20110811Application.pdf

EXECUTIVE OFFICES
INTERMOUNTAIN GAS COMPANY RECEIVED
555 SOUTH COLE ROAD. P.O. BOX 7608. BOISE, IDAHO 83707. [phone]. FAX: 377-§Q97
lin I AUG , I AM 10= J 7
August 11, 2011
Ms. Jean Jewell
Commission Secretary
Idaho Public Utilties Commission
472 W. Washington St.
P.O. Box 83720
Boise, 10 83720-0074
RE: Case No. INT-G-11-01
Dear Ms. Jewell:
Attached for consideration by this Commission are the original and seven (7) copies of
Intermountain Gas Company's Application for Authority to Decrease Its Prices on October
1,2011. '
If you have any questions regarding the attached, please contact me at [phone].
c t adison
Vice President & Chief Accounting Officer
SWM/mt
Enclosures
cc: K. F. Morehouse
T.M. Clark
D.L. Haider
RECEIVE
2011 AUG I I AM fa: 17
INl'ERMOUNTAIN GAS COM~AN1tl°A::H~%¡j¡'~Qil~i\t5l1='.E"",~1 """i\,1ì'å3 i~l ,..........;:l v; "i:
CASE NO. INT-G-II-0l
APPLICATION
AND
EXHIBITS
In the Matter of the Application of INTERMOUNTAIN GAS COMPAN
for Au thority to Decrease Its Prices on October 1,2011
(Octobfl 1,2011 Purchased Gas Cost Adjustment Filing)
Stephen R. Thomas, iS) ~ 2326
MOFF ATT THOMAS 3ARRTT ROCK & FIELDS, CHTD.
101 S. Capitol Boulevard, Suite 1000
Boise, Idaho 83702
Telephone: [phone]
Attorneys for IntermoUl lain Gas Company
RECEIVED
101 1 AUG '' AM 10:1 7
BEFC)RE THE IDAHO PUBLIC UTILITIES COMMISSION
In the Matter of the Application of
INTERMOUNTAIN G A.S COMPANY
for Authority to Decreas e Its Prices
Case No. INT-G-11-01
APPLICATION
Intermountai (ras Company ("Intermountan" or "Company"), a subsidiar of MDU
Resources Group, Inc. 1 vith general offices located at 555 South Cole Road, Boise, Idaho, hereby
requests authority, purSl ant to Idaho Code Sections 61-307 and 61-622, to place into effect October
1,2011 new rate schediiles which will decrease its anualized revenues by $14.4 millon, pursuat
to the Rules of Procedi re of the Idaho Public Utilties Commission ("Commssion"). Because of
changes in Intermoun1 ain's gas related costs, as described more fuly in ths Application,
Intermountain's earg s will not be decreased as a result of the proposed decrease in prices and
revenues. Intermountai ' s curent rate schedules showing proposed changes are attched hereto as
Exhibit NO.1 and are in ::orporated herein by reference. Intermountain's proposed rate schedules are
attached hereto as Exhil it No.2 and are incorporated herein by reference.
Communcations in refe rence to this Application should be addressed to:
Scott M~ idison
Vice PrE sident & Chief Accounting Officer
Intermoi mtan Gas Company
Post Off ,ce Box 7608
Boise, Il) 83707
and
Stephen R. Thomas, ISB 2326
MOFFA IT THOMAS BARRTT ROCK & FIELDS, CHTD.
101 S. ( apitol Boulevard, Suite 1000
Boise, I( ,aho 83702
In support of th ; Application, Intermountain does allege and state as follows:
APPLICATION - 2
I.
Intermountai i; a gas utility, subject to the jursdiction of the Idaho Public Utilties
Commission, engaged i 1 the sale of and distribution of natual gas within the State of Idaho under
authority of Commis~ ion Certificate No. 219 issued December 2, 1955, as amended and
supplemented by Order 'lo. 6564, dated October 3, 1962.
Intermountai p 'Ovides natual gas servce to the following Idaho communities and counties
and adjoining areas:
Ada County - Boise, Eage, Garden City, Kuna, Meridian, and Sta;
Bannock County - Chubl uck, Inkom, Lava Hot Springs, McCammon, and Pocatello;
Bear Lake County - Geoi getown, and Montpelier;
Bingham County - Aberc een, Basalt, Blackfoot, Firth, Fort Hall, Moreland/verside, and Shelley;
Blaine County - Bellevu(, Hailey, Ketchum, and Sun Valley;
Bonnevile County - Am non, Idaho Falls, Iona, and Ucon;
Canyon County - Caldw( ii, Greenleaf, Middleton, Nampa, Parma, and Wilder;
Caribou County - Bancrc fi, Conda, Grace, and Soda Springs;
Cassia County - Burley, J )eclo, Malta, and Raft River;
Elmore County - Glenns Ferr, Hamett and Mountain Home;
Fremont County - Parker and St. Anthony;
Gem County - Emmett;
Gooding County - Goodi ig, and Wendell;
Jefferson County - Lewi~ vile, Menan, Rigby, and Ririe;
Jerome County - Jerome;
Lincoln County - Shoshc rie;
Madison County - Rexbt rg, and Sugar City;
Minidoka County - Heyl: iim, Paul, and Rupert;
Owyhee County - Brune lU, and Homedale;
Payette County - Fruitlar d, New Plymouth, and Payette;
Power County - America i Falls;
Twin Falls County - Bub ., Filer, Hansen, Kimberly, Murtugh, and Twin Falls;
Washington County - Wi iser.
Intermountain's properties in these locations consist of tranmission pipelines, a liquefied
natual gas storage facil ty, distrbution mais, services, meters and regulators, and general plant and
equipment.
II.
Intermountain s ~eks with ths Application to pass through to each of its customer classes
changes in gas related costs resulting from: 1) an increase in costs biled Intermountan from
Northwest Pipeline GP ("Nortwest" or "Nortwest Pipeline"), 2) a decrease in costs from the
Company's upstream )ipeline suppliers and it's storage facility contracts, 3) a decrease in
Intermountain's Weigh1 ed Average Cost of Gas, or "WACOG", 4) an updated customer allocation
APPLICATION - 3
of gas related costs purs Jat to the Company's Purchased Gas Cost Adjustment ("PGA") provision,
5) the inclusion of temi Olar surcharges and credits for one year relating to natual gas purchases
and interstate transporta lion costs from Intermountain's deferred gas cost accounts, and 6) benefits
resulting from Intermo intain's management of its storage and firm capacity rights on varous
pipeline systems. Intt rmountain also seeks with ths Application to eliminate the temporar
surcharges and credits i ricluded in its curent prices durg the past 12 months, pursuat to Order
No. 32077 per Case No, INT-G-1O-03. The above changes would result in an overall price decrease
to Intermountain's custc mers.
These price chai iges are applicable to servce rendered under rate schedules afected by and
subject to Intermounta n's Purchased Gas Cost Adjustment ("PGA"), intially approved by ths
Commission in Order No. 26109, Case No. INT-G-95-1, and additionally approved though
subsequent proceedings
Exhbit No. 3 c )ntans pertinent excerpts from applicable pipeline taffs. Exhbit No. 4
sumarzes the price cl anges in: 1) Intermounta's base rate gas costs, 2) its rate class allocation,
and 3) adjusting tempe rar surcharges or credits flowig through to Intermountan's direct sales
customers. Exhbit Nc s. 3 and 4 are attched hereto and incorporated herein by reference.
III.
The curent pri ::es of Intermountain are those approved by ths Commssion in Order
No. 32077, Case No. Th I-G-lO-03.
IV.
Intermountain'~ proposed prices incorporate all changes in costs relating to the
Company's firm inters1 ite transportation capacity including, but not limited to, any price changes
or projected cost adjus :ments implemented by the Company's pipeline suppliers as well as any
volumetric adjustment; in contracted transportation agreements which have occured since
Intermountain's PGA f ling in Case No. INT-G-10-03.
Intermountain continues to effectively manage its natural gas storage assets at
Northwest's Jackson I rairie and Questar Pipeline's Clay Basin storage facilities. Supporting
documents relating tc Line 19 of Exhibit No.4, include $2.7 milion in savings from
Intermountain's manag ~ment of these storage assets.
APPLICATION - 4
Exhibit No.4, I ines 1 through 19, details the proposed changes in Intermountain's prices
resulting from adjustii Lents to the cost of Northwest Pipeline interstate capacity, upstream
pipeline capacity, and I itermountain's storage facilty costs from its varous suppliers.
v.
The WACOG n flected in Intermountan's proposed prices is $0.45342 per therm, as shown
on Exhbit No.4, Line : ~1, CoL. (t). Ths compares to $0.49211 per therm curently included in the
Company's taffs.
Continued weai ness in the regional and national economies has put downward pressure on
new customer growt a id weather adjusted demand for natual gas. At the same time, natual gas
supplies are ample and J.S. dr gas production is at an all time high. Robust supply coupled with
flat demand has kept th( near term prices for natual gas relatively low.
Additionally, tle proposed WACOG includes benefits to Intermounta's customers
generated by the Comp my's management of its signficant natual gas storage assets. Because gas
added to storage is pro( lled during the suier season when prices are tyically lower than during
the winter, the cost of I itermountan's storage gas is normally less than what could be obtaed on
the open market in wini er month. Additionally, and in an effort to fuer stabilze the prices paid
by our customers dur ~ the upcoming winter period, Intermounta has entered into varous fixed
price agreements to lo( ~-in the price for signficant portions of its underground storage and other
winter "flowig" suppli :s.
Intermountain è ;:lieves that the W ACOG proposed in ths Application, subject to the effect
of actu supply and i lemand and based on curent market conditions, provides today's most
reasonable forecast of ~as costs for the 2011-2012 PGA period. Intermountan will employ, in
addition to those fixec price agreements already in place, cost effective price arangements to
fuer secure the price )f flowing gas embedded within ths Applicaton when, and if, those pricing
opportties materializ ~ in the marketplace.
Intermounta è ;:lieves that timely natual gas price signals enhance its customer's abilty to
make informed and a ,propriate energy use decisions. The Company is committed to alert
customers to impendin! price chages before their winter natual gas usage occurs. By employig
the use of customer ma ilings, the Company's website, and varous media resources, Intermounta
will continue to educa1 ~ its customers regarding the wise and effcient use of natual gas, biling
options available to helJ i manage their energy budget, and pending natual gas price changes.
APPLICATION - 5
VI.
Pursuat to Ca ¡e No. INT-G-1O-03, Intermountain included temporar surcharges and
credits in its October 1, 2010 prices for the principal reason of collecting or passing back to its
customers deferred gas :ost charges and benefits, as outlined in Case No. INT-G-1O-03. Line 26 of
Exhbit NO.4 reflects th ~ elimination of these temporar surcharges and credits.
VII.
Intermounta's PGA taff includes provisions whereby Intermountain's proposed prices
will be adjusted for Uj ,dated customer class sales volumes and purchased gas cost allocations,
pursuat to the Compar y's approved cost of service methodology. Intermountan's proposed prices
include a fixed cost col ection adjustment pursuat to these PGA provisions, as outlined on Exhbit
No.5, Line 24. The i: rice impact of this adjustment is included on Exhbit No.4, Line No. 27.
Exhibit NO.5 is attchei i hereto and incorporated herein by reference.
VIII.
Intermounta i: ~oposes to pass through to its customers the benefits that will be generated
from the management ( f its transporttion capacity totaing $3.7 millon as outlined on Exhbit No.
7. These benefits incliide credits from a segmented release of a porton of Intermounta's fi
capacity rights on Nor11west Pipeline and other non-segmented capacity releases. Intermounta
proposes to pass back 11ese credit amounts via the per therm credits, as detaled on Exhbit No. 7
and included on Exhbi : No.6, Line 1. Exhbit Nos. 6 and 7 are attched hereto and incorporated
herein by reference.
IX.
Intermountain r roposes to allocate deferred gas costs from its Account No. 186 balance to
its customers though :emporar price adjustments to be effective during the 12-month period
ending September 30, 2 )12, as follows:
1) Intermounta n has deferred fixed gas costs in its Account No. 186. The credit amount
shown on Exhbit No. l, Line 8, CoL. (b) of$5.9 millon is attbutable to a tre-up of the collection
of interstate pipeline (apacity costs, the tre-up of expense issues previously ruled on by ths
Commission, and miti; :ating capacity release credits generated from the incremental release of
Intermountai's pipelin ~ capacity. Intermountain proposes to pass back these balances via the per
APPLICATION - 6
therm credits, as detaile 1 on Exhbit NO.8 and included on Exhbit No.6, Line 2. Exhbit NO.8 is
attched hereto and incc rporated herein by reference.
2) Intermounta n has also deferred in its Account No. 186 a varable gas credit of $12.2
milion, as shown on Sxhibit No.9, Line 2, CoL. (b). Ths deferred credit is attbutable to
Intermountai's lower' 'arable gas costs since October 1, 2010. Intermountain proposes to pass
back this balance via a i er therm credit, as shown on Exhbit No.9, CoL. (b), Line 4 and included on
Exhbit No.6, Line 3.
3) Finally, Inte mountain has deferred in its Account No. 186 deferred gas costs related to
Lost and Unaccounted For Gas as shown on Exhibit No.9, CoL. (b), Lines 5 though 20. Ths
deferral results in net )er therm decreases to Intermountan's sales customers, as ilustrated on
Exhbit No.9, Line 12, CoL. (b), and included on Exhibit No.6, Line 3. The Lost and Unaccounted
For Gas deferral also ri :sults in a per therm credit for Intermountan's transportation customers as
shown on Exhibit No. S , Line 20, CoL. (b). Exhbit No.9 is attched hereto and incorporated herein
by reference.
x.
Intermounta h is allocated the proposed price changes to each of its customer classes based
upon Intermountan's I GA provision. However, a straight cent per therm price decrease was not
utilzed for the LV -1 t riff as no fixed costs are curently recovered in the tail block of the LV-1
tariff. The proposed cl anges in the W ACOG, and varable deferred credits as outlined on Exhbit
No.9, are applied to al thee blocks of the LV -1 taff. However, all adjustments relating to fied
costs are applied only t( the first two blocks of the LV -1 tarff.
XI.
Each block oftle proposed LV-I, T-3, T-4 and T-5 taffs include a unform cents per therm
decrease to adjust for L )st and Unaccounted For Gas as detailed on Exhbit No.9, Lines 13 though
20, CoL. (b). The price:, including the proposed adjustent for each block of the T-3, T-4 and T-5
taiffs, and the removal of existing temporar price changes, are outlined on Exhbit No.1, Page 1,
Lines 21 though 32.
XII.
Exhbit No. lOs an analysis of the overall price changes by class of customer. Exhbit No.
lOis attched hereto an 1 incorporated herein by reference.
APPLICATION - 7
XIII.
The proposed i .verall price changes herein requested among the classes of service of
Intermountai reflect a just, fair, and equitable pass-through of changes in gas related costs to
Intermountain's custom ~rs.
xiv.
Ths Applicatio: l is filed pursuat to the applicable statutes and the Rules and Reguations of
the Commssion. This A.pplication has been brought to the attention of Intermountain's customers
through a Customer Nc :ice and by a Press Release sent to daily and weekly newspapers, and major
radio and television st itions in Intermountain's service area. The Press Release and Customer
Notice are attached he eto and incorporated herein by reference. Copies of this Application, its
Exhbits, and Workp. ipers have been provided to those paries reguarly intervenig in
Intermountain's rate pn ceedings.
xv.
Intermountain i ~quests that this matter be handled under modified procedure pursuant to
Rules 201-204 of the C )mmission's Rules of Procedure. Intermountan stads ready for immediate
consideration of ths m, tter.
APPLICATION - 8
WHEREFORE, Intermountan respectfly petitions the Idaho Public Utilties Commission
as follows:
a. That the pre posed rate schedules herewith submitted as Exhbit No. 2 be approved
without suspension and made effective as of October 1, 2011 in the maner shown on Exhbit No.
2.
b. That ths Api lication be heard and acted upon without hearng under modified procedure,
and
c. For such olier relief as this Commission may determine proper herein.
I ATED at Boise, Idaho, ths 11 th day of August, 2011.
CAS COMPANY MOFFATT HOMAS BAR T ROCK &
FIELDS, C TD
..
Tomas
r Intermountain Gas Company
on
resident & Chie . Accounting Officer
APPLICATION - 9
CERTIFICATE OF MAILING
I HERJ my CERTIFY that on ths 11th day of Augut, 2011, I served a copy of the
foregoing Case No. Th I-G-11-01 upon:
Paula Pyron
Northwest Industral (as Users
4113 Wolf Berr Cow l
Lake Oswego, OR 97( 35-1827
Chad Stokes
Cable Huston et aL.
1001 SW Fifth Avenue, Suite 2000
Portland, Oregon 97204-1136
w R. Scott Pasley
J. R. Simplot Compan: r
PO Box 27
Boise, ID 83707
Steven Gray
J. R. Simplot Company
PO Box 27
Boise, ID 83707
Conley E. Ward, Jr.
Givens, Pursley, Webl & Huntley
277 N. 6th St., Suite 2110
PO Box 2720
Boise, il 83701
by depositing tre cop es thereof in the United Stat M', postage prepaid, in envelopes addressed
to said persons at the a Jove addresses.
Sc adison
ice President & Chief Accounting
APPLICATION - 10
EXHIBIT NO.1
CASE NO. INT-G-II-0l
INTERMOUNTAIN GAS COMPANY
CURRNT TARFFS
Showing Proposed Price Changes
(11 pages)
Exhibit NO.1
Case No. INT-G-11-01
Intermountain Gas Company
Page 1 of 11
C )MPARISON OF PROPOSED OCTOBER 1, 2010 PRICES
TO OCTOBER 1, 2011 PRICES
October I, 2010 Proposed
Line Prices per Proposed October 1, 2011
No.Rate Class INT-G-10-03 Adjustment Prices
(a)(b)(c)(d)
1 RS I
2 April - November $0.94465 $(0.04864)$0.89601
3 December - March 0,83209 (0.04864)0.78345
4 RS 2
5 April - November 0,79583 (0.03444)0.76139
6 December - March 0,76220 (0.03444)0.72776
7 GS I
8 April - November
9 Block 1 0.83871 (0.06124)0.77747
10 Block 2 0.81698 (0,06124)0.75574
11 Block 3 0.79596 (0.06124)0.73472
12 December - March
13 Block 1 0.78786 (0.06124)0.72662
14 Block 2 0.76666 (0.06124)0.70542
15 Block 3 0.74620 (0.06124)0.68496
16 CNGFuel 0.74620 (0.06124)0.68496
17 LV ,i
18 Block 1 0.57143 (0.03026) (1)0.54117
19 Block 2 0.53294 (0.03026) (1)0.50268
20 Block 3 0.44686 (0.02700) (2)0.41986
21 T-:
22 Block 1 0.05490 (0.00090) (3)0.05400
23 Block 2 0.02230 (0.00090) (3)0.02140
24 Block 3 0.00817 (0.00090) (3)0.00727
25 T-'
26 Block 1 0.05913 (0.00090) (3)0.05823
27 Block 2 0.02064 (0.00090) (3)0.01974
28 Block 3 0.00591 (0.00090) (3)0.00501
29 T-~
30 Demand Charge 0.84253 0.84253
31 Commodity Charge 0.00176 (0.00090) (3)0.00086
32 Over-Run Service 0.04435 (0.00090) (3)0.04345
33 IS- l (4)
34 April - November 0.76220 (0.03444)0.72776
35 December - March 0,76220 (0.0344)0.72776
36 IS. : (5)
37 April - November
38 Block i 0.78786 (0.06124)0.72662
39 Block 2 0.76666 (0.06124)0.70542
40 Block 3 0.74620 (0.06124)0.68496
41 December - March
42 Block i 0.78786 (0.06124)0.72662
43 Block 2 0.76666 (0.06124)0.70542
44 Block 3 0.74620 (0.06124)0.68496
(i)i ee WorkpaperNo. 7, Line 13, Column (e)
(2) i ee Workpaper No.7, Line 17, Column (e)
(3) J ,emove INT-G-10-03 temporary of $(0.00070) and add the temporary from Exhibit 9. Line 20. Column (b)
(4) c he IS-R price is based on the RS-2 December - March price and receives the same PGA adjustments,
(5) c he IS-C price is based on the GS-I December - March price and receives the same PGA adjustments.
Exhibit No. 1
Case No. INT-G-11-01
Intermountain Gas Company
Page 2 of 11
I.P.U.C. Gas Tanff
Second Revised Vc fume No.1
(Supersedes First F evised Volume No.1)
Fo -5e Revis ed Third Sheet No. 01
Name
of Utilty, Ir ,termountain Gas Company
IDAHO PUBLIC UTILITES COMMISSIONApproved Effective
Sept. S6, 2616 Oct. 1, 2919
Pei O.ft 32977
Jean D. Jewell Secretary
Rate Schedule RS-1
RESIDENTIAL SERVICE
AVAILAILITY:
Available' 0 individually metered consumers not otherwise specifcaii~"provided for, using
natural gas for n sidential purposes.
RATE:
Monthly n inimum charge is the customer charge.
For bilin i periods ending April through November
Cu~ tomer Charge - $2.50 per bil
Cor imodit Charge - $9.94465 per therm* $0.89601
For bilin i periods ending December through March
Cu~ tomer Charge - $6.50 per bil
Coi rimodity Charge - $9.83299 per therm* $0.78345
*lncludes:
Temporary purchased gas cost adjustment of $(8.8'96) $(0.07748)
Weighted average cos of gas of $6:4211 $0.45342
PURCHASED G) iS COST ADJUSTMENT:
This tañfl is subject to an adjustment for cost of purchased gas as provided for in the
Company's Pure hased Gas Cost Adjustment Provision.
SERVICE COND TIONS:
All natur¡ ¡J gas service hereunder is subject to the' General Service Provisions of the
Company"s Tari1 f, of which this rate schedule is a part
Issued by: Interi nountain Gas Company
By: ICaLI.eline J. B~n¡~rd Scott Madison Title: Meli~eF Ges SI:(3(31y & Re§l:latsPJAffaiFS
Effective: ~f 1, 2010 October 1, 2011 Vice President & Chief Accounting Offcer
Exhibit No. 1
Case No. INT-G-11-01
Intermountain Gas Company
Page 3 of 11
I.P.U.C. Gas Tanff
Second Revised Vol Jme NO.1
(Supersedes First Ri !vised Volume No.1)
Forty-'5 Revlsi id Third Sheet No. 02
NameofUllllty Intermountain Gas Company
IDAHO PUBLIC UTILITIES COMMISSIONApproved Effective
Sept. 38, 2818 Oct. 1, 2818
Per 0..,. 32977
,Jean D. Jewell Secretary.
Rate Schedule RS-2
MULTIPLE USE RESIDENTIAL SERVICE
AVAILABILITY:
Available t J indivdually metered consumers using gas for several residential purposes
including both Wi iter heating an~ space heating.
RATE:
Monthly mnimum charge is the customer charge.
For bilini ! periods ending April through November
Cus :omer Charge - $2.50 per bill
Con imodit Charge. $8.79583 perthènn* $0.76139
For bilinii periods ending December through March
Cus tomer Charge - $6.50 per bil
COl1lmodit Charge. $8.76228 per therm* $0.72776
*Includes:
Temporary purchased gas cost adjustment of $(8.8'118) $(0.06720)
Weighted average cost of gas' of $9.4924 4 $0.45342
PURCHASED G~ S COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the
Company's Purc riased Gas Cost Adjustment Provision.
SERVICE CONDI nONS:
All natulël gas service hereunder is subject to the General Service Provisions of th~
Company's Taril f, of which this rate schedule Is a part
Issued by: Interi riountain Gas Company
By: ¡caerine d. I ~ Scott Madison Tite: Mafla§er Gas gy¡:¡;ly &. Regbllati: Affirs
Effective: ee F ~, 201 Q October 1, 2011 Vice President & Chief Accounting Offcer
Exhibit No. 1
Case No. INT-G-11-01
Intermountain Gas Company
Page 4 of 11
I.P.U.C. Gas Tariff
Secnd Revised Volume NO.1
(Supersedes First Revised Volume No.1)
Fort-f Revised Fifth Sheet No. 03 (Paiie 1 of 2)
Name
of Uti lily Intermountain Gas Company:
IDAHO PUBLIC UTILITIES COMMISSION.Approved Effective
5epl36,2616 Set. 1, 2:916
Per S.U. 32677
Jean D. Jewell Secretary
Rate Schedule GS-1
GENERAL SERVICE
AVAILABILITY:
Available to individually metered customers whose requirements for natural gas do not exceed
2,000 therms per day, at any point on Company's disibution system. Requirements in exces of
2,000 thenns per day may be served. under this rate schedule upon execution of a one-year writen
servic~ contract.
RATE:
Monthly minimum chare is the customer charge.
For billng periods ending April through November
Customer Charge. $2.00 per bil .
Commodity Charge - First 200 thenns per bil ~ $6.93871* $0.77747
Next 1,800 thenns per bil ~$e.61696* $0.75574
Over 2,000 thenns per bil ~ $9.79596* $0.73472
For billng periods ending December through March
Customer Charge - $9.50 per bil
Commodity Charge - First 200 thenns per bil ~ $9.78786* $0.72662
Next 1,800 thenns per bil ~$9.7666&" $0.70542
Over 2,000 therms per bil ~ $9.74&29* $0.68496
*Includes:
Temporary purchased gas cost adjustment of $(9.96646) $(0.07988)
Weighted average cost of gas of $9.49i!44 $0.45342
Issued by: Intermountain Gas Company
By: l~lhel'Re d. Bl'Ffl'FB Scott Madison
Effective: Oeteef 1, 2818 October 1, 2011 Tite: MElR6§eF Gas 8YFlFllY & Resylalgi: Afji:
Vice President & Chief Accunting Offcer
Exhibit No. 1
Case No. INT-G-11-01
Intermountain Gas Company
Page 5 of 11
I.P.U.C. Gas Tariff
Second Revised Volume NO.1
(Supersedes First Revised Volume No.1)Forty-Fo Revised Fifth Sheet No. 03' (Paae 2 of 2)Name .
of Utilit Intermountain Gas Company
IDAHO PUBLIC UTILITIES COMMISSIONApproved Effective
Sept. 36, 2616 Oct. 1, 2918
Pei O.N. 32977
Jean D. Jewell Secretary
Rate Schedule GS-1
GENERAL SERVICE (Continued)
For separately metered deliveries of gas utilized solely as Compressed Natural Gas Fuel invehicular intemal combustion engines. .
Customer Charge - $9.50 per bil
Commodity Charge - $6.r4628 per therm'" $0.68496
.Includes:
Temporary purchased gas cost adjustment of $(Q.96646l $(0.07988)
Weighted average cost of gas of $9.049:211 $0.45342
PURCHASED GAS COST ADJUSTMENT:
This taff 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 wil pay to Intennountain Gas Company,
upon exitg the GS-1 service, all gas and trnsporttion related cost incurrd 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 lèaves the GS.1 service wil
have refunded to them, upon exiting the GS-1 service, any excess gas commodity or
trnsporttion payments made by the customer during the time they were a GS-1
customer.
2. All natural gas service hereunder is subject to the General Service Provisions of the
Company's Tariff, of which this rate schedule is a part
Issued by:. Intermountain Gas Company
By: ~eriRe d. 8erRsFå Scott Madison
Effectve: Oetober 1, 2018 October 1, 2011
Title: Maiiagei Gas 8t11'I'IY & Re~l:latf)!l'JfiRl
Vice President & Chief Accountin Offcer
Exhibit No. 1
Case No. INT-G-11-01
Intermountain Gas Company
Page 6 of 11
I.P.U.C. Gas Tariff
Second Revised Volume NO.1
(Supersedes First Revised Volume No.1)Fif-5e Revised Third Sheet No. 04 (Pai:e 1 of 2)
Nameof Utilty Intermountain Gas COmpany
IDAHO PUBLIC UTILITIES COMMISSIONApproved Effective
Sept. 38, 2616 Oct. 1, 2616
Pei OJ" 32677
Jean D. Jewell Secretary
Rate Schedule LVM1
LARGE VOLUME FIRM SALES SERVICE
AVAILABILITY:
Available at any mutually agreeable derivery point on the Company's distribution system to any
existing customer receiving service under the Company's rate schedule LV-1 or any new customer
whosè usage does not exceed 500,000 therms annually, upon execution of a one-year minimum written
service cont~ct for firm sales service in excess of 200,000 therm per year.
MONTHLY RATE:
Commodit Charge:
First 250,000 therms per bil ~ $6.57143* $0.54117
Next 500,000 therms per biI ~ $9.63294* $0.50268
Amount Over 750,000 therms per bil (g $9.4468&" $0.41986
The above prices include weighted average cost of gas of $6.042t1 $0.45342
* Includes temporary purchased gas cost adjustment of $(6.95693) $(0.04992)
** Includes temporary purchaséd gas cost adjustent of $(9.9SQ86) $(0.04017)
PURCHASED GAS COST ADJUSTMENT:
This tarif is subject to an adjustment for cost of purchased gas as provided for in the Company's
Purchased Gas Cost Adjustment Provision. .
SERVICE CONDITIONS:
1. All natural gas service hereunder is subject to the General Service Provisions of the
Company's Tarif, 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 limite to, the
expiration of the contract term) wil pay to Intermountain Gas Company, upon exiting the LV-1 service,
all gas and/or intersate transportation related costs to serve the custômer during the LVM1 contract'
period not borne by the customer during the LV-1 contract period. Any LV-1 customer wll have
refunded to them, upon exiting the LV-1 service, any excess gas and/or interste transporttion relatedpayments made by the customer during the LV-1 contrct 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 currnt contrct period used less
than the contract minimum of 200,000 therms, an additonal amount shall be biled. The additional
amount shall be calculated by biling the deficit usage below 200,000 therms at the LV-1 Block 1 rate
adjusted for the removal of variable gas costs. The customer's future eligibilty for the LV-1 Rate
Schedule wil be renegotiated with the Company.
Issued by: Intermountain G.as Company
By: l~eFiRe d. BaFFaFEcott MadlsotJe: MaReeeF Gas Sl:~i:ly & R€ii:lati: AffaiFE
Effective: OelbeF ~, 2010 October 1, 2011 Vice President & Chief Accunting Offcer
Exhibit No. 1
Case No. INT-G-11-01
Intermountain Gas Company
Page 7 of 11
I.P.U.C. Gas Tariff
Second Revised Volume No. 1
(Supersedes First Revised Volume No.1)
ri Revised Sixt Sheet No. 11 (Page 1 of 2)Name I . t.
of Utilty ntermoun ain Gas Company
IDAHO PUBLIC UTILITIES COMMISSIONApproved . Effective
Sept. 39, 2819 Oct. 1,2618
Pei O.rt 326'7
Jean D. Jewell Secretary
Rate Schedule T-3
INTERRUPTIBLE DISTRIBUTION TRANSPORTATION SERVICE
AVAILABILIT:
Available ~t 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 thenns transported~ $9.95499* $0.05400
Next 50,000 therms transported~ $9;92239* $0.02140
Amount over 150,000 therms transported~ $6.69Bi7* $0.00727
*Includes temporary purchased gas cost adjustment of $(9.99979) $(0.00160)
ANNUAL MINIMUM BILL:
The customer shall be subject to the payment of an annual minimum bil of $30,000
during each annual contract period, unless a higher minimum is required under the
service contract to cover special conditions.
PURCHASED GAS COST ADJUSTMENT:
This taif 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. 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 writen
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 o~ 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-1, T-4, or T-5 customer electing this schedule may concurrently
utilze Rate Schedule T -3 on the same or contiguous propert.
Issued by: Intermountain Gas Company,
By: ¡(lit! iéi ii ie d. BlIrl iard Scott Madison Title: Mana~ef Gas'St:13131' & Regt:Ii*8F' AffiF6
Effective: Octber 1, 2818 October 1, 2011 Vice President & Chief Accunting Offcer
Exhibit No. 1
Case No. INT-G-11-01
Intermountain Gas Company
Page 8 of 11
I.P.U.C. Gas Tariff
Secnd Revised Volume No.1
(Supersedes First Revised Volume No.1)
"f Revised Fifth Sheet No. 13 (Paae 1 of 2)
Name
of Utilty Intermountain Gas Company
IDÁHO PUBLIC UTILITIES COMMISSIONApproved Effective
Sept. 39, 2919 Oct. 1, ~919
Per O.N. 32977
Jean D. Jewell Secretary
Rate Schedule T-4
FIRM DISTRIBUTION ONLY TRANSPORTATION SERVICE
AVAILAILITY:
Available at any mutually agreeable delivery point on the Company's distribution system to any
customer upon execution of, a one year minimum written seivice contract for firm distribution
transportation seivice in excess of 200,000 therms per year.
MONTHLY RATE:
Commodity Charge:
Block One:
Bloc/(Two:
Block Three:
First
Next
Amount over
250,000 therms transported~ $9.95913* $0.05823
500,000 therms transported~$a.92e&4* $0.01974
750,000 therm transported~ $9.e8591* $0.00501
"Includes temporaiy purchased gas cost adjustment of $te.eee7'e) $(0.00160)
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 Adjustent Provision.
SERVICE CONDITIONS:
1. This service excludes the seivice and cost of firm 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' seivice hereunder is subject to the General Seivice Provisil?ns 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 wil be stated in
the contract and in effect th.roughout the term of ~he seivice contra~t.
5. An existing LV-1, T-3, orT-S customer electing this schedule may concurrently utilze Rate
Schedule T -4 on the customer's same or contiguous propert.
BILLING ADJUSTMENTS:
1. In the event that total deliveries to any customer within the last three contrct periods met or
exceeded the 200,000 therm threshold, but the customer during the current contract penod
used less than the contract mlilimum of 200,000 therms, an additional amount shall be biled.
The additional amount shall be calculated by billng the deficit usage below 200,000 therms
at the T -4 Block 1 rate. The customets future eligibilty for the T -4 Rate Schedule wil be
renegotiated with the Company.
Issued by: Intermountain Gas Company
By 1(e¡'eriRe d. BerReFåScott MadisonTile: MeR8e¡ef Gas Sl:flfllY & Re!'i:latery Aifir:
Effective: Oetber 4 2818 October 1, 2011 Vice President & Chief Accountin Offcer
Exhibit No. 1
Case No. INT-G-11-01
Intermountain Gas Company
Page 9 of 11
I.P.U.C. Gas Tariff
Second Revised Volume NO.1
(Supersedes First Revised Volume No.1)
'Ì Revised Fourth Sheet No. 14 (Page 1 of 2)
Name
ofUlility
IDAHO PUBLIC UTILITIES COMMISSIONApproved Effective
Sept. 39, 2919 Oct. 1, 2919
Per O.N. 32977
Jean D. Jewell Secretary
Intermountain Gas Company
Rate Schedule T-5
FIRM DISTRIBUTION SERVICE WITH MAXIMUM DAILY DEMANDSAVAILABILI~ " .
Available at any mutually agreeable delivery point on the Company's distribution system to any
existing T.. customer whose.daily contract demand on any given day meets or exceeds a predetermined
level agrëëd to by (he èustol1èrand thëCorrpãnyüpoli "exëëutlö-n öla one-yeãr minimum wrltLenservièè
contract for firm distribution service in excess of 200,000 therms per year.
MONTHLY RATE:
Firm Service
Demand Charge:
Firm Daily Demand -
Rate Per Therm
$0.84253
Commodity Charge:
For Firm Therms, Transported
Over_Run Service
Commodity Charge:
For Therms Transported In Excess Of MDFQ:
$9.99176" $0.00086
$9.94495* $0.04345
*Includes temporary purchased gas cos adjustent of $(9.99'079) $(0.00160)
PURCHASED GAS COST ADJUSTMENT:
This tariff Is subject t9 an adjustment for cost of purchased gas as provided for in the Company'sPurchased 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 nominate a Maxmum Daily Firm Quantit (MDFQ), which wil be stated In and wil
be in effect throughout the term of the service èontract.
3. Thè monthly Demand Charge wil be equal to the MDFQ times the Firm Daily Demand rate. Firm
demand relief wil be afforded to those T.. customers paying both demand and commodity charges
for gas when, in the Company's judgment, such relief is warranted.
4. The actual therm usage for the month or the MDFQ times the number of days in the biling month,
whichever is less, wil be biled at the applicable commodity charge for firm thenns.
Issued by; Intermountain Gas Company
By: KethefÎ~e d. 8arfleft Scott Madison Title: Mel'flser Gas 8i:flfllr & Re!;i:lalsfJ' Afirs
Effective: Oeteeer 1, 2818 October 1, 2011 Vice President & Chief Accunting Offcer
Exhibit NO.1
Case No. INT-G-11-01
Intermountain Gas Company
Page 10 of 11
I.P.U.C. Gas Tariff-F Revised Second Sheet No. 16 (Page 1 of 2)
Name
of Utiit Intermountain Gas Company
IDAHO PUBLIC UTILITIES COMMISSIONApproved Effective
Se~t. 39, 2949 Oct. 1, 2618
Pei OJ" 32677
Jean D. Jewell Secretary
Rate Schedule IS-R
RESIDENTIAL INTERRUPTIBLE SNOWMELT SERVICE
APPLICABILITY:
Applicable to any new residential or Customer using natural gas to melt snow and/or ice on
sidewalks, driveways or any other similar appurtenances. Any and all such applications meeting the
above criteria wil be subject to service under Rate Schedule IS-R and will be separately and
individually metered. All service hereunder is interruptible at the sale discretion of the Company.
FACILIT REIMBURSEMENT CHAGE:
All new Interruptible Snowmelt service customers are required to pay for the cost of theSnowmelt meter set and other related facilty and equipment costs, prior to the insllation of the
meter set. Any requestto alter the physical location of the meter set and related facilities fróm
Company's initial design may be granted provided, however, the Company can reasonably
accommodate said relocation and Customer agrees to pay all related costs.
RATE:
Monthly minimum charge is the Customer Charge.
For billng periods ending April through November
Customer Charge - $2.50 per bil
Commodit Charge. $9.76229 per thenn* $0.72776
For biling periods ending December through March
Customer Charge. $6.50 per bil
Commodity Charge - $6.762£6 per thenn* $0.72776
*Includes:
Tempora purchased gas cost adjustent of $(6.97419) $(0.06720)
Weighted averae cost of gas of $9.4e211 $0.45342.
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 Cos Adjustment Provision.
SERVICE CONDmONS:
1. All natural gas sérvice hereunder is subject to the General Service Provisions of the
Company's Tariff, of which this Rate Schedule is a part.
Issuedby: Intermountain Gas Company
By: I CatlieiÍlie J. Baiiaid Scott Madison TIle: Mal'ager Gas 6t:""~ 8: Regt:latlj Affe:irs
Effectve: Oeæl:er 1, 2010 October 1, 2011 Vice President & Chief Accunting Offcer
Exhibit No. 1
Case No. INT-G-11-01
Intermountain Gas Company
Page 11 of 11
I.P.U.C. Gas Tanfff' Revised Second Sheet No. 17 (page 1 of 2)
Name
of Utilty Intermountain Gas Company
IDAHO PUBLIC UTILITIES COMMISSIONApproved Effective
Sept. 38, 2818 Oct. 1,2818
Pei e.N. 32877
Jean D. Jewell Secretary
Rate Schedule IS-C
SMALL COMMERICAL INTERRUPTIBLE SNOYVMEL T SERVICE
APPLICABILITY:
Applicable to any new Customer otheiwise eligible to receive gas service under Rate Schedule
GS-1 and using natural gas to melt snow and/or ice on sidewalks, driveways or any other similar
appurtenances. Any and all such applications meeting the above criteria wil be subject to service
uncier .Rate SçhecllJlel.s~Cand will bei:eparately and individually metered. All service hereunder is
interruptible atthe sole discretion ofthe Company. . . . .. ..
FACILITY REIMBURSEMEl' CHARGE:
All new interrptible Snowmelt service customers are required to pay for the cos of the
Snowmelt meter set and other related facilty and equipment costs, prior to the installation of the
meter set. Any request to alter the physical location of the meter set and related facilties from
C:ompany's initial design may be granted provided, however, the Company can reasonably
accommodate said relocation and Customer agrees to pay all related costs.
RATE:
Monthly minimum charge is the Customer Charge.
For billng periods ending April through November
Customer Charge - $2.00 per bil .
Commodit Charge - Firs 200 therms per bil ~ $9.78786l $0.72662
Next 1,800 therms per bil ~ $8.76666" $0.70542
Over 2,000 therms per bil ~ $9.14629* $0.68496
For billng periods ending December through March
Customer Charge - $9.50 per bil
Commodity Charge - First 200 therms per bil ~ $9.78786" $0.72662
Next 1,800 thenns per bil ~ $9.16666' $0.70542
Over 2,000 therms per bil ~ $9.14629" $0.68496
"Includes:
. Temporary purchased gas cost adjusbnent of $~9.9664&) $(0.07988)
Weighted average cost of gas of $9.4924 4 $0.45342
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.
Issued by: Intermountain Gas Company
By: l(ftlieril'ed. 86f1!ml Scott Madison Title: M8fl8§er Gas Si:~~ly & Re§141ateFj' Mfai¡:
Effectie: Oaleer 1, 2919 October 1, 2011 Vice President & Chief Accuntin Offcer
EXHIBIT NO.2
CASE NO. INT-G-II-0l
INTERMOUNTAIN GAS COMPANY
PROPOSED TARFFS
(10 pages)
Exhibit NO.2
Case No. INT-G-11-01
Intermountain Gas Company
Page 1 of 10
I.P.U.C. Gas Tariff
Second Revised Volume No. 1
(Supersedes First Revised Volume No.1)Forty-Third Revised Sheet No. 01 (Paae 1 of 1)
Name
of Utility Intermountain Gas Company
Rate Schedule RS-1
RESIDENTIAL SERVICE
AVAILABILITY:
Available to individually metered consumers not otherwise specifically provided for, using
natural gas for residential purposes.
RATE:
Monthly minimum charge is the customer charge.
For billng periods ending April through November
Customer Charge - $2.50 per bil
Commodity Charge - $0.89601 per therm*
For biling periods ending December through March
Customer Charge - $6.50 per bil
Commodity Charge - $0.78345 per therm*
*Includes:
Temporary purchased gas cost adjustment of $(0.07748)
Weighted average cost of gas of $0.4342
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: Scott Madison Title: Vice President & Chief Accounting Offcer
Effective: October 1, 2011
I.P.U.C. Gas Tariff
Second Revised Volume No. 1
(Supersedes First Revised Volume No.1)Fort-Third Revised Sheet No. 02 (Paoe 1 of 1)
Exhibit NO.2
Case No. INT-G-11-01
Intermountain Gas Company
Page 2 of 10
Name
of Utiity Intermountain Gas Company
Rate Schedule RS-2
MULTIPLE USE RESIDENTIAL SERVICE
AVAILABILITY:
Available to individually metered consumers using gas for several residential purposes
including both water heating and space heating.
RATE:
Monthly minimum charge is the customer charge.
For biling periods ending April through November
Customer Charge - $2.50 per bil
Commodity Charge - $0.76139 per therm*
For biling periods ending December through March
Customer Charge - $6.50 per bil
Commodity Charge - $0.72776 per therm*
*Includes:
Temporary purchased gas cost adjustment of $(0.06720)
Weighted average cost of gas of $0.45342
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: Scott Madison Title: Vice President & Chief Accounting Offcer
Effective: October 1, 2011
Exhibit NO.2
Case No. INT-G-11-01
Intermountain Gas Company
Page 3 of 10
I.P.U.C. Gas Tariff
Second Revised Volume NO.1
(Supersedes First Revised Volume No.1)Forty-Fifth Revised Sheet No. 03 (Paae 1 of 2)
Name
of Utilty Intermountain Gas Company
Rate Schedule GS-1
GENERAL SERVICE
AVAILABILITY:
Available to individually metered customers whose requirements for natural gas do not exceed
2,000 thenns per day, at any point on Company.s distribution system. Requirements in excess of
2,000 thenns per day may be served under this rate schedule upon execution of a one-year wñtten
service contract.
RATE:
Monthly minimum charge is the customer charge.
For biling peñods ending Apñl through November
Customer Charge - $2.00 per bil
Commodit Charge - First 200 thenns per bill (t $0.77747*
Next 1,800 thenns per bil (t $0.75574*
Over 2,000 thenn per bil (t $0.73472*
For billng periods ending December through March
Customer Charge - $9.50 per bil
Commodity Charge - First 200 thenns per bil (t $0.72662*
Next 1,800 thenns per bil (t $0.70542*
Over 2,000 thenns per bil (t $0.68496*
*Includes:
Temporaiy purchased gas cost adjustment of $(0.07988)
Weighted average cost of gas of $0.45342
Issued by: Intermountain Gas Company
By: Scott Madison Title: Vice President & Chief Accounting Offcer
Effective: October 1, 2011
Exhibit NO.2
Case No. INT-G-11-01
Intermountain Gas Company
Page 4 of 10
I.P.U.C. Gas Tariff
Second Revised Volume No. 1
(Supersedes First Revised Volume No.1)Fort-Fifth Revised Sheet No. 03 (Pai:e 2 of 2)
Name
of Utility Intermountain Gas Company
Rate Schedule GS-1
GENERAL SERVICE (Continued)
For separately metered deliveries of gas utilzed solely as Compressed Natural Gas Fuel in
vehicular internal combustion engines.
Customer Charge - $9.50 per bil
Commodity Charge - $0.68496 per therm*
*Includes:
Temporaiy purchased gas cost adjustment of $(0.07988)
Weighted average cost of gas of $OA5342
PURCHASED GAS COST ADJUSTMENT:
This tari 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 wil pay to Intennountain Gas Company,
upon exiting the GS-1 service, all gas and transporttion 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 wil
have refunded to them, upon exiting the GS-1 service, any excess gas commodity or
transporttion payments made by the customer during the time they were a GS-1
customer.
2. All natural gas service hereunder is subject to the General Service Provisions of the
Company's Tariff, of which this rate schedule is a part.
Issued by: Intermountain Gas CompanyBy: Scott Madison Title: Vice President & Chief Accounting Offcer
Effective: October 1, 2011
Exhibit No.2
Case No. INT-G-11-01
Intermountain Gas Company
Page 5 of 10
I.P.U.C. Gas Tariff
Second Revised Volume No. 1
(Supersedes First Revised Volume No.1)
Fitt- Third Revised Sheet No. 04 (Paae 1 of 2)
Name
of Util tv Intermountain Gas Company
Rate Schedule LV-1
LARGE VOLUME FIRM SALES SERVICE
AVAILABILITY:
Available at any mutually agreeable delivery point on the Company's distribution system to any
existing customer receiving service under the Company's rate schedule LV-1 or any new customerwhose usage does not exceed 500,000 thenns annually, upon execution of a one-year minimum written
service contract for firm sales service in excess of 200,000 thenns per year.
MONTHLY RATE:
Commodity Charge:
First 250,000 thenns per bil ~ $0.54117*
Next 500,000 thenns per bil ~ $0.50268*
Amount Over 750,000 thenns per bil ~ $0.41986**
The above prices include weighted average cost of gas of $0.452
* Includes temporary purchased gas cost adjustment of $(0.04992)
** Includes temporary purchased gas cost adjustment of $(0.04017)
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 CONDITONS:
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 tenn) wil pay to Intennountain 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 wil 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 thre contract periods met or
exceeded the 200,000 thenn threshold, but the customer during the current contract period used less
than the contract minimum of 200,000 thenns, an additional amount shall be biled. The additional
amount shall be calculated by billng the deficit usage below 200,000 therms at the LV-1 Block 1 rate
adjusted for the removal of variable gas costs. The customer's future eligibilty for the LV-1 Rate
Schedule wil be renegotiated with the Company.
Issued by: Intermountain Gas Company
By: Scott Madison Title: Vice President & Chief Accunting Offcer
Effective: October 1, 2011
I.P.U.C. Gas Tariff
Second Revised Volume No. 1
(Supersedes First Revised Volume No.1)Sixth Revised Sheet No. 11 (Pace 1 of 2)
Name
of Utilty Intermountain Gas Company
Exhibit NO.2
Case No. INT-G-11-01
Intermountain Gas Company
Page 6 of 10
Rate Schedule T-3
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~ $0.05400*
Next 50,000 therms transported~ $0.02140*
Amount over 150,000 therms transported~ $0.00727*
*Includes temporary purchased gas cost adjustment of $(0.00160)
ANNUAL MINIMUM Bill:
The customer shall be subject to the payment of an annual minimum bil of $30,000
during each annual contract period, unless a higher minimum is required under the
service contract to cover special conditions.
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. 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-1, T-4, or T-5 customer electing this schedule may concurrently
utilze Rate Schedule T-3 on the same or contiguous propert.
Issued by: Intermountain Gas Company
By: Scott Madison Title: Vice President & Chief Accounting Offcer
Effective: October 1, 2011
I.P.U.C. Gas Tariff
Second Revised Volume No. 1
(Supersedes First Revised Volume No.1)
Fifth Revised Sheet No. 13 (Page 1 of 2)Name It. G C
of Utilty n ermountam as ompany
Exhibit NO.2
Case No. INT-G-11-01
Intermountain Gas Company
Page 7 of 10
Rate Schedule T -4
FIRM DISTRIBUTION ONLY TRANSPORTATION SERVICE
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~ $0.05823*
500,000 therms transported~ $0.01974*
750,000 therms transported~ $0.00501*
*Includes temporary purchased gas cost adjustment of $(0.00160)
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. This service excludes the service and cost of firm 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 wil be stated in
the contract and in effect throughout the term of the service contract.
5. An existing LV-1, T-3, or T-5 customer electing this schedule may concurrently utilze 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 biled.
The additional amount shall be calculated by biling the deficit usage below 200,000 therms
at the T -4 Block 1 rate. The customer's future eligibilty for the T -4 Rate Schedule wil be
renegotiated with the Company.
Issued by: Intermountain Gas Company
By: Scott Madison Title: Vice President & Chief Accounting Offcer
Effective: October 1, 2011
Exhibit NO.2
Case No. INT-G-11-01
Intermountain Gas Company
Page 8 of 10
I.P.U.C. Gas Tariff
Second Revised Volume NO.1
(Supersedes First Revised Volume No.1)
Fourth Revised Sheet No. 14 (Page 1 of 2)
Name
of Utility Intermountain Gas Company
Rate Schedule T-5
FIRM DISTRIBUTION SERVICE WITH MAXIMUM DAILY DEMANDS
AVAILABILITY:
Available at any mutually agreeable delivery point on the Company's distribution system to any
existing T-5 customer whose daily contract demand 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 distribution service in excess of 200,000 therms per year.
MONTHLY RATE:
Firm Service
Demand Charge:
Firm Daily Demand -
Rate Per Therm
$0.84253
Commodity Charge:
For Firm Therms Transported
Over-Run Service
Commodity Charge:
For Therms Transported In Excess Of MDFQ:
$0.00086*
$0.04345*
*Includes temporary purchased gas cost adjustment of $(0.00160)
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company"s
Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
1 All natural gas service hereunder is subject to the General Service Provisions of the Company's Tariff,
of which this Rate Schedule is a part.
2. The customer shall nominate a Maximum Daily Firm Quantity (MDFQ), which wil be stated in and wil
be in effect throughout the term of the service contract.
3. The monthly Demand Charge wil be equal to the MDFQ times the Firm Daily Demand rate. Firm
demand relief wil be afforded to those T -5 customers paying both demand and commodity charges
for gas when, in the Company's judgment, such relief is warranted.
4. The actual therm usage for the month or the MDFQ times the number of days in the billng month,
whichever is less, wil be biled at the applicable commodity charge for firm therms.
Issued by: Intermountain Gas Company
By: Scott Madison Title: Vice President & Chief Accounting Offcer
Effective: October 1, 2011
Exhibit Nò. 2
Case No. INT-G-11-01
Intermountain Gas Company
Page 9 of 10
I.P.U.C. Gas TariffSecond Revised Sheet No. 16 (Page 1 of 2)
Nameof Utilty .Intermountain Gas Company
Rate Schedule IS-R
RESIDENTIAL INTERRUPTIBLE SNOWMELT SERVICE
APPLICABILIT:
Applicable to any new reidential or Customer using natural gas to melt snow and/or ice on
sidewalks, driveways or any other similar appurtnances. Any and all such applications meeting the
above criteña wil be subject to service under Rate Schedule IS-R and wil be separately. and
individually metered. All service hereunder is interruptible at the sole discretion of the Company.
FACILITY REIMBURSEMENT CHARGE:
All new interruptible Snowmelt service customers are required to pay for the cost of the
Snowmelt meter set and other related facilty and equipment costs, pñor to the installation of the
meter set. Any request to alter the physical location of the meter set and related facilties from
Company's initial design may be granted provided, however, the Company can reasonably
accommodate said relocation and Customer agres to pay all . related cots.
RATE:
Monthly minimum charge is the Customer Charge.
For biling periods ending April through November
Customer Charge. $2.50 per bil
Commodit Charge - $0.72776 per thenn*
For biling periods ending December through March
Customer Charge. $6.50 per bil
Commodity Charge - $0.72776 per thenn*
*Includes:
Temporary purchased gas cost adjustment of $(0.06720)
Weighted average cost of gas of $0.45342
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 CONDmONS:
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.
Issued by: Intermountain Gas Company
By: Scott Madison Title: Vice President & Chief Accunting Offcer
Effective: October 1, 2011
Exhibit No. 2
Case No. INT-G-11-01
Intermountain Gas Company
Page 10 of 10
I.P.U.C. Gas TariffSecond Revised Sheet No. 17 (Page 1 of 2)
Name
of Utility Intermountain Gas Company
Rate Schedule IS-C
SMALL COMMERICAL INTERRUPTIBLE SNOWMELT SERVICE
APPLICABILITY:
Applicable to any new Customer otherwise eligible to receive gas service under Rate Schedule
GS-1 and using natural gas to melt snow and/or ice on sidewalks, driveways or any other similar
appurtenances. Any and aU such applications meeting the above criteria wil be subject to service
under Rate Schedule IS-C and wil be separately and individually metered. All service. hereunder is
interruptible at the sole discretion of the Company.
FACILITY REIMBURSEMENT CHARGE:
All new interrptible Snowmelt service customers are required to pay for the cost of the
Snowmelt meter set and other related facilty and equipment costs, prior to the installation of the
meter set. Any request to alter the physical location of the meter set and related facilties from
Company's initial design may be granted provided, however, the Company can reasonably
accommodate said relocation and Customer agrees to pay all related costs.
RATE:
Monthly minimum charge is the Customer Charge.
For billng periods ending April through November
Customer Charge - $2.00 per bil
Commodity Charge - First 200 therms per bil cæ $0.72662*
Next 1,800 therms per bil cæ $0.70542*
Over 2,000 therms per bil cæ $0.68496*
For biling periods ending December through March
Customer Charge - $9.50 per bil
Commodity Charge - First 200 therms per bil cæ $0.72662*
Next 1,800 therms per bil cæ $0.70542*
Over 2,000 therms per bil cæ $0.68496*
*Includes:
Temporary purchased gas cost adjustment of $(0.07988)
Weighted average cost of gas of $0.45342
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.
Issued by: Intermountain Gas Company
By: Scott Madison Title: Vice President & Chief Accounting OffcerEffective: October 1, 2011 '
EXHIBIT NO.3
CASE NO. INT-G-II-0l
INTERMOUNTAIN GAS COMPANY
PERTINENT EXCERPTS FROM INTERSTATE PIPELINES AND RELATED
FACILITIES
(16 pages)
Northwest Pipeline GP
FERC Gas Tariff
Fifth Revised Volume No.1
FERC GAS TARIFF
FIFTH REVISED VOLUME NO. 1
(Superseding Fourth Revised Volume No.1)
Of
NORTHWEST PIPELINE GP
Filed with
FEDERA ENERGY REGULATORY COMMISSION
Communications concerning this Tariff should be sent to:
Laren M. Gertsch, Director, Rates & Regulatory
Northwest Pipeline GP
295 Chipeta Way
Salt Lake City, Utah 84108
P . O. Box 589 a 0
Salt Lake City, Utah 84158
Telephone: [phone]
Facsimile: [phone]
Exhibit NO.3
Case No. INT-G-11-01
Intermountain Gas Company
Page 1 of 16
Exhibit No. 3
Case No. INT-G-11-01
Intermountain Gas Company
Page 2 of 16
Northwest Pipeline GP
FERC Gas Tariff
Fifth Revised Volume No.1
First Revised Sheet No.5
Superseding
Substitute Original Sheet No.5
STATEMENT OF RATES
Effective Rates Applicable to
Rate Schedules TF-l, TF-2, TI-l, TFL-l and TIL-l
(Dollars per Dth)
Rate Schedule and
Type of Rate
Base
Tariff Rate
Minimum Maximum ACA(2)
CurrentlyEffective
Tariff Rate (3)
Minimum Maximum
Rate Schedule TF-l (4) (5)Reservation
(Large Customer)
System-Wide .00000 .37984 .00000 .37984
15 Year Evergreen Exp..00000 .38101 .00000 .38101
25 Year Evergreen Exp..00000 .36445 .00000 .36445
Volumetric
(Large Customer)
System-Wide .00756 .03000 .00190 .00946 .03190
15 Year Evergreen Exp..00369 .00369 .00190 .00559 .00559
25 Year Evergreen Exp..00369 .00369 .00190 .00559 .00559
(Small Customer)(6).00756 .67209 .00190 .00946 .67399
Scheduled Overrun .00756 .40984 .00190 .00946 .41174
Rate Schedule TF-2 (4) (5)
Reservation
Volumetric
Scheduled Daily Overrun
Annual Overrun
.00000
.00756
.00756
.00756
.37984
.03000
.40984
.40984
.00000
.00756
.00756
.00756
.37984
.03000
.40984
.40984
Rate Schedule TI-l
Volumetric (7).00756 .40984 .00190 .00946 .41174
Rate Schedule TFL-l (4) (5)
Reservation
Volumetric
Scheduled Overrun
Rate Schedule TIL- 1
Volumetric
Exhibit No. 3
Case No. INT-G-11-01
Intermountain Gas Company
Page 3 of 16
Northwest Pipeline GP
FERC Gas Tariff
Fifth Revised Volume No.1
First Revised Sheet No. 5-C
Superseding
Substitute Original Sheet No. 5C
STATEMENT OF RATES (Continued)
Effective Rates Applicable to
Rate Schedules TF-1, TF-2, TI-1, TFL-1 and TIL-1 (Continued)
(Dollars per Dth)
Footnotes (Continued)
(4) All reservation rates are daily rates computed on the basis of 365 days
per year, except that such rates for leap years are computed on the
basis of 366 days.
For Rate Schedule TF-1, the 15-Year and 25-Year Evergreen Expansion
reservation and volumetric rates apply to Shippers receiving service
under Rate Schedule TF- 1 Evergreen Expansion service agreements. The
System-Wide reservation and volumetric rates apply to Shippers
receiving service under all other Rate Schedule TF-1 service
agreements.
For Rate Schedule TF-1, the 15-Year and 25-Year Evergreen Expansion
maximum base tariff reservation rates are comprised of $0.37610 and
$0.35954 for transmission costs and $0.00491 and $0.00491 for storage
costs , respectively. The System-Wide maximum base tariff reservation
rates for Rate Schedule TF-1 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-1 (Large Customer), the maximum base tariff
volumetric rates applicable to Shippers receiving service under Rate
Schedule TF- 1 Evergreen Expansion service agreements are comprised of
$0.00344 for transmission costs and $0.00025 for storage costs. The
maximum base tariff volumetric rates 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 costs and $0.00025 forstorage costs.
Exhibit NO.3
Case No. INT-G-11-01
Intermountain Gas Company
Page 4 of 16
Northwest Pipeline GP
FERC Gas Tariff
Fifth Revised Volume No. i
First Revised Sheet No. 5-D
Superseding
Substitute Original Sheet No. 5D
STATEMENT OF RATES (Continued)
Effective Rates Applicable to
Rate Schedules TF-1, TF-2, TI-1, TFL-1 and TIL-1 (Continued)
(Dollars per Dth)
Footnotes (Continued)
(5) Rates for Rate Schedules TF-1,TF-2 and TFL-1 are also applicable to
capacity release service except for short-term capacity release transactions
for a term of one year or less that take effect on or before one year from
the date on which Transporter is notified of the release, which are not
subj ect to the stated maximum tariff rate. (Section 22 of the General Terms
and Conditions describes how bids for capacity release will be evaluated.)
The reservation rate is the comparable volumetric bid reservation charge
applicable to Replacement Shippers bidding for capacity released on a one-
part volumetric bid basis.
(6) For Rate Schedule TF-1 (Small Customer), the maximum base tariff rate
is comprised of $0.66202 for transmission costs and $0.01007 for
storage costs. Transporter will not transport gas for delivery for
Small Customers subject to this Rate Schedule TF-1 under any
interruptible Service Agreement or under any capacity release Service
Agreement unless such Small Customer has exhausted its daily levels of
firm service entitlement for that day.
(7) Rate Schedule TI-1 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-1, TF-2, TI-1, TFL-1 and TIL-1 pursuant
to Section 15.5 of the General Terms and Conditions.
Exhibit No. 3
Case No. INT-G-11-01
Intermountain Gas Company
Page 5 of 16
Northwest Pipeline GP
FERC Gas Tariff
Fifth Revised Volume No.1
First Revised Sheet No.7
Superseding
Substitute Original Sheet No.7
STATEMENT OF RATES (Continued)
Effective Rates Applicable to Rate Schedules SGS-2F and SGS-21
(Dollars per Dth)
Rate Schedule and
Tye of Rate
Currently EffectiveTariff Rate (1)
Minimum Maximum
Rate Schedule SGS-2F (2) (3) (4) (5)
Demand Charge
Pre-Expansion Shipper 0.00000 0.01551
Expansion Shipper 0.00000 0.08476
Capacity Demand Charge
pre-Expansion Shipper 0.00000 0.00056
Expansion Shipper - 2010 Phase 0.00000 0.00233
Volumetric Bid Rates
Wi thdrawal Charge
Pre-Expansion Shipper 0.00000 0.01551
Expansion Shipper 0.00000 0.08476
Storage Charge
pre-Expansion Shipper 0.00000 0.00056
Expansion Shipper - 2010 Phase 0.00000 0.00233
Rate Schedule SGS-21
Volumetric 0.00000 0.00113
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.
Exhibit No. 3
Case No. INT-G-11-01
Intermountain Gas Company
Page 6 of 16
Northwest Pipeline GP
FERC Gas Tariff
Fifth Revised Volume No.1
First Revised Sheet No. 7-A
Superseding
Substitute Original Sheet No.7 A
STATEMENT OF RATES (Continued)
Effective Rates Applicable to Rate Schedules SGS-2F and SGS-21 (Continued)
Footnotes (Continued)
(2) Rates are daily rates computed on the basis of 365 days per year,
except that rates for leap years are computed on the basis of 366 days.
Rates are also applicable to capacity release service except for short-
term capacity release transactions for a term of one year or less that
take effect on or before one year from the date on which Transporter is
notified of the release, which are not subject to the stated maximum
tariff rate. (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.
(3) Transporter will file proposed tariff sheets listing the phased rates
associated with the Expansion Shippers' Capacity Demand Charge and
Storage Charge rates no sooner than 60 days and no later than 30 days
prior to the proposed effective date for each phase pursuant to the
Commission order in Docket No. CP02-384.
(4) Upon the in-service of the deliverability expansion (November i, 2008),
the Expansion Shippers Demand Charge and the Volumetric Bid Rate
Withdrawal Charge will be effective on an interim basis until the
working gas storage capacity expansion is completed.
(5) Upon the completion of the capacity expansion, the Expansion Shippers'
Capacity Demand Charge and Demand Charge rates along with the
Volumetric Bid related storage charge and Withdrawal Charge rates will
be revised to reflect an allocation of the aggregated costs split 50/50
between the capacity expansion and the deliverability expansion.
Exhibit No. 3
Case No. INT-G-11-01
Intermountain Gas Company
Page 7 of 16
Northwest Pipeline GP
FERC Gas Tariff
Fifth Revised Volume No.1
First Revised Sheet No.8
Superseding
Substitute Original Sheet No.8
STATEMENT OF RATES (Continued)
Effective Rates Applicable to Rate Schedule LS-1
(Dollars per Dth)
Type of Rate
Currently EffectiveTariff Rate (1)
Demand Charge (2 )
Capacity Charge (2)
0.03062
0.00391
Liquefaction
vaporization 0.64110
0.04184
Footnotes
(1) Shippers receiving service under this rate schedule are required to
furnish fuel reimbursement in-kind at the rate specified on Sheet No.
14.
(2) Rates are daily rates computed on the basis of 365 days per year i
except that rates for leap years are computed on the basis of 366 days.
Exhibit NO.3
Case No. INT-G-11-01
Intermountain Gas Company
Page 8 of 16
Northwest Pipeline GP
FERC Gas Tariff
Fifth Revised Volume No.1
Third Revised Sheet No. 14
Superseding
Second Revised Sheet No. 14
STATEMENT OF FUEL USE REQUIREMENTS FACTORS
FOR REIMBURSEMENT OF FUEL USE
Applicable to Transportation Service Rendered Under
Rate Schedules Contained in this Tariff, Fifth Revised Volume No. 1
The rates set forth on Sheet Nos. 5, 6, 7, 8 and 8.1 are exclusive of
fuel use requirements. Shipper shall reimburse Transporter in-kind for its
fuel use requirements in accordance with Section 14 of the General Terms and
Condi tions contained herein.
The fuel use reimbursement furnished by Shippers shall be as follows
for the applicable Rate Schedules included in this Tariff:
Rate Schedule TF-1
Rate Schedule TF-1 - Evergreen Expansion
Incremental Surcharge (1)
Rate Schedule TF-2
Rate Schedule TI-1
Rate Schedule TFL- 1
Rate Schedule TIL- 1
Rate Schedule SGS-2F
Rate Schedule SGS-2I
Rate Schedule LS-1
Rate Schedule LS-2F
Rate Schedule LS-2I
Rate Schedule DEX-1
1.67%
0.50%
1. 67%
1.67%
0.40%
0.40%
1.63%
1.63%
1.63%
1.67%
The fuel use factors set forth above shall be calculated and adjusted
as explained in Section 14 of the General Terms and Conditions. Fuel
reimbursement quantities to be supplied by Shippers to Transporter shall be
determined by applying the factors set forth above to the quantity of gas
nominated for receipt by Transporter from Shipper for transportation, for
injection into storage, or for deferred exchange, as applicable.
Footnote
(1) In addition to the Rate Schedule TF-1 fuel use requirements factor, the
Evergreen Expansion Incremental Surcharge will apply to the quantity of gas
nominated for receipt at the Sumas, SIPI or Pacific Pool receipt points under
Evergreen Expansion service agreements.
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. i-A
FERC GAS TARFF
FOURTH REVISED VOLUM NO. I-A
OF
GAS TRANSMISSION NORTHWEST LLC
FILED WITH THE
FEDERAL ENERGY REGULATORY COMMSSION
Communications Concerning This Tariff
Should Be Addressed To:
Joan Collns
Manager, Tariffs and Compliance
Gas Transmission Northwest LLC
Mailng Address: P.O. Box 2446
Houston, TX 77252-2446
717 Texas Street, Suite 2400
Houston, TX 77002-2761
[phone]
[phone]
Courier Address:
Phone:
Fax:
Exhibit No. 3
Case No. INT-G-11-01
Intermountain Gas Company
Page 9 of 16
Exhibit NO.3
Case No. INT-G-11-01
Intermountain Gas Company
Page 10 of 16
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. I-A
PART 4.1
4.1 - Statement of Rates
FTS-1 and LFS-1 Rates
v.2.0.0 Superseding v.1.0.0
STATEMENT OF EFFECTIVE RATES AN CHAGES FOR
TRASPORTATION OF NATURAL GAS
Rate Schedules FTS-1 and LFS-1
RESERVATIONDAILY DAILY
MILEAGE (a) NON-MILEAGE (b) DELIVERY (c)
(Dh-MILE) (Dh) (Dh-MILE)
FlÆL(d)
(Dh-MILE)
Max. Min.Max.Min.Max.Min.Max.Min.
BASE 0.000463 0.000000 0.036632 0.000000 0.000016 0.000016 0.0050% 0.0000%
STF (e)(e)0.000000 (e)0.000000 0.000016 0.000016 0.0050% 0.0000%
EXTENSION CHAGES
MEDFORD
E-1 (f)0.003290 0.000000 0.005498 0.000000 0.000026 0.000026
E-2 (g)(l)0.008620 0.000000 0.000000 0.000000
(WW)
E-2 (h)(l)0.002972 0.000000 0.000000 0.000000
(Diamond 1)
E-2(h)(l)0.001166 0.000000 0.000000 0.000000
(Diamond 2)
COYOTE SPRIGS
E-3 (i) 0.001412 0.000000 0.001420 0.000000 0.000000 0.000000
OVERRUN CHAGE (j)
SURCHAGES
ACA(k)0.001900 0.001900
Issued: April II, 20II
Effective: April 4, 2011
Docket No. RPII-1986-000
Accepted: May 4, 20II
NOVA Gas Transmission Ltd.
Exhibit NO.3
Case No. INT-G-11-01
Intermountain Gas Company
Page 11 of 16
GAS TRANSPORTATION TARIFF
OF
NOVA GAS TRASMISSION LTD.
Effective Date: November 1, 2010
Exhibit No. 3
Case No. INT-G-11-01
Intermountain Gas Company
Page 12 of 16
NOVA Gas Transmission Ltd.Table of Rates, Tolls and Charges
Page 1 ofl
Service Rates, Tolls and Charges
1.Rate Schedule Ff-R Refer to Attachment "1" for applicable Ff -R Demand Rate per month based on a
thee year term (Price Point "B") & Surcharge for each Receipt Point
Average Firm Servce Receipt Prce (AFSRP)$ 19L.49/io3m3
2.Rate Schedule Ff-RN Refer to Attachment "1" for applicable Ff-RN Demand Rate per month & Surcharge
for each ReceiPt Point
3.Rate Schedule Ff-D Refer to Attachment "2" for applicable Ff -D Demand Rate per month based on a one
year term (price Point "Z") & Surcharge for each Group 1 or Group 2 Delivery Point.
Average Ff -D Demand Rate for Group 1 Delivery Points $ 5.97/GJFf -D Demand Rate for Group 2 Delivery Points i $ 1.741GJFf-D Demand Rate for Group 3 Delivery Points 2 N/A
4.Rate Schedule STF STF Bid Prce = Minimum of 100% of the applicable Ff -D Demand Rate basd on
a one yea term (Price Point "'C') for each Group 1 Delivery Point
5.Rate Schedule Ff-DW Ff-DW Bid Prce = Minimum of 125% of the applicable Ff-D Demand Rate based
on a thee vear term (Pce Point "Y") for each Group 1 Delivery Point
6.Rate Schedule Ff-P Refer to Attchment "3" for applicable Ff -P Demand Rate per month
7.Rate Schedule LRS Contract Term Effective LRS Rate ($/lO'm'/day)
1-5 years 10.64
6-10 yea 8.89
15 years 7.97
20vear 7.08
8.:Rte Schedule LRS-2 LRS-2 Rate per month $ 50,000
9.Rate Schedule LRS-3 LRS-3 Demand Rate per month $ 129.55/103m3
10. Rate Schedule IT-R Refer to Attchment "1" for applicable IT -R Rate for each Recipt Point
11. Rate Schedule IT-D Refer to Attachment "2" for applicable IT-D Rate for each Delivery Point
12. Rate Schedule FCS The FCS Charge is determned in accordance with Attchment "1" to the applicable
Schedule of Service
13. Rate Schedule PT Schedule No PTRate PT Gas Rate 900-0100-0 $ 6O.50/d 1.0103m3/d
900-01001-1 $ 660.oo/d 50.0 103m3/d
14. Rate Schedule OS Schedule No.Charge
2011462247 $27.00 I month
2011462241 $7.00 I month
2011462238 $20.00 I month
2011462242 $3.00 I month
2011462243 $1.00 I month 201146224 $32.00 I month
2011462240 $1.00 I month
2011462245 $1,985.00 I month
2011462252 $3.00 I month
2011462239 $56.00 I month
2011462248 $135.00 I month
2011462249 $75.00 I month
2011462246 $11.00 I month
2011462250 $207.00 I month
2011462251 $204.00 I month
2011463220 $392.00 I month
200300522 $ 83,333.00 I month
15. Rate Schedule CO2 Tier CO2 Rate ($11 O'm')
1 505.25
2 399.89
3 261.29
1. Rate for all Group 2 Delivery Points witli the excetion of Albera-Montaa. Cold Lae and Unity.
2. Pr-D Serice at Group 3 Delivery Points not available until the hilegration Effective Date.
Effective Date: Jan 1,2011 (Amended March 1, 2011)
Foothils Pipe Lines Ltd.
PHASE I
GAS TRASPORTATION TARFF
OF
FOOTIDLLS PIPE LINS LTD.
Exhibit NO.3
Case No. INT-G-11-01
Intermountain Gas Company
Page 13 of 16
Pagel
This Gas Transporttion Tariff is subject to the National Energy Board Act, is available for
inspection during normal business hours and is also available electronically at
ww.transcanada.com. Communications concerning this Gas Transporttion Tariff should be
addressed to:
Foothils Pipe Lines Ltd.
450 First Street S.W.
Calgary, Albert
TIP 5RI
Attention: Greg Szuch
TARIF - PHASE I Effective Date: Aprill, 2007
Foothils Pipe Lines Ltd.
TABLE OF EFFECTIVE RATES
1. Rate Schedule FT, Firm Trausportation Service
Demand Rate
($/GJlKm/onth)Zone 6 0.0064669166
Zone 7 0.0075037155
Zone 8* 0.0158521729
Zone 9 0.0063707902
2. Rate Schedule OT, Overrun Transportation Service
Commodity Rate
($/GJIK)Zone 6 0.0002338721
Zone 7 0.0002713672
3. Rate Schedule IT, Interruptible Transportation Service
Commodity Rate
($/GJlKm)Zone 8* 0.0005732841
Zone 9 0.0002303957
* For Zone 8, Shippers Haul Distance shall be 170.7 kI.
Exhibit NO.3
Case No. INT-G-11-01
Intermountain Gas Company
Page 14 of 16
Pagel
TARF - PHASE I Effective Date: Januar 1,2011
Exhibit 3
Case No. INT-G-11-01
Intermountain Gas Company
Page 15 of 16
FERC GAS TARIFF
SECOND REVISED VOLUME NO. 1
of
QUESTAR PIPELINE COMPANY
filed with the
FEDERAL ENERGY REGULATORY COMMISSION
Communications regarding this Tariff should be addressed to:
L. Bradley Burton,
General Manager Federal Regulatory Affairs and Chief Compliance Offcer
Questar Pipeline Company
180 East 100 South
. P. O. Box 45360
Salt Lake City, UT 84145-0360
Telephone: [phone]
FAX: [phone]
Exhibit 3
Case No. INT-G-11-01
Intermountain Gas Company
Page 16 of 16 .
Questar Pipeline Company
FERC Gas Tariff
Second Revised Volume NO.1
Statement of Rates
Section Version: 2.0.0
STATEMENT OF RATES
Base Annual Currently
Rate Schedule/Tariff Charge EffectiveType of Charge Rate Adjustment 4/Rate
(a)(b)(c)(d)
$$$PEAKING STORAGE
Monthly Reservation Charge
Maximum::2.87375 2.87375/Dth
Minimum 0.00000 O.OOOOO/DthUsage Charge
Injection 0.03872 0.03872/DthWithdrawal0.03872 0.03872/Dth
CLAY BASIN STORAGE
Firm Storage Service - FSS
Monthly Reservation Charge
Deliverabilty
Maximum 21 2.85338 2.85338/Dth
Minimum 0.00000 O.OOOOO/DthCapacity
Maximum 0.02378 0.02378/Dth
Minimum 0.00000 O.OOOOO/Dth
Usage Charge
Injecion 0.01049 0.00190 0.01239/DthWithdrawal0.01781 0.01781/DthAuthorized Overrun Charge
0.30505/Dth .Maximum 0.30315 0.00190
Minimum 0.01781 0.00190 0.01971/DthInterruptible Storage Service - ISS
Usage Charge
Inventory 11
Maximum 0.05927 0.05927/Dth
Minimum 0.00000 O.OOOOO/DthInjection0.01049 0.00190 0.01239/DthWithdrawal0.01781 0.01781/Dth
OPTONAL VOLUMETC RELEASES 7.
Peaking Storage Service - PKSMaximum~3.40890 3.40890/DthMinimum0.00000 O.OOOOO/DthFirm Storage Service - FSSMaximum~0.57068 0.57068/DthMinimum0.00000 O.OOOOO/DthStorage Usage Charges Applicable to Volumetric Releases JI
Peaking Storage Service - PKS:
Injection 0.03872 0.03872/DthWithdrawal0.03872 0.03872/Dth
Clay Basin Storage Service - FSS:
Injection 0.01049 0.00190 0.01239/DthWithdrawal0.01781 0.01781/Dth
PARK AND LOAN SERVICE - PALl
Daily Charge
Maximum 0.30315 0.30315/DthMinimum0.00000 O.OOOOO/DthDelivery Charge 0.02830 0.00190 0.03020/Dth
FUEL REIMBURSEMENT - 2.0% (0.2% utilty and 1.8% compressor fuel) for Rate Schedule PAll
Filed On: May 20,2011 Effective On: July 1,2011
EXHIBIT NOS. 4-10
CASE NO. INT-G-II-0l
INTERMOUNTAIN GAS COMPAN
(7 pages)
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2
0
1
0
An
n
u
a
l
Co
s
t

o
f

S
e
r
v
i
c
e

A
l
l
o
c
a
t
i
o
n

o
f

G
a
s

C
o
s
t

A
d
j
u
s
t
m
e
n
t

(
I
I
Lin
e
BI
I
l
n
g

D
e
t
e
r
m
i
n
a
n
t
s
Pr
i
c
e
s
Co
s
t
No
.
De
s
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r
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p
t
i
o
n
IN
T

-
G
.
1
0
.
0
3
IN
T
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1
0
-
o
3
IN
T

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G
1
0
.
0
3
RS
o
1
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o
2
GS
o
1
LV
.
1
(a
)
(b
)
(c
)
(d
)
(e
)
(f
)
(g
)
(h
)
1
DE
M
A
N
D

C
H
A
R
G
E
S
:
2
Tr
a
n
s
p
o
r
t
t
i
o
n
:
3
NW
P

T
F
-
1

D
e
m
a
n
d

1

(
F
u
l
l

R
a
t
e
)
59
5
,
4
8
3
,
3
0
0
$
0.0
3
9
3
0
$
23
,
4
0
3
,
3
1
2
$
2,
7
5
7
,
5
1
9
$
12
,
7
2
7
.
5
1
6
$
7.
8
3
2
,
9
2
5
$
85
,
3
5
2
4
NW
P

T
F
-
1

D
e
m
a
n
d

1

(
D
i
s
c
o
u
n
t
e
d
)
33
7
.
1
4
0
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2
5
0
0.0
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7
0
4
9,1
1
5
.
8
3
6
1,
0
7
4
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8
2
4,9
5
7
,
5
0
3
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5
1
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6
33
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2
4
5
5
Up
s
t
r
e
a
m

C
a
p
a
c
i
t
y
1,
2
4
1
,
1
2
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8
3
0
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1
4
0
9
17
,
4
8
8
.
5
9
9
2,
0
6
0
,
6
1
2
9,5
1
0
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8
9
4
5,
8
5
3
,
3
1
2
63
,
7
8
1
6
St
o
r
a
g
e
:
7
SG
S
-
1
8
De
m
a
n
d
30
3
,
3
7
0
0.0
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1
5
5
17
1
,
7
4
2

(
2
20
,
2
3
6
93
.
3
9
9
57
,
4
8
1
62
6
9
Ca
p
a
c
i
t
y

D
e
m
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n
d
10
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9
2
0
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9
9
0
0.
0
0
0
6
22
3
.
2
2
5

(
2
)
26
,
3
0
2
12
1
,
3
9
7
74
,
7
1
2
81
4
10
TF
-
2

R
e
s
e
r
v
t
i
o
n
10
,
9
2
0
,
9
9
0
0.
0
3
7
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8
41
4
.
7
7
9
48
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8
7
2
22
5
,
5
7
0
13
8
.
8
2
4
1.
5
1
3
11
TF
-
2

R
e
d
e
l
i
v
e
r
y

C
h
a
r
g
e
10
,
9
2
0
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9
9
0
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0
0
3
0
0
32
,
7
6
3
3.8
6
0
17
,
8
1
8
10
.
9
6
6
11
9
12
LS
-
1
13
De
m
a
n
d
1,1
3
2
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0
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0
0
3
0
6
1,
2
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4
.
3
3
1

(
2
14
8
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9
7
1
68
7
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5
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42
3
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6
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1
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Ca
p
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i
10
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5
6
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4

(
2
)
18
3
,
8
6
4
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4
8
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3
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52
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8
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9
1
15
Li
q
u
e
f
a
c
t
o
n
10
,
9
6
2
,
2
3
5
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0
6
4
1
1
70
2
,
7
8
9
82
,
8
0
7
38
2
,
2
0
0
23
5
,
2
1
9
2,5
6
3
16
Va
p
o
r
i
z
a
t
i
o
n
10
,
9
6
2
,
2
3
5
0.
0
4
1
8
4
45
8
,
6
6
0
54
,
0
2
24
9
,
4
3
5
15
3
,
5
1
0
1,6
7
3
17
TF
-
2

R
e
s
e
r
v
a
t
i
o
n
10
,
9
6
2
,
2
3
5
0.
0
3
7
9
8
41
6
,
3
4
6
49
,
0
5
6
22
6
,
2
4
13
9
,
3
4
8
1,5
1
8
18
TF
-
2

R
e
d
e
l
i
v
e
r
y

C
h
a
r
g
e
10
,
9
6
2
,
2
3
5
0.0
0
3
0
0
32
,
8
8
7
3,
8
7
5
17
,
8
8
5
11
,
0
0
7
12
0
19
Ot
e
r

S
t
r
a
g
e

F
a
c
i
l
i
t
i
e
s
3,
3
4
0
,
4
1
2
39
3
,
5
8
7
1,8
1
6
,
6
3
0
1,1
1
8
,
0
1
3
12
,
1
8
2
-
20
To
t
a
l

F
i
x
e
d

G
a
s

C
o
s
t

C
h
a
r
g
e
s
$
58
,
6
2
6
,
1
5
5
$
6,
9
0
7
,
6
8
5
$
31
,
8
8
2
,
8
9
6
$
19
,
6
2
1
,
7
6
6
$
21
3
,
8
0
8
21
No
r
m
a
l
i
z
e
d

S
a
l
e
s

V
o
l
u
m
e
s

(
I
N
T
.
G
-
1
1
-
0
1

E
s
t
i
m
a
t
e
d

V
o
l
u
m
e
s
)
34
,
1
1
8
,
9
3
2
17
8
,
6
7
8
,
6
0
7
10
5
.
6
8
1
,
3
6
5
2,
9
3
7
,
4
8
0
=
22
Fix
e
d

C
o
s
t

C
o
l
l
e
c
n

p
e
r

T
h
e
r
m

(
L
i
n
e

2
0

d
i
v
i
d
e
d

b
y

L
i
n
e

2
1
)
$
0.
2
0
2
4
6
$
0.
1
7
8
4
4
$
0.
1
8
5
6
7
$
0.
0
7
2
9
23
Cu
r
r
n
t

F
i
x
e
d

C
o
s
t

C
o
l
l
e
c
t
o
n

p
e
r

T
h
e
r
m
$
0.
2
1
0
7
2
$
0,
1
8
1
8
2
$
0.
1
9
5
5
5
$
0.
0
7
1
6
9
-
24
Dif
e
r
e
n
c
e

(
L
i
n
e

2
2

m
i
n
u
s

L
i
n
e

2
3
)
$
(0
.
0
0
8
2
6
)
$
(0
.
0
0
3
3
8
)
$
(0
.
0
0
9
8
8
)
$
0.0
1
1
0
(1
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S
e
e

W
o
r
k
p
a
p
e
r

N
o
,

5
,

L
i
n
e

8
(2
)

P
r
i
c
e

R
e
f
l
e
c
t

D
a
i
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C
h
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e
;

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)
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q
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Exhibit No.6
Case No. INT-G-11-01
Intermountain Gas Company
Page 1 of 1
IN
T
E
R
M
O
U
N
T
A
I
N

G
A
S

C
O
M
P
A
N
Y
Al
l
o
c
a
t
i
o
n

o
f

A
n
n
u
a
l
i
z
e
d

C
r
e
d
i
t
s

R
e
s
u
l
t
i
n
g

f
r
o
m

M
a
n
a
g
e
m
e
n
t

o
f

P
i
p
e
l
i
n
e

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

C
a
p
a
c
i
t
y
Co
s
t

o
f

S
e
r
v
i
c
e

A
l
l
o
c
a
t
i
o
n

o
f

D
e
f
e
r
r
e
d

G
a
s

C
o
s
t
s

(
1
)
Li
n
e
No
.
De
s
c
r
i
p
t
i
o
n
To
t
a
l
RS
.
1
RS
.
2
GS
.
1
LV
.
1
(a
)
(b
)
(c
)
(d
)
(e
)
(f
)
1
Se
g
m
e
n
t
a
t
i
o
n

C
r
e
d
i
t
s
$
(1
,
2
7
1
,
7
8
2
)
$
(1
4
9
,
8
4
9
)
$
(6
9
1
,
6
3
8
)
$
(4
2
5
,
6
5
7
)
$
(4
,
6
3
8
)
2
No
r
t
h
w
e
s
t

P
i
p
e
l
i
n
e

C
a
p
a
c
i
t
y

R
e
l
e
a
s
e
s
(2
,
4
6
2
,
9
0
4
)
(2
9
0
,
1
9
4
)
(1
,
3
3
9
,
4
1
1
)
(8
2
4
,
3
1
7
)
(8
,
9
8
2
)
3
To
t
a
l

M
a
n
a
g
e
m
e
n
t

.
o
f

P
i
p
e
l
i
n
e

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

C
a
p
a
c
i
t
y
$
(3
,
7
3
4
,
6
8
6
)
$
(4
4
0
,
0
4
3
)
$
(2
,
0
3
1
,
0
4
9
)
$
(1
,
2
4
9
,
9
7
4
)
$
(1
3
,
6
2
0
)
4
No
r
m
a
l
i
z
e
d

S
a
l
e
s

V
o
l
u
m
e
s

(
1
/
1
1
1
0

-
1
2
/
3
1
/
1
0
)
33
,
2
8
2
,
6
8
2
17
5
,
5
9
7
,
0
0
9
10
5
,
0
1
7
,
5
8
2
2,
7
0
1
,
0
9
4
5
Pr
o
p
o
s
e
d

P
r
i
c
e

A
d
j
u
s
t
m
e
n
t

P
e
r

T
h
e
r
m
$
(0
.
0
1
3
2
2
)
$
(0
.
0
1
1
5
7
)
$
(0
.
0
1
1
9
0
)
$
(0
.
0
0
5
0
4
)
(1
)

S
e
e

W
o
r
k
p
a
p
e
r

N
o
.
5
,

L
i
n
e

8
-a
-
a
m
ll

;
a

l
l

X
(Q

(
1

e
n

:
:
(1

.
.

(
1

õ
'
3
z
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.
..
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3

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00
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IN
T
E
R
M
O
U
N
T
A
I
N

G
A
S

C
O
M
P
A
N
Y
Pr
o
p
o
s
e
d

T
e
m
p
o
r
a
r
y

S
u
r
c
h
a
r
g
e
s

(
C
r
e
d
i
t
s
)
.

F
i
x
e
d

C
o
s
t
s
De
f
e
r
r
e
d
Ac
c
o
u
n
t

1
8
6
0
Es
t
i
m
a
t
e
d
Co
s
t

o
f

S
e
r
v
i
c
e

A
l
l
o
c
a
t
i
o
n

o
f

D
e
f
e
r
r
e
d

G
a
s

C
o
s
t
s

(
2
)
Li
n
e
Se
p
t
.

3
0
,

2
0
1
1
No
.
De
s
c
r
i
p
t
i
o
n
Ba
l
a
n
c
e

(
1
)
RS
.
1
RS
.
2
GS
.
1
LV
.
1
-
(a
)
(b
)
(c
)
(d
)
(e
)
(f
)
1
Fi
x
e
d

C
o
s
t
s
:
2
Fr
o
m

I
N
T
-
G
-
1
0
-
0
3

(
A
c
c
u
n
t
s

1
8
6
0
.
2
0
5
0

-

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Exhibit No. 9
Case No. INT-G-11-01
Intermountain Gas Company
Page 1 of 1
INTERMOUNTAIN GAS COMPANY
Proposed Temporary Surcharges (Credits). Variable Costs
Line
No.Description
(a)
Amount
(b)
1 Account 1860 Variable Amounts Which Apply to RS.1, RS-2, GS.1 J and LV.1 :
2 Account 1860 Variable Costs $(12,210,476) (1)
3 Normalized Sales Volumes (1/1/10 - 12/31/10)316,598,367
4 Proposed Temporary Surcharge (Credit). Variable Costs $(0.03857)
5 Lost and Unaccounted For Gas Amounts Which Apply to RS.1 J RS-2, and GS.1:
6 Lost and Unacounted For Gas Amounts from INT-G-10-03 (Account 1860-2120)$(396,830) (2)
7 lost and Unacunted For Gas Amorzation (Account 1860-2130)422,028 (3)..
8 (Over)/nder Collection of Lost and Unacounted For Ga frm INT-G-10-o3 25,198
9 Lost and Unacunted For Gas INT-G-11-o1 (1,115,955) (4)
10 Total Lost and Unacounted For Gas Amounts Which Aply to RS-1, RS-2, and GS-1 $(1,090,757)
11 Normalized Sales Volumes (1/1/10 -12/31/10)313,897,273
12 Proposed Temporary Surcharge (Credit). Lost and Unaccounted For Gas Costs $(0.00347)
13 L~st and Unaccounted For Gas Amounts Which Apply to LV.1, T.3, T -4, and T.5:
14 Lost and Unaccunted For Gas Amounts from INT-G-10-3 (Account 1860-2120)$(150,901) (5)
15 Lost and Unacconted For Gas Amortization (Accunt 1860-2140)166,843 (6)
16 (Over)/Under Collection of lost and Unaccnted For Gas fro INT-G-10-3 15,942
17 Lost and Unaccunted For Gas INT-G-11-01 (371,989) (7
18 Total Lost and Unaccounted For Gas Amounts Which Apply to LV-1, T-3, T-4 and T.5 $(356,047)
19 Normalized Sales Volumes (1/1/10 -12/31/10)222,658,322
20 Proposed Temporary Surcharge (Credit) . Lost and Unaccounted For Gas Costs $(0.00160)
(1) See Workpaper No.6, Page 1, Line 17, Column (Q
(2 Se Workpaper No.6, Page 1, Line 19, Column (c)
(3) See Workpaper No.6, Page 1, Line 25, Column (d) .
(4) See Workpaper No.6, Page 1, Line 40, Column (d) plus Line 46, Coumn (e)
(5) See Workaper No.6, Page 1, Line 20, Column (c)
(6) See Workpaper No.6, Page 1, Line 29, Column (d)
(7 See Workpape No.6, Page 1, Line 41, Column (d) plus Line 50, Column (e)
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WORKAPERNOS.I-8
CASE NO. INT-G-II-0l
RECEIVED
2UII AUG II AM 10: 18
INTERMOUNTAIN GAS COMPAN
(9 pages)
Workpaper No. 1
Case No. INT-G-11-01
Intermountain Gas Company
Page 1 of 1
INTERMOUNTAIN GAS COMPANY
Summary of Northwest Pipeline TF.1 Full Rate Demand Costs
Line INT.G.10.03 INT.G.10.03 INT.G.10.03
No.Transportation AnnuaHherms Prices Annual Cost
(a)(b)(c)(d)
1 TF-1 Demand 1 Contract #1 412,537,600 $0.038922 $16,056,788
2 TF-1 Demand 1 Contract #2 25,550,000 0.053543 1,368,012
3 TF-1 Demand 1 Contract #3 73,000,000 0.037984 2,772,833
4 TF-1 Demand 1 Contract #4 23,542,500 0.037984 894,238
5 TF-1 Demand 1 Contract #5 24,353,200 0.037984 925,028
6 TF-1 Demand 1 Contract #6 36,500,000 0.037984 1,386,413
7 Total Annual Cost 595,483,300 $0.039301 $23,403,312
Line INT.G.11.01 INT.G.11.01 INT.G.11.01
No.Transportation Annual Therms Prices Annual Cost
(a)(b)(c)(d)
8 TF-1 Demand 1 Contract #1 413,667,840 $0.038913 $16,097,001
9 TF-1 Demand 1 Contract #2 25,620,000 0.053194 1,362,835
10 TF-1 Demand 1 Contract #3 73,200,000 0.037984 2,780,430
11 TF-1 Demand 1 Contract #4 23,607,000 0.037984 896,688
12 TF-1 Demand 1 Contract #5 49,106,220 0.037984 1,865,251
13 TF-1 Demand 1 Contract #6 36,600,000 0.037984 1,390,212
14 Total Annual Cost 621,801,060 $0.039229 $24,392,417
15 Total Annual Cost Difference (Row 14 minus Row 7)$989,105 (1)
(1) See Exhibit 4, Line 3, Column (h)
Workpaper No. 2
Case No. INT-G-11-01
Intermountain Gas Company
Page 1 of 1
INTERMOUNTAIN GAS COMPANY
Summary of Northwest Pipeline TF.1 Discounted Demand Costs
Line INT.G.10.03 INT.G.10.03 INT.G.10.03
No.Transportation Annual Therms Prices Annual Cost
(a)(b)(c)(d)
1 TF-1 Demand 1 Contract #1 43,680,000 $0.037984 $1,659,141
2 TF-1 Demand 1 Contract #2 28,470,000 0.022790 648,831
3 TF-1 Demand 1 Contract #3 29,404,400 0.020132 591,969
4 TF-1 Demand 1 Contract #4 58,090,000 0.018992 1,103,245
5 TF-1 Demand 1 Contract #5 36,500,000 0.022790 831,835
6 TF-1 Demand 1 Contract #6 36,500,000 0.024851 907,062
7 TF-1 Demand 1 Contract #7 104,495,850 0.032286 3,373,753
8 Total Annual Cost 337,140,250 $0.027039 $9,115,836
Line INT.G.11.01 INT.G.11.01 INT.G.11.01
No.Transportation Annual Therms Prices Annual Cost
(a)(b)(c)(d)
9 TF-1 Demand 1 Contract #1 43,920,000 $0.037984 $1,668,258
10 TF-1 Demand 1 Contract #2 28,548,000 0.020895 596,508
11 TF-1 Demand 1 Contract #3 29,484,960 0.020147 594,030
12 TF-1 Demand 1 Contract #4 58,560,000 0.018992 1,112,171
13 TF-1 Demand 1 Contract #5 36,600,000 0.024690 903,642
14 TF-1 Demand 1 Contract #6 36,600,000 0.024690 903,642
15 TF-1 Demand 1 Contract #7 104,782,140 0.032286 3,383,034
16 Total Annual Cost 338,495,100 $0.027065 $9,161,285
17 Total Annual Cost Difference (Row 16 minus Row 8)$45,449 (1)
(1) See Exhibit 4, Line 4, Column (h)
Workpaper No. 3
Case No. INT-G-11-01
Intermountain Gas Company
Page 1 of 1
INTERMOUNTAIN GAS COMPANY
Summary of Upstream Capacity Costs
Line INT .G.1 0.03 INT .G.1 0.03 INT.G.10.03
No.Transportation Annual Therms Prices Annual Cost
(a)(b)(c)(d)
1 Upstream Agreement #1 189,697,800 $0.019633 $3,724,337
2 Upstream Agreement #2 149,132,660 0.008327 1,241,828
3 Upstream Agreement #3 155,025,220 0.016505 2,558,691
4 Upstream Agreement #4 300,519,100 0.019633 5,900,091
5 Upstream Agreement #5 292,792,050 0.008314 2,434,273
6 Upstream Agreement #6 153,957,000 0.013831 2,129,379
7 Total Annual Cost $17,988,599
8 Estimated Upstream Capacity Release Credits $(500,000)
9 Total Annual Cost Including Capacity Release Credits $17,488,599
Line INT.G.11.01 INT.G.11.01 INT.G.11.01
No.Transportation Annual Therms Prices Annual Cost
(a)(b)(c)(d)
10 Upstream Agreement #1 190,217,520 $0.016760 $3,188,101
11 Upstream Agreement #2 149,664,020 0.009681 1,448,863
12 Upstream Agreement #3 155,553,660 0.017336 2,696,640
13 Upstream Agreement #4 301,155,780 0.016760 5,047,459
14 Upstream Agreement #5 293,524,680 0.009674 2,839,559
15 Upstream Agreement #6 160,127,480 0.013891 2,224,408
16 Total Annual Cost $17,445,030
17 Estimated Upstream Capacity Release Credits $(500,000)
18 Total Annual Cost Including Capacity Release Credits $16,945,030
19 Total Annual Cost Difference (Row 18 minus Row 9)$(543,569) (1)
(1) See Exhibit 4, Line 5, Column (h)
Workpaper NO.4
Case No. INT-G-11-01
Intermountain Gas Company
Page 1 of 1
INTERMOUNTAIN GAS COMPANY
Summry of Oter Storage Facilty Costs
INT-G10-Ð3
Line Monthly INT-G.10-Ð3 INT.G-10-Ð3 INT -G10-3
No.Storae Facilites Biling Deerinant Prices MonthiY Co Annual Cost
(a)(b)(c)(d)(e)
1 Demand Cost .
2 Clay Basin i Reseion 266,250 (1)$0,28533 75,971 $911,652
3 Clay Basin" Reertion 221,840 (1)0.285338 63,29 759,58
4 Clay Basin'" Reservation 213,010 (1)0.285338 60,780 729,360
5 Clay Basin I Capac 31,950,000 (2 0,002378 75,977 911,724
6 Clay Basin" caac 26,625,00 (2 0,002378 63,314 759,768
7 Clay Basin'" Caaci 25,560,00 (2 0.002378 60,782 729,384
8 Tota Deand Cots 84,135,00 (3)400,123 4,801,476
9 Cycling Costs .
10 Clay Bain Cycling Cost 84,135,000 0,000749 $63,010 756,120
11 Rexburg LNG Facility
12 Traspoon Resertion 0
13 Variable Traspor 0
14 Tot Rexburg LNG Facli Cots 0
15 Ste Dend Chare Cr (2,217,184)
16 Tot Costs Including Ste Crii 3,34,412
INT-G.11-Ðl
Line Montly INT-G11-Ð1 INT-G11-Ð1 INT-G11-Ð1
No.Strage Facilites Biling Deermnant Price Moly co Annual Cos
(a)(b)(c)(d)(e)
17 Demand Cost .
18 Clay Basin I Reseti 266,250 (1)0,285338 $75,971 $911,652
19 Clay Basin II Reseion 221,84 (1)0,28538 63,29 759,588
20 Clay Basin'" Reseraton 213,010 (1)0.285338 60,780 729,360
21 Clay Bas i Capacty 31,950,00 (2 0,00238 75,977 911,724
22 Clay Basin" Capac 26,625,00 (2 0,002378 63,314 759,768
23 Cl Basin'" Caac 25,560,00 (2 0.002378 60,782 729,38
24 Tota Deand Cots 84,135,00 (3)400,123 4,801,476
25 Cycling Cost .
26 Clay Bain Cyin Cots 84,135,00 $0,00741 $62,305 $747,665
27 Rexburg LNG Facilit
28 Transpoon Reservati 17,813 213,750
29 Varable Transpotion 21,00
30 Tota Rexburg LNG Facilit Cots $234,750
31 Estimated Ste Deand Chare Cret $(2,700,00)
32 Tota Cots Includmg Ste Crii $3,083,891
33 Tolal Annual Cos Difference Including Strage Credit (Ro 32 minus Row 16)$(2,521) (4)
~1) Charge Bas on Maxmum Daly WiUidraal
(2 Chare Based on Mamum Contial Capaci
~3) Non Aditve BiDing Derminants; Include only Capaci Volume
i" See Exibit 4, Line 19, Coumn (h)
Workpaper NO.5
Case No. INT-G-11-01
Intermountain Gas Company
Page 1 of 1
INTERMOUNTAIN GAS COMPANY
Peak Day Analysis for Demand Allocators
Line Peak Firm Sales Totl
No.Description RS-1 R5-2 GS-1 LV.1 Peak Sales
(a)(b)(c)(d)(e)(f)
DEMAND ALLOCATORS PER CASE NO.INT-G-10-03:
Peak Day Therms 451,358 2,086,332 1,290,473 12,850 3,841,013
Percnt ofT alai ~~~~100,0000%
4 PROPOSED DEMAND ALLOCATORS PER CASE NO.INT-G-11.01:
Peak Day Usage Per Customer 7,12 9,67 42,87
6 January 2011 Actual Customers 64,211 218,218 30,293 312,722
INT -G-11-o1 Peak Day Therms (Line 5 mulitplied by Line 6)457,182 2,110,168 1,298,661 14,150 (1)3,880,161
8 Percnt ofT alai ~~~~100,0000%
(1) Contract Demand Therms
Workpaper NO.6
Case No. INT-G-11-01
Intermountain Gas Company
Page 1 of2
INTERMOUNTAIN GAS COMPAN
Analysis of Acunl1860 Surcharges (Crel1)
Estmatd Sepmbe 3D, 2011
Lile~Decripti 0...l!Amunt Sub-Total ~
(i)til le)(d)(e)(l
ACCONT 1860 VARABLE AMOUNTS:
Net Cumula Defed Ou Balineeln 186.2010 I. of 1011/10 (15,62,976.50)Amorti ill66,200 as of 6l11 15,265,865.96
Estatd Th Sal. 71111ugh 9l11 28,00.31Amatin Ra 0,05116 1,432.49,47
Estatød Am in 186.202 at9J11 16,718,36.43
Ead Blline In 186.2010 II 9l11 1,08,387,93
8 De..d Gn Cos Fro Ptuclfuppliers In 186.2180 at 1011110 1,242,048.71
9 De GasCo From Prppli in 1862180 lhough 6/11 (13,63,25,74)
10 Eomllod Ood Cost ill66,2180 to 7111hh 9l11 (90,4325)
11 Ead Bole ill86.21" II 9l1 (13,297,637,28)
12 Dall Ga. Ei._ Siie Dorr In 186.240 II &l11
13 Inte",11 Deerr in 186.2 at 1011110 119.91
14 Inla Ild ill66.2340 Ilugh 6l11 (970.75)15 Estimatd Inlestlo71111ugh 9l11 (375,42)16 ~lad Bilancoln 186.2 II lIll (1.22.26
17 ESTIMATED ACCOUNT 1860 VARABLE BACE AT 913/11 (12,210.475,61)
18 ACCUNT 1860 LOST AND UNACCOUNTED FOR AMOUNTS:
19 Co CUmula Deer Ga Baan in 186.2120 as of 1011110 (3,63,11)
20 Indual CUmu Defed Gas Balan In 186.2120 as of 1011/10 (150.90.92)
21 Nit Cum_De 0.. Balinc.1n 186.2120 II of 1011110 $(547,731.03)
22 CoAmill66,213Oasof6l11 38,04.51
23 Estol Th Sa 7/111ugh 9l11 21,46,854
24 AmRaIo 0.00131 35.981.5
25 Esol__ ill662130 119l11 01,028,09
26 IncMl'aiAmill862140asof6l11 133,36,01
21 EstolThSa.711l1gh9l11 47,829,38
28 _nRat 0,0070 33,48,57
29 EstatdAmiiil662140at9l11 166,842,58
30 ~ta Bane In 186.2120 119l1 41,139,64
31 Lost & Unacunt For GIl Dterrln 186.2150 at 1011110 18,120,99
32 Tota Lo & Unacted For Gas thgh 6l11 (48.21.5)
33 Esilod Lost 8 Unacunlod For Ga 1I11'" 9l11
34 Esatd Tot Lo & Unaclo For G.. al9l11 (48.21.50)
35 Sue Ra Co of Lo & Unaclod For G..lIgh 6fl1 88,98,59
36 Esimatd Ba Ralo Co of Lo & Unanlod For G.. 7/1l1ugh 9l11 137,06,52
37 Esat Ba Rate Co of Lo & Unacnted For Gas al 9l11 1,026,05.11
38 Esatd Lo & Unalo For De (Tot 10.. _ Ra Co 1011/10 ll'" BIll)(1,50251.61)
39 Estatd Ba.. ii 1862150 atBl11 (1,48,130.62)
40 Co _ of Lo & Unaclo For Ga IJ 75%(1,116,097.97)41 Induma Al of Lost & Unacted For Gas Deeral 25%(3,032.6642_Baneln 116.2150 II lIll (1,48.130,63)
43 Cor Lost & Unaconte For Inrest Dtd In 186.270 at 1011MO 62,19
44 Co lo & Unacnted For Inll Ded il186.2420 thgh 6l11 112,33
45 Estatd Co Inlestlo7/1l1gh 9l11 (31.71)
48 ~ta Bilaneln 1862420119l1 142,81
47 indust Lo & Unaccounted For Inr..t Ded in 116.2 at 101111.20,95
48 In_Lo& Un..nlo For InIaDe_d in 18623 Ilugh 6l11 33.40
49 EsI_d IncN_ Lo & Unaclod For InIe.lto7/1llgh 9l11 (10.66)
50 Ead Bilae In 186.2 II lIl1 43,68
51 ESTIMATED ACCOUNT 1860 LOST AND UNACCOUNTED FOR BACE AT 9130/11 (1,44,804,49)
52 ACCOUN 1860 FIXD AMOUNTS:
53 Ne Cumat Do_ Ga. Balance in 186.2 II 1011110 (2,079,149,03)
54 RS-l De Ga Ba.. ii 186,20 at 1011/10 (6,834,23)55 _foRSliil66,20at6l11 29,981.3
56 Esatd RS-l Th Sa.71111gh 9l11 1,46,46
57 RSl __ Ra 0,00 12,913.84
56 Esat R$-1 Ba in 186.20 at 9111 30,061.3
59 RS-2 Ood Ga Ba.. in 166,2070.11011/10 (5,379.98)
60 _fo RS-2 ii 166,2070at6l11 1,622,711.55
61 Esiol RS-2 Thoi Sal 1Ilhrogh 9l11 13,015,35
62 RS2AmRa 0,0071 126,379,10
63 Estiat RS2 Bace ¡¡ 186.2070 at 9l11 1,743,710,67
64 GS-1De_d Ga Ba.. ii 186200 111011110 6,66.31
65 Am fo G8-1 in 186.20 at 6l11 133,921.53
66 Estatd Th Sa 1I11ugh 9l11 12,984,017
õl GSl Amzsl Ra 0.00138 17,917.94
68 EsolGS-l Ba..ii 186,20119l11 158,401.8
68 Indutial Defed Gas Baan ill86.20 at 1011110 (2.13)70 _aInfo LV-l ii 166.20 at6fl1 $3.4271E.liolLV.l BI 1 &2Thoi sa1Il1gh9l11 53,507
72 LV-l Am Ra 0,0017 90,70
73 Estate Indusna Baan In 186209 at 9J11 214,99
74 Estite Cumull Saline. in 1860.2 It 9JM 1 126,23,75
Workpaper NO.6
Case No. INT-G-11-01
Intermountain Gas Company
Page 2 of2
INTERMOUAIN GAS COMPAN
Analysis of Accunt 18&0 Surcharges (Crit)
Estmatd Sepmber 30, 2011
Un!!_pl.
(II
I!
tbl
fi'" CollCohct. Da..d In 186.2 il101NO
Fixed Co.i Cole. Ded in 186.22 Uigh 6l11
EsalFixedCoCo.iifed_7/1 Uigh9l11
Eiti B.llnc In 116.2 at 9l11
Capacit Rtleuedlrchl'H Deferd In 186.23 at 1011110
Caac Releas_asd Deed in 1860,23 Uigh 6l11Ealial Capac Rele_acd Ded _71 Uigh 9l11Eata Boli...in '86.220 119l11
9 Iirollin 186.243 111011110
10 In iifed in 186,243 Uigh 6l11
11 EaIøI.teslfnm711Ihh9l11
12 EaBoIi...1n 186.243119l1
13 ...naof Pipelie Tniniporttin ClPICIt Deferr In 186.2 at 10111014 Maøg.lof Piif T..po Caac Oe in 186,25 Uijj 6l11
15 Eaald Oøai in 186.253 fr 711. Uigh 9l11
16 EaaId8aaninl86,253Oal9I11
17 RSl _aI in 186,2540 016l11
18 Eaii RSl Th Sa._7N Uigh9l1119 RSl Amli Ra
20 EaiiRS.1Amalin186,25al9I11
1,46,482
0,0136
21 RS2Amin186.24Oal6I11
22 Esite RS.2 Then Sa. fnm 71 fh 9l1123 RS2AmRile
24 EsllteRS.2Am_inl86,254Oat9l11
13,015,35
0,01192
25 GS.1 Amin 186.240016l11
26 Eaii GSl Th Safnm 7/1 Uigh9l11'l GSl__
28 EalialdGS1Amin186.25alIl11
12,94,017
0,01261
29 EsaldCoAmfiln 186,2540019l11
30 LY-1 Amal in 186,2550016l11
31 Esii LY-111 1&2 Th Sa_711 Uigh 9l11
32 LY-1AmRata
33 EslatadLY.1Aminl86,25al9I11
53,5070,00
34 Eslmatø InduUialAr in 186.25 at9l11
35 Ea Biliiln 186.2 at Illl
36 ESTMATED ACCOUN 1860 FIXD BACE AT 910111
37 TOTAL DEFERRED ACCOUN 166 BACE
INTERMOUNTAIN GAS COMPANY
Analysis of LV.1 Tariff Block 1, Block 2, and Block 3 Adjustments
Line
No.Description
(a)
Block 1
Therm Sales
(b)
LV-1 Therm Sales (1/1/10 -12/31/10)2,701,094
2 Blocks 1 and 2 Therm Sales 2,701,094
3 Percent Therm Sales between Blocks 1 and 2 100.000%
4 Proposed Adjustmentto LV-1 Tariff (1)
5 LV-1 Therm Sales (1/1/10 -12131/10)
6 Annualized Adjustment (Line 4 multiplied by Line 5)
7 Annualized Adjustment (Line 4 multiplied by Line 5)
8 Percent Annualized Sales included in Block 1 and Block 2
9 Adjustment to Block 1 and 2 (Line 7 multiplied by Line 8)
10 Block 1 and 2 Therms
11 Price AdjustmenUTherm Block 1 and 2 (Line 9 divided by Line 10)
12 WACOG Commodity Charge Change (2)
13 Total Price AdjustmenUTherm Block 1 and Block 2
14 Price AdjustmenUTherm Block 3 (3)
15 WACOG Commodity Charge Change (2)
16 Eliminate INT-G-10-03 Variable Temporary
17 Total Price AdjustmenUTherm Block 3
Block 2
Therm Sales
(c)
0.000%
Block 3
Therm Sales
(d)
o
o
(1) See Exhibit No.4; Line 30, Column (I) minus the difference of Line 21, Column (0 minus Line 21, Column (c)
(2) See Exhibit No.4; Line 21, Column (f) minus Line 21, Column (c)
(3) See Exhibit No.6, Line 3, Column (e)
Workpaper No. 7
Case No. INT-G-11-01
Intermountain Gas Company
Page 1 of 1
Total
(e)
o 2,701,094
2,701,094
100.000%
$0.00843
2,701,094
$22,762
$22,762
100.000%
$22,762
2,701,094
$
$
0.00843
(0.03869)
(0.03026)
$(0.04017)
(0.03869)
0.05186
(0.02700)$
Workpaper No. 8
Case No. INT-G-11-01
Intermountain Gas Company
Page 1 of 1
INTERMOUNTAIN GAS COMPANY
Analysis of Lost and Unaccounted for Gas ("L&U")
Line
No.Description
(a)
Detail
(b)
Amount
(c)
1 Lost and Unaccounted for Gas INT-G-11-01 (Therms)
2
3
Projected Oct 10 - Sep 11 L&U (Therms)
Estimated Oct 10 - Sep 11 Sales 1
(894,032)
563,763,803
4 Oct 10 .. Sep 11 L&U Factor (line 2 divided by line 3)-0.159%
5 Lost and Unaccounted for Gas INT-G-11-01 (Dollars)
6 Lost & Unaccounted for Gas (1860-2150) 2 $(480,202)
7 Estimated Oct 10 - Sep 11 Sales 1 563,763,803
8 L&U rate per therm embedded in base rates $0.00182
9 Oct 10 - Sep 11 Collection of Lost & Unaccounted for Gas 1,026,050
10 Projected L&U (Over)/Under Collection (Line 6 minus Line 9)$(1,506,252)
1 Estimated Oct 09 - Sep 10 Sales (Therms)
RS-1
RS-2
GS-1
Industrial
Total Sales
35,247,196
181,799,847
112,839,289
233,877,471
563,763,803
2 See Workpaper No.6, Page 1, Line 34, Column (c)