31.01.01.233, and 31.02.01.005.07 and pursuant
to Idaho Code Section 9-340D and Section 48-801 et seq.Intermountain Gas Company hereby
states that the enclosed information is confidential and a trade secret or otherwise is exempt
from disclosure under Section 9-340A to 9-340H. We ask that it be protected from inspection
examination or copying by any person other than the Commissioners and PUC Staff.
Thank you for your cooperation. If you should have comments or questions regarding this
request, please contact Mike McGrath (377-6168) or me (385-5468).
Smc~e
Ste en R. Thomas
Attorney for Intermountain Gas Company
Idaho State Bar No. 2326
SRT/sec
Enclosure
BOI MT2:661946.