20130812Application.pdf

EXECUTIVE OFFICES
INTERMOUNTAIN GAS COMPANY c
555 SOUTH COLE ROAD •P.O.BOX 7608 •BOISE,IDAHO 83707 •[phone] •FAX:[phone] ,,,.-r I ‘2U\!b —)
August 9,2013
Ms.Jean Jewel!
Commission Secretary
Idaho Public Utilities Commission
472 W.Washington St.
P.O.Box 83720
Boise,ID 83720-0074
RE:Case No.INT-G-13-05
Dear Ms.Jewell:
UTS
Attached for consideration by this Commission are the original and seven (7)copies of Intermountain
Gas Company’s Application for Authority to Change Its Prices on October 1,2013.
If you should have any questions regarding this Application please contact me at 377-6168.
cc:Scott Madison
Morgan W.Richards
Sincerely,
l P.Mcrath
Director —Regulatory Affairs
Intermountain Gas Company
Enclosure
r._q p 3-1.5INTERMOUNTAINGASCOMPANY
CASE NO.INT-G-13-05 LTIUt COMi
APPLICATION,
EXHIBITS,
AND
WORKPAPERS
In the Matter of the Application of INTERMOUNTAIN GAS COMPANY
For Authority to Change Its Prices on October 1,2013
(October 1,2013 Purchased Gas Cost Adjustment Filing)
Morgan W.Richards Jr.,ISB 1913
Richards Law Office
P.O.Box 2076
Boise,Idaho 83701
Telephone:[phone]
Attorney for Intermountain Gas Company
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
In the Matter of the Application of Case No.NT-G-13-05
INTERMOUNTAIN GAS COMPANY APPLICATION
for Authority to Change Its Prices
Intermountain Gas Company (“Intermountain’or “Company”),a subsidiary of MDU
Resources Group,Inc.with general offices located at 555 South Cole Road,Boise,Idaho,hereby
requests authority,pursuant to Idaho Code Sections 61-307 and 61-622,to place into effect October
1,2013 new rate schedules which will increase its annualized revenues by $10.3 million,pursuant
to the Rules of Procedure of the Idaho Public Utilities Commission (“Commission”).Because of
changes in Intermountain’s gas related costs,as described more fully in this Application,
Intermountain’s earnings will not increase as a result of the proposed changes in prices and
revenues.Intermountain’s current rate schedules showing proposed changes are attached hereto as
Exhibit No.1 and are incorporated herein by reference.Intermountain’s proposed rate schedules are
attached hereto as Exhibit No.2 and are incorporated herein by reference.
Communications in reference to this Application should be addressed to:
Michael P.McGrath
Director —Regulatory Affairs
Intermountain Gas Company
Post Office Box 7608
Boise,ID 83707
and
Morgan W.Richards Jr.
Richards Law Office
P.O.Box 2076
Boise,Idaho 83701
In support ofthis Application,Intermountain does allege and state as follows:
APPLICATION -2
I.
Intermountain is a gas utility,subject to the jurisdiction of the Idaho Public Utilities
Commission,engaged in the sale of and distribution of natural gas within the State of Idaho under
authority of Commission Certificate No.219 issued December 2,1955,as amended and
supplemented by Order No.6564,dated October 3,1962.
Intermountain provides natural gas service to the following Idaho communities and counties
and adjoining areas:
Ada County -Boise,Eagle,Garden City,Kuna,Meridian,and Star;
Bannock County -Chubbuck,Inkom,Lava Hot Springs,McCammon,and Pocatello;
Bear Lake County -Georgetown,and Montpelier;
Bingham County -Aberdeen,Basalt,Blackfoot,Firth,Fort Hall,Moreland/Riverside,and Shelley;
Blame County -Bellevue,Halley,Ketchum,and Sun Valley;
Bonneville County -Ammon,Idaho Falls,lona,and Ucon;
Canyon County -Caldwell,Greenleaf,Middleton,Nampa,Parma,and Wilder;
Caribou County -Bancroft,Conda,Grace,and Soda Springs;
Cassia County -Burley,Declo,Malta,and Raft River;
Elmore County -Glenns Ferry,Hammett,and Mountain Home;
Fremont County -Parker,and St.Anthony;
Gem County -Emmett;
Gooding County -Gooding,and Wendell;
Jefferson County -Lewisville,Menan,Rigby,and Ririe;
Jerome County -Jerome;
Lincoln County -Shoshone;
Madison County -Rexburg,and Sugar City;
Minidoka County -Heyburn,Paul,and Rupert;
Owyhee County —Bruneau,and Homedale;
Payette County -Fruitland,New Plymouth,and Payette;
Power County -American Falls;
Twin Falls County -Buhl,Filer,Hansen,Kimberly,Murtaugh,and Twin Falls;
Washington County -Weiser.
Intermountain’s properties in these locations consist of transmission pipelines,liquefied
natural gas storage facilities,distribution mains,services,meters and regulators,and general plant
and equipment.
II.
Intermountain seeks with this Application to pass through to each of its customer classes
changes in gas related costs resulting from:1)an increase in costs billed Intermountain from firm
transportation providers including Northwest Pipeline OP (“Northwest”or “Northwest Pipeline”),
2)an increase in Intermountain’s Weighted Average Cost of Gas,or “WACOG”,3)an updated
customer allocation of gas related costs pursuant to the Company’s Purchased Gas Cost Adjustment
APPLICATION -3
(“PGA”)provision,4)the inclusion of temporary surcharges and credits for one year relating to
natural gas purchases and interstate transportation costs from Intermountain’s deferred gas cost
accounts,and 5)benefits resulting from Intermountain’s management of its storage and firm
capacity rights on various pipeline systems.Intermountain also seeks with this Application to
eliminate the temporary surcharges and credits included in its current prices during the past 12
months,pursuant to Case No.INT-G-12-01.The aforementioned changes would result in an
overall price increase to Intermountain’s RS-1,RS-2,GS-1 and LV-1 customers and a price
decrease to Intermountain’s T-3,T-4 and T-5 customers.
These price changes are applicable to service rendered under rate schedules affected by and
subject to Intermountain’s Purchased Gas Cost Adjustment (‘tPGA”),initially approved by this
Commission in Order No.26109,Case No.TNT-G-95-1,and additionally approved through
subsequent proceedings.
Exhibit No.3 contains pertinent excerpts from applicable pipeline tariffs.Exhibit No.4
summarizes the price changes in:1)Intermountain’s base rate gas costs,2)its rate class allocation,
and 3)adjusting temporary surcharges or credits flowing through to Intennountain’s direct sales
customers.Exhibit Nos.3 and 4 are attached hereto and incorporated herein by reference.
III.
The current prices of Intermountain are those approved by this Commission in Order
No.32653,Case No.INT-G-12-01.
Iv.
Intermountain’s proposed prices incorporate all changes in costs relating to the
Company’s firm interstate transportation capacity including,but not limited to,any price changes
or projected cost adjustments implemented by the Company’s pipeline suppliers as well as any
volumetric adjustments in contracted transportation agreements which have occurred since
Intermountain’s PGA filing in Case No.INT-G-12-01.
Northwest Pipeline and its shippers settled Northwest’s recent rate case filing resulting in
an approximate 9%price increase effective January 1,2013.Case No.INT-G-12-01
incorporated this increase for a pro-forma nine month period.This PGA includes the annualized
impact pertaining to the costs associated with the additional three months.Intermountain
continues to effectively manage its natural gas storage assets at Northwest’s Jackson Prairie and
Questar Pipeline’s Clay Basin storage facilities.Supporting documents relating to Line 19 of
APPLICATION -4
Exhibit No.4,include $2.7 million in savings from Intermountain’s management of these
storage assets.
Exhibit No.4,Lines 1 through 19,details the proposed changes to Intermountain’s prices
resulting from Intermountain’s cost of storage,and interstate and upstream capacity from its
various suppliers.
V.
The WACOG reflected in Intermountain’s proposed prices is $O.37341 per therm,as shown
on Exhibit No.4,Line 21,Col.(f).This compares to $O.334$9 per therm currently included in the
Company’s tariffs.
Current deliverable shale gas reserves in North America continue to be significant.
However,recent improvements in our nation’s economy coupled with an increase in natural gas
fired electric generation translate into increased demand on these abundant supplies which,in turn,
cause upward pressure on natural gas prices.from a historical perspective,however,robust natural
gas supplies combined with significant storage balances have kept natural gas prices significantly
lower as compared to just a few years ago.
Additionally,the proposed WACOG includes benefits to Inteimountain’s customers
generated by the Company’s management of its significant natural gas storage assets.Because gas
added to storage is procured during the summer season when prices are typically lower than during
the winter,the cost of Intermountain’s storage gas is normally less than what could be obtained on
the open market in winter months.Additionally,in an effort to further stabilize the prices paid by
our customers during the upcoming winter period,Intermountain has entered into various fixed
price agreements to lock-in the price for significant portions of its underground storage and other
winter “flowing”supplies.
Intermountain believes that the WACOG proposed in this Application,subject to the effect
of actual supply and demand and based on current market conditions,provides today’s most
reasonable forecast of gas costs for the 2013-2014 PGA period.Intermountain will employ,in
addition to those fixed price agreements already in place,cost effective price arrangements to
further secure the price of flowing gas embedded within this Application when,and if,those pricing
opportunities materialize in the marketplace.
Intermountain believes that timely natural gas price signals enhance its customer’s ability to
make informed and appropriate energy use decisions.The Company is committed to alert
APPLICATION -5
customers to impending price changes before their winter natural gas usage occurs.By employing
the use of customer mailings,the Company’s website,and various media resources,Intermountain
will continue to educate its customers regarding the wise and efficient use of natural gas,billing
options available to help manage their energy budget,and pending natural gas price changes.
VI.
Pursuant to Case No.1NT-G-12-0l,Intermountain included temporary surcharges and
credits in its October 1,2012 prices for the principal reason of collecting or passing back to its
customers deferred gas cost charges and benefits,as outlined in Case No.TNT-G-12-01.Line 26 of
Exhibit No.4 reflects the elimination of these temporary surcharges and credits.
WI.
Intermountain’s PGA tariff includes provisions whereby Intermountain’s proposed prices
will be adjusted for updated customer class sales volumes and purchased gas cost allocations,
pursuant to the Company’s approved cost of service methodology.Intermountain’s proposed prices
include a fixed cost collection adjustment pursuant to these PGA provisions,as outlined on Exhibit
No.5,Line 24.The price impact of this adjustment is included on Exhibit No.4,Line No.27.The
fixed Cost Collection Rate resulting from the adjustment plus the annual difference in demand
charges from Exhibit No.4,Lines 1 —19,Col.(h)is shown on Exhibit No.5,Line 2$.Exhibit No.
5 is attached hereto and incorporated herein by reference.
VIII.
Intermountain proposes to pass through to its customers the benefits that will be generated
from the management of its transportation capacity totaling $3.9 million as outlined on Exhibit No.
7.These benefits include credits from a segmented release of a portion of Intermountain’s firm
capacity rights on Northwest Pipeline and other non-segmented capacity releases.Intermountain
proposes to pass back these credit amounts via the per therm credits,as detailed on Exhibit No.7
and included on Exhibit No.6,Line 1.Exhibit Nos.6 and 7 are attached hereto and incorporated
herein by reference.
APPLICATION -6
Ix.
Intermountain proposes to allocate deferred gas costs from its Account No.186 balance to
its customers through temporary price adjustments to be effective during the 12-month period
ending September 30,2014,as follows:
1)Intermountain has deferred fixed gas costs in its Account No.186.The credit amount
shown on Exhibit No.8,Line 8,Col.(b)of $8.8 million is attributable to a true-up of the collection
of interstate pipeline capacity costs,the true-up of expense issues previously ruled on by this
Commission,and mitigating capacity release credits generated from the incremental release of
Intermountain’s pipeline capacity.Intermountain proposes to pass back these balances via the per
therm credits,as detailed on Exhibit No.$and included on Exhibit No.6,Line 2.Exhibit No.8 is
attached hereto and incorporated herein by reference.
2)Intermountain has also deferred in its Account No.186 a variable gas cost debit of $3.1
million,as shown on Exhibit No.9,Line 2,Col.(b).This deferred debit is attributable to
Intermountain’s variable gas costs since October 1,2012.Intermountain proposes to collect this
balance via a per therm debit,as shown on Exhibit No.9,Col.(b),Line 4 and included on Exhibit
No.6,Line 3.
3)finally,Intermountain 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 through 20.This
deferral results in net per therm decreases to Intermountain’s sales customers,as illustrated on
Exhibit No.9,Line 12,Col.(5),and included on Exhibit No.6,Line 3.The Lost and Unaccounted
for Gas deferral also results in a per therm decrease for Intermountain’s transportation customers as
shown on Exhibit No.9,Line 20,Col.(b).Exhibit No.9 is attached hereto and incorporated herein
by reference.
x.
Pursuant to Commission Order No.32793,Case No.1NT-G-13-02,Intermountain has
deferred in its Account No.186 variable gas cost credits associated with sales of liquefied natural
gas at its Nampa,Idaho facility.Intermountain proposes to pass back this sales credit as outlined on
Exhibit No.10,Line 5.Exhibit No.10 is attached hereto and incorporated herein by reference.
APPLICATION -7
XI.
Intermountain has allocated the proposed price changes to each of its customer classes based
upon Intermountain’s PGA provision.However,a straight cent per therm price increase was not
utilized for the LV-1 tariff as no fixed costs are currently recovered in the tail block of the LV-1
tariff.The proposed changes in the WACOG,and variable deferred debits and credits as outlined
on Exhibit No.’s 9 and 10,are applied to all three blocks of the LV-l tariff.However,all
adjustments relating to fixed costs are applied only to the first two blocks of the LV-1 tariff.
MI.
Each block of the proposed LV-1,1-3,T-4 and T-5 tariffs include a uniform cents per therm
decrease to adjust for Lost and Unaccounted For Gas as detailed on Exhibit No.9,Lines 13 through
20,Col.(b).The prices,including the proposed adjustment for each block of the T-3,T-4 and 1-5
tariffs,and the removal of existing temporary price changes,are outlined on Exhibit No.1,Page 1,
Lines 21 through 32.
XIII.
Exhibit No.11 is an analysis of the overall price changes by class of customer.Exhibit No.
11 is attached hereto and incorporated herein by reference.
XIV.
The proposed overall price changes herein requested among the classes of service of
Intermountain reflect a just,fair,and equitable pass-through of changes in gas related costs to
Intermountain’s customers.
XV.
This Application is filed pursuant to the applicable statutes and the Rules and Regulations of
the Commission.This Application has been brought to the attention of Intermountain’s customers
through a Customer Notice and by a Press Release sent to daily and weekly newspapers,and major
radio and television stations in Intermountain’s service area.The Press Release and Customer
Notice are attached hereto and incorporated herein by reference.Copies of this Application,its
Exhibits,and Workpapers have been provided to those parties regularly intervening in
Intermountain’s rate proceedings.
APPLICATION -$
xv’.
Intermountain requests that this matter be handled under modified procedure pursuant to
Rules 20 1-204 of the Commission’s Rules of Procedure.Intermountain stands ready for immediate
consideration of this matter.
APPLICATION -9
WHEREFORE,Intermountain respectfully petitions the Idaho Public Utilities Commission
as follows:
a.That the proposed rate schedules herewith submitted as Exhibit No.2 be approved
without suspension and made effective as of October 1,2013 in the manner shown on Exhibit No.
2.
b.That this Application be heard and acted upon without hearing under modified procedure,
and
c.for such other relief as this Commission may determine proper herein.
DATED at Boise,Idaho,this 9th day of August,2013.
INTERMOUNTAIN GAS COMPANY Richards Law Office
By
_______________
By 2.1S-j,Michi WMc ath Morgan W.chards,Jr.u
Ditor —Regulatory Affairs Attorney for Intermountain Gas Company
APPLICATION -10
CERTIFICATE OF MAIUNG
I HEREBY CERTIFY that on this 9th day of August,2013,I served a copy of the
foregoing Case No.JNT-G-13-05 upon:
Ed Finldea Chad Stokes
Northwest Industrial Gas Users Cable Huston et al.
326 5th St 1001 SW Fifth Avenue,Suite 2000
Lake Oswego,OR 97034 Portland,Oregon 97204-1136
R.Scott Pasley Don Sturtevant
J.R.Simplot Company J.R.Simplot Company
P0 Box 27 P0 Box 27
Boise,D $3707 Boise,ID $3707
by depositing true copies thereof in the United States Mail,postage prepaid,in envelopes addressed
to said persons at the above addresses.
Mi .McGrath
ector —Regulatory Affairs
APPLICATION -11
EXHIBIT NO.1
CASE NO.INT-G-13-05
INTERMOUNTAIN GAS COMPANY
CURRENT TARIFFS
Showing Proposed Price Changes
(11 pages)
Exhibit No.1
Case No.INT-G-13-05
Intermountain Gas Company
Page 1 of 11
COMPARISON OF PROPOSED OCTOBER 1,2013 PRICES
TO OCTOBER 1,2012 PRICES
Proposed
Line Prices per Proposed October 1,2013
No.Rate Class INT-G-12-01 Adjustment Prices
(a)(b)(c)(d)
I RS-J
2 April -November $0.85696 $0.01616 $0.87312
3 December-March 0.74440 0.01616 0.76056
4 RS-2
5 April -November 0.70238 0.02887 0.73125
6 December -March 0.66875 0.02887 0.69762
7 GS-1
8 April -November
9 Block 1 0.72011 0.04946 0.76957
10 Block 2 0.69838 0.04946 0.74784
11 Block 3 0.67736 0.04946 0.72682
12 December -March
13 Block 1 0.66926 0.04946 0,71872
14 Block 2 0.64806 0.04946 0.69752
15 Block 3 0.62760 0.04946 0.67706
16 CNG Fuel 0.62760 0.04946 0.67706
17 LV-1
18 Block 1 0.45461 0.06797 (1)0.52258
19 Block 2 0.41612 0.06797 (1)0.48409
20 Block 3 0.34014 0.04836 (2)0.38850
21 T-3
22 Block 1 0.058 19 (0.00360)0.05459
23 Block 2 0.02559 (0.00360)(3)0.02199
24 Block 3 0.01146 (0,00360)13)0.00786
25 T-4
26 Block 1 0.06242 (0.00361)(3)0.05881
27 Block 2 0.02393 (0.00361)(3)0.02032
28 Block 3 0.00920 (0.00361)(3)0.00559
29 T-5
30 Demand Charge 0.84253 -0.84253
31 Commodity Charge 0.00505 (0.00360)(3)0.00145
32 Over-Run Service 0.04764 (0.00360)(3)0.04404
33 IS-R
34 April -November 0.66875 0.02887 0.69762
35 December -March 0.66875 0.02887 0.69762
36 IS-C (5)
37 April -November
38 Block 1 0.66926 0.04946 0.71872
39 Block 2 0.64806 0.04946 0.69752
40 Block 3 0.62760 0.04946 0.67706
41 December -March
42 Block 1 0.66926 0.04946 0.71872
43 Block 2 0.64806 0.04946 0.69752
44 Block 3 0.62760 0.04946 0.67706
See Workpaper No.7,Line 13,Column (e)
(2)See Workpaper No,7,Line 17,Column (e)
(3)Remove INT-G-l2-0l temporary of $000259 and add the temporary from Exhibit 9,Line 20,Column (b)
plus the temporary from Exhibit 10,LineS,Column (g)-(h)
The IS-R price is based on the RS-2 December -March price and receives the same PGA adjustments.
(5)The IS-C price is based on the GS-1 December -March price and receives the same PGA adjustments.
Rate Schedule RS-1
RESIDENTIAL SERVICE
Exhibit No.1
Case No.INT-G-13-05
Intermountain Gas Company
Page 2 of 11
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
3tpt.28,2012 Oct.1,2012
Per O.N.32653
Jean D.Jewell Secretary
AVAILABILITY:
Available to individually metered consumers not otherwise specifically provided for,using
natural gas for residential purposes.
RATE:
Monthty minimum charge is the customercharge.
For billing aerlods endina Airil throuah November
Customer Charge -$2.50 per bill
Commodity Charge -$0.05090 per therm*$0.8731 2
For billing oeriods endina December throuah March
Customer Charge -$6.50 per bill
Commodity Charge -$0.74440 pertherm*$076056
*includes:
Temporary purchased gas cost adjustment of $(0.02618)$fO.041 97)
Weighted average cost of gas of $0.3348t $0.37341
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.
lssuedby.Intermountain Gas Company
By Ctott Madison Michaei P.McGrath Title:Vice PresidentS.Chief Accounting Officer
Effective:October 1,2012 October 1,2013 Director,Regulatory Affairs
I.P.U.C.Gas Tariff
Second Revised Volume No.1
(Supersedes First Revised Volume No.1)
Forty-i#Revised Sixth Sheet No.01 (Page 1 of 1)
Intermountain Gas Company
Exhibit No.1
Case No.INT-G-13-05
Intermountain Gas Company
Page 3 of 11
I.P,U.C.Gas Tariff
Second Revised Volume No.I IDAHO PUBLIC UTILITIES COMMISSION
(Supersedes First Ryied Volume No.1)Approved Effective
Fortv.Rffit Revised sixth Sheet No.02 (Page 1 of 1 20,2072 O.,t.1,2012
Intermountain Gas Company Per O.N.32C53
Jean D.Jewell Secretary
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 billina oerlods endlna AvrII throuah November
Customer Charge -$2.50 per bill
Commodity Charge 40.70230 pertherm’$073125
For billina nerlods endlna December throuah March
Customer Charge -$6.50 per bill
Commodity Charge -$0.66875 per therm’$0.69762
‘Includes:
Temporary purchased gas cost adjustment of $(0.02332)$(0.031 26)
Weighted average cost of gas of $0.33489 $0.37341
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
y:Ccott Madison Michael P.Mcgrath Title:Vice rrcsidcnt 3 Chicf Accounting Offiocr
Effective:October 1,2012 October 1,2013 Director,Regulatory Affairs
Exhibit No.1
Case No.INT-G-13-05
Intermountain Gas Company
Page 4 of 11
LP.U.C.Gas Tariff
Supersedes Rrst Revised Vume No.1)IDAHO PUBLIC UTILITIES COMMISSION
Forty-3evth Revised Eighth Sheet No.03 (Page 1 of 2)Approved Effective
Name ept.20,2012 Oct.1,2012
of Utdity tntermountain Gas Company Per O.N.32GS3
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 themis 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-
yearwritten servIce contract.
RATE:
Monthly minimum charge is the customer charge.
For billina aeriods ending AerlI throuah November
Customer Charge -$2.00 per bill
CommodIty Charge -First 200 thenns per bill @ 0.72011*$076957
Next 1,600 therms per bill @ $0.6830*$0.74784
Over 2,000 therms per bill $0.6fl36*$072682
For billing aedods ending December through March
Customer Charge -$9.50 per bill
CommodIty Charge -First 200 therms per bill @ $0.Cc2G*$0.71 872
Next 1,800 thenns per bill @ $0.C4006*$0.69752
Over 2,000 themis per bill c $0.62760*$067706
*IncIuUes:
Temporary purchased gas cost adjustment of $(0.02001)$(0.02360)
Weighted average cost of gas of $0.33480 $037341
issued by:Intermountain Gas Company
By:6cott Medi3otr Michael P.McGrath Title:Vice r-esident &Chief Accounting Officer
Effective:October 1,2012 October 1.2013 Director,Regulatory Affairs
Exhibit No.1
Case No.INT-G-13-05
Intermountain Gas Company
Page 5 of 11
I.P.U.C.Gas Tariff
No.1)IDAHO PUBLIC UTILITIES COMMISSION
Forty-Deieth Revised Eighth Sheet No.03 (Page 2 of 2)Approved Effective
Name Gept.20,20f 2 Oct.f,2072E
oTUtiIft Intermountain Gas Company Per ON.32653
Jean 0.JewelI Secretary
Rate Schedule GS-1
GENERAL SERVICE (Continued)
For separately metered deliveries of gas utilized solely as Compressed Natural Gas Fuel In
vehicular Internal combustion engines.
Customer Charge -$9.50 per bill
Commodity Charge -$0.C27C0 per therm*$0.67706
*lncludes:
Temporary purchased gas costadjustmentofS(0.020C1)sf002360)
Weighted average cost of gas of .334O9 50.37341
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for In the
Company’s Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
1.Any GS-1 customer who leaves the GS-1 service will pay to lntermountain Gas Company,
upon exiting the GS-1 service,all gas and transportation related costs Incurred to serve
the customer during the GS-1 service period not borne by the customer during the time
the customer was using GS-f service.Any GS-1 customer who leaves the GS-f service
will have refunded to them,upon exiting the GS-1 service,any excess gas commodity or
transportation payments made by the customer during the time they were a GS-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:Ccott Madison Michael P.McGrath Title;Vice rresidcnt Chief Accounting Officer
Effective:October 1,2012 October 1,2013 Director,Regulatory Affairs
Exhibit No.1
Case No.INT-G-13-05
Intermountain Gas Company
Page 6 of 11
I.P.U.C.Gas Tariff
Second Revised Volume No.1 IDAHO PUBLIC UTILITIES COMMISSION(Supersedes First Revised Volume No.1)A r ved EffectiveFifty-Fifth Revised Sixth Sheet No.04 (Page 1 of2)28,2012 Od.1,201 2
Intermountain Gas Company r&O.N.3265
Jean 0.JeweIl Secretary
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-I or any new customer
whose usage does not exceed 500,000 therms annually,upon execution of a one-year minimum written
service contract for firm sales service in excess of 200,000 therms per year.
MONTHLY RATE:
Commodity Charge:
First 250,000 therms per bill $0.44G1*$052258
Next 500,000 thenns per bill $0AfG12 $0.48409
Amount Over 750,000 therms per bill @ t0.340I4*$038850
The above prices include weIghted average cost of gas of $0.33409 $037341
*Includes temporary purchased gas cost adjustment of $(0.02818)$f0.02708)
**Includes temporary purchased gas cost adjustment of $(0.0013C)$000848
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:
I.All natural gas service hereunder is subject to the General Service Provisions of the
Company’s Tariff,of which this Rate Schedule is a part.
2.Any LV-1 customer who exits the LV-1 service at any time (including,but not lImIted to,the
expiration of the contract term)will pay to lntermountain 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-i contract period.Any LV-1 customer will have
refunded to them,upon exiting the LU-f service,any excess gas and/or interstate transportation related
payments made by the customer during the LU-I contract period.
3.In the event that total deliveries to any customer within the last three contract periods met
or exceeded the 200,000 therm threshold,but the customer during the current contract period used
less than the contract minimum of 200,000 therms,an additional amount shall be bIlled.The additionalamountshallbecalculatedbybillingthedeficitusagebelow200,000 therms at the LV-1 Block I rateadjustedfortheremovalofvariablegascosts.The customer’s future eligibility for the LU-I RateSchedulewillberenegotiatedwiththeCompany.
issued by:Intermountain Gas Company
..Michael P.Mcc,taoBy.3tt MaJji i itie:Vioc Prcsident 3 Chief Accounting OfficerEffective:Octobcr 1,2012 October 1 2013 Director,Regulatory Affairs
Exhibit No.1
Case No.INT-G-13-05
Intermountain Gas Company
Page 7 of 11
I.P.U.C.Gas Tariff IDAHO PUBLIC UTILITIES COMMISSION
Second Revised Volume No.I Approved Effective
(Supersedes First Revised Volume No.1)Sc t 8 Oct 1 “012&eventh Revised Eighth Sheet No.11 (Page 1 of 2)
—Per O.N.32653
Intermountain Gas Company Jean 0.JewelI Secretary
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:First 100,000 therms transported$0.0S01 50.05459
Block Two:Next 50,000 therms transported@ $0.02550 $0.02 199
Block Three:Amount over 150,000 therms transported@ $0.01 146*$0.007$6
*Inctudes temporary purchased gas cost adjustment of S0.00260 $(0.001 01)
ANNUAL MINIMUM BILL:
The customer shall be subject to the payment of an annual minimum bill of $30,000
during each annual contract period,unless a higher minimum is required under the
service contract to cover special conditions.
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 customets 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.It 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,T4,or T-5 customer electing this schedule may concurrently
utilize Rate Schedule T-3 on the same or contiguous property.
Issued by:Intermountain Gas Corn party
By:Scott Madison Micha&P.McGrath Title:‘lice rrcsidcnt Chicf Accounting Officer
Effective:October 1,2012 October 1,2013 Director,Regulatory Affairs
Exhibit No.1
Case No.INT-G-13-05
Intermountain Gas Company
Page 8 of 11
I.RU.C.Gas Tariff IDAHO PUBLIC UTILITIES COMMISSION
Second Revised Volume No.1 Approved Effective(Supersedes First Revised Volume No.1)t —a ‘oi 0 t 1 2012‘Bxth Revised Seventh Sheet No.13 (Page 1 of 2)£Per O.N.32653
Intermountain Gas Company Jean D.Jewell Secretary
Rate Schedule T4
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:First 250,000 therms transported $0.06242k $005881
Block Two:Next 500,000 therms transported@ $0.02393*$0.02032
Block Three:Amount over 750,000 therms transported W.00020*$000559
*lncludes temporary purchased gas cost adjustment of $080259-$(O.OO1 02)
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 will 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 utilize Rate
Schedule T4 on the customer’s same or configuous property.
BILLING ADJUSTMENTS:
1.In the event that total deliveries to any customer within the last three contract periods met or
exceeded the 200,000 therm threshold,but the customer during the current contract period
used less than the contract minimum of 200,000 therms,an additional amount shall be billed.
The additional amount shall be calculated by billing the deficit usage below 200,000 therms
at the T4 Block I rate.The customer’s future eligibility for the T4 Rate Schedule will be
renegotiated with the Company.
Issued by:Intermountain Gas Company
By:Scott Madison Michael P.McGrathTitle:‘/ice President &Chief Accounting Officer
[_Effective:October 1,2012 October 1,2013 Director,Regulatory Affairs
AVAILABILITY:
Exhibit No.1
Case No.INT-G-13-05
Intermountain Gas Company
Page 9 of 11
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Ecpt.28,2012 Oct.1,2012
Per O.N.32653
Jean 0.JeweIl Secretary
Rate Schedule T-5
FIRM DISTRIBUTION SERVICE WITH MAXIMUM DAILY DEMANDS
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:
0.00606*$000145
o.o47c4*$o.04404
*includes temporary purchased gas cost adjustment of $0.00250 $(0.001 01)
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:
I 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 will be stated in and will
be in effect throughout the term of the service contract
3.The monthly Demand Charge will be equal to the MDFQ times the Firm Daily Demand rate.Firm
demand relief will be afforded to those T-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 billing month,
whichever is less,will be billed at the applicable commodity charge for firm therms.
b Intermountain Gas Company
By:Ccott Madison Michael P.McGrath TiDe:Vice P esidant &Chief AccounUng Officer
Effective:Octobcr 1,2012 October 1 2013 Director,Regulatory Affairs
I.P.U.C.Gas Tariff
Second Revised Volume No.I
(Supersedes First Revised Volume No.1)
fiftfr Revised Sixth Sheet No.14 (Page 1 of 2)
Jty Intermountain Gas Company
I.P.U.C.Gas Tariff
fcsrth Revised Fifth Sheet No.16 (Page 1 of 2)
ty Intermountain Gas Company
Exhibit No.1
Case No.INT-G-13-05
Intermountain Gas Company
Page lOofil
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Cept.28,2012 Oct.1,2012
Per O.N.32653 V
Jean D.Jeweil Secretary
Rate Schedule IS-R
RESIDENTIAL INTERRUPTIBLE SNOWMELT SERVICE
APPLICABILITY:
Applicable to any new residential or Customer using natural gas to melt snow andlor Ice on
sidewalks,driveways or any other similar appurtenances.My and all such applications meeting the
above criteria will be subject to servIce under Rate Schedule IS-R and will 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 facility and equipment costs,prior to the Installation of the
meter set Any request to alter the physical location of the meter set and related facilities 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 billing oeriods ending Anril throush November
Customer Charge -$2.50 per bill
Commodity Charge -$0.66875 per thenn*$069762
For billing oeriods endino December throuah March
V
Customer Charge -$6.50 per bill
Commodity Charge -*0.66875 pertherm*$069762
*Includes:
Temporary purchased gas cost adjustment &$(0.02332)$(0.03126)Weighted average cost of gas of 0.3340 $037341
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 Prevision.
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
Issued b Intermountain Gas Company
By:Ccott Madi,cn Michael P.McGrath Title:\ioc Propidont S ChiotAooounting Offloor
Effective:&k’br 1,2012 October 1 2013 Director,Regulatory Affairs
Exhibit No.1
Case No.INT-G-13-05
Intermountain Gas Company
Page 11 of 11
I.P.U.C.Gas Tariff
fourth Revised Fifth Sheet No.17 (Page 1 of 2)
Intermountain Gas Company
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Sept.20,2012 Oct.1,2012
Per O.N.32653
Jean D.lewell Secretary
Rate Schedule IS-C
SMALL COMMERICAL INTERRUPTIBLE SNOWMELT SERVICE
APPLICABILITY:
Applicable to any new Customer otherwise eligible to receive gas seIiIce under Rate Schedule
GS-1 and using natural gas to melt snow andlor Ice on sidewalks,driveways or any other similar
appurtenances.Any and all such applications meeting the above criteria will be subject to service
under Rate Schedule IS-C and will be separately and individually metered.All service hereunder Is
interruptible at the sole discretion of the Company.
FACILITY REIMBURSEMENT CHARGE:
All new Interruptible Snowmeft service customers are requited to pay for the cost of the
Snowmelt meter set and other related facility and equipment costs,prior to the installation of the
meter set.My request to alter the physical location of the meter set and related facilities 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 billing periods ending Aodl throuah November
Customer Charge —$2.00 per bill
Commodity Charge —First 200 therms per bill @ $0.cC92C*$0.71 872
Next 1,800 thenns per bill t $0.6480C*$069752
Over 2,000 themis per bill t $0.62760*$067706
For billing periods endlna December throuoh March
Customer Charge —$9.50 per bill
Commodity Charge —First 200 therms per bill 0.C62C $0.77 872
Next 1,800 the mis per bill @ 0.C4000*$0.69752
Over 2,000 themis per bill t t0.627G0 $067706
*lncludes:
Temporary purchased gas cost adjustment of 40.O2DCI)sf002360)
Weighted average cost of gas of $0.33489 $0.37341
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
B Ccott Madi&1n Michael P.McGrath Title:Vice rresident &Chief Accou tng OfficerEffective:Octob 1,2072 October 1,2013 Director,Regulatory Affairs
EXHIBIT NO.2
CASE NO.INT-G-13-05
INTERMOUNTAIN GAS COMPANY
PROPOSED TARIFFS
(10 pages)
Rate Schedule RS-1
RESIDENTIAL SERVICE
Exhibit No.2
Case No.INT-G-13-05
Intermountain Gas Company
Page 1 oflO
AVAILABILITY:
Available to individually metered consumers not otherwise specifically provided for,using
natural gas for residential purposes.
RATE:
Monthly minimum charge is the customer charge.
For billing periods ending April through November
Customer Charge -$2.50 per bill
Commodity Charge -$0.87312 per therm*
For billing periods ending December through March
Customer Charge -$6.50 per bill
Commodity Charge -$0.76056 per therm*
*Includes:
Temporary purchased gas cost adjustment of $(0.04197)
Weighted average cost of gas of $0.37341
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the
Company’s Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the
Company’s Tariff,of which this rate schedule is a part.
Issued by:Intermountain Gas Company
By:Michael P.McGrath Title:Director —Regulatory Affairs
Effective:October 1,2013
I.P.U.C.Gas Tariff
Second Revised Volume No.1
(Supersedes First Revised Volume No.1)
Forty-Sixth Revised Sheet No.01 (Page 1 of 1)
Intermountaln Gas Company
Rate Schedule RS-2
MULTIPLE USE RESIDENTIAL SERVICE
Exhibit No.2
Case No.INT-G-13-05
Intermountain Gas Company
Page 2 of 10
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 billing periods ending April through November
Customer Charge -$2.50 per bill
Commodity Charge -$0.731 25 per therm*
For billing periods ending December through March
Customer Charge -$6.50 per bill
Commodity Charge -$0.69762 per therm*
*Includes:
Temporary purchased gas cost adjustment of $(0.03126)
Weighted average cost of gas of $0.37341
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.
1
l.P.U.C.Gas Tariff
Second Revised Volume No.1
(Supersedes First Revised Volume No.1)
Forty-Sixth Revised Sheet No.02 (Page 1 of 1)
Tity Intermountain Gas Company
Issued by:Intermountain Gas Company
By:Michael P.McGrath Title:Director —Regulatory Affairs
Effective:October 1,2013
_____
Rate Schedule GS-1
GENERAL SERVICE
Exhibit No.2
Case No.INT-G-13-05
Intermountain Gas Company
Page 3 of 10
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 distribution system.Requirements in
excess of 2,000 therms per day may be served under this rate schedule upon execution of a one-
year written service contract.
RATE:
Monthly minimum charge is the customer charge.
For billing periods ending April through November
Customer Charge -$2.00 per bill
Commodity Charge -First 200 therms per bill @ $0.76957*
Next 1,800 therms per bill @ $0.74784*
Over 2,000 therms per bill @ $0.72682*
For billing periods ending December through March
Customer Charge -$9.50 per bill
Commodity Charge -First 200 therms per bill @ $0.71 872*
Next 1,800 therms per bill $0.69752*
Over 2,000 therms per bill $0.67706*
*Includes:
Temporary purchased gas cost adjustment of $(0.02360)
Weighted average cost of gas of $0.37341
Issued by:Intermountain Gas Company
By:Michael P.McGrath Title:Director —Regulatory Affairs
Effecbve:October 1,2013
l.P.U.C.Gas Tariff
Second Revised Volume No.1
(Supersedes First Revised Volume No.1)
Forty-Eighth Revised Sheet No.03 (Page 1 of 2)
Intermountain Gas Company
Exhibit No.2
Case No.INT-G-13-05
Intermountain Gas Company
Page 4 of 10
Rate Schedule GS-1
GENERAL SERVICE (Continued)
For separately metered deliveries of gas utilized solely as Compressed Natural Gas Fuel in
vehicular internal combustion engines.
Customer Charge -$9.50 per bill
Commodity Charge -$0.67706 per therm*
*lncludes:
Temporary purchased gas cost adjustment of $(O.02360)
Weighted average cost of gas of $0.37341
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the
Company’s Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
1.Any GS-1 customer who leaves the GS-1 service will pay to Intermountain Gas Company,
upon exiting the GS-J service,all gas and transportation related costs incurred to serve
the customer during the GS-1 service period not borne by the customer during the time
the customer was using GS-1 service.Any GS-f customer who leaves the GS-1 service
will have refunded to them,upon exiting the GS-f service,any excess gas commodity or
transportation payments made by the customer during the time they were a GS-1
customer.
2.All natural gas service hereunder is subject to the General Service Provisions of the
Company’s Tariff,of which this rate schedule is a part.
I.P.U.C.Gas Tariff
Second Revised Volume No.I
(Supersedes First Revised Volume No.1)
Forty-Eighth Revised Sheet No.03 (Page 2 of 2)
Intermountaln Gas Company
Issued by:Intermountain Gas Company
By:Michael P.McGrath Title:Director —Regulatory Affairs
Effective:October 1 2013
Exhibit No.2
Case No.INT-G-13-05
Intermountain Gas Company
Page 5 of 10
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 customer
whose usage does not exceed 500,000 therms annually,upon execution of a one-year minimum written
service contract for firm sales service in excess of 200,000 therms per year.
MONTHLY RATE:
Commodity Charge:
First 250,000 therms per bill @ $0.52258*
Next 500,000 therms per bill @ $0.48409*
Amount Over 750,000 therms per bill @ $0.38850**
The above prices include weighted average cost of gas of $0.37341
*Includes temporary purchased gas cost adjustment of $(0.02708)
**Includes temporary purchased gas cost adjustment of $0.00848
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.Any LV-1 customer who exits the LV-1 service at any time (including,but not limited to,the
expiration of the contract term)will pay to Intermountain Gas Company,upon exiting the LV-1 service,
all gas andlor interstate transportation related costs to serve the customer during the LV-1 contract
period not borne by the customer during the LV-1 contract period.Any LV-1 customer will have
refunded to them,upon exiting the LV-1 service,any excess gas andlor interstate transportation related
payments made by the customer during the LV-1 contract period.
3.In the event that total deliveries to any customer within the last three contract periods met
or exceeded the 200,000 therm threshold,but the customer during the current contract period used
less than the contract minimum of 200,000 therms,an additional amount shall be billed.The additional
amount shall be calculated by billing the deficit usage below 200,000 therms at the LV-1 Block I rate
adjusted for the removal of variable gas costs.The customer’s future eligibility for the LV-I Rate
Schedule will be renegotiated with the Company.
Issued by:Intermountain Gas Company
By:Michael P.McGrath Title:Director —Regulatory Affairs
Effective:October 1,2013
l.P.U.C.Gas Tariff
Second Revised Volume No.I
(Supersedes First Revised Volume No.1)
Fifty-Sixth Revised Sheet No.04 (Page 1 of 2)
Intermountaln Gas Company
Exhibit No.2
Case No.INT-G-13-05
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:First 100,000 therms transported $0.05459
Block Two:Next 50,000 therms transported @ $0.02199*
Block Three:Amount over 150,000 therms transported @ $0.007$6*
*Includes temporary purchased gas cost adjustment of $(0.00f 01)
ANNUAL MINIMUM BILL:
The customer shall be subject to the payment of an annual minimum bill of $30,000
during each annual contract period,unless a higher minimum is required under the
service contract to cover special conditions.
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
utilize Rate Schedule T-3 on the same or contiguous property.
I.P.U.C.Gas Tariff
Second Revised Volume No.I
(Supersedes First Revised Volume No.1)
Eighth Revised Sheet No.11 (Page 1 of 2)
Intermountain Gas Company
Issued by:Intermountain Gas Company
By:Michael P.McGrath Title:Director —Regulatory Affairs
Effective:October 1,2013
Exhibit No.2
Case No,INT-G-13-05
Intermountain Gas Company
Page 7 of 10
Rate Schedule 1-4
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:First 250,000 therms transported @ $0.05881*
Block Two:Next 500,000 therms transported @ $0.02032*
Block Three:Amount over 750,000 therms transported @ $0.00559*
*Includes temporary purchased gas cost adjustment of $(0.00102)
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 will 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 utilize Rate
Schedule T-4 on the customer’s same or contiguous property.
BILLING ADJUSTMENTS:
1.In the event that total deliveries to any customer within the last three contract periods met or
exceeded the 200,000 therm threshold,but the customer during the current contract period
used less than the contract minimum of 200,000 therms,an additional amount shall be billed.
The additional amount shall be calculated by billing the deficit usage below 200,000 therms
at the T-4 Block I rate.The customer’s future eligibility for the T4 Rate Schedule will be
renegotiated with the Company.
Issued by:Intermountain Gas Company
By:Michael P.McGrath Title:Director —Regulatory Affairs
Effective:October 1,2013
I.P.U.C.Gas Tariff
Second Revised Volume No.1
(Supersedes First Revised Volume No.1)
Seventh Revised Sheet No.13 (Page 1 of 2)
Intermountain Gas Company
Exhibit No.2
Case No.INT-G-13-05
Intermountain Gas Company
Page 8 of 10
Rate Schedule 1-5
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 Rate Per Therm
Demand Charge:
Firm Daily Demand -$0.84253
Commodity Charge:
For Firm Therms Transported $0.00145*
Over-Run Service
Commodity Charge:
For Therms Transported In Excess Of MDFQ:$0.04404*
*lncludes temporary purchased gas cost adjustment of $(0.00101)
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:
I 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 will be stated in and will
be in effect throughout the term of the service contract.
3.The monthly Demand Charge will be equal to the MDFQ times the Firm Daily Demand rate.Firm
demand relief will be afforded to those T-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 billing month,
whichever is less,will be billed at the applicable commodity charge for firm therms.
Issued by:Intermountain Gas Company
By:Michael P.McGrath Title:Director —Regulatory Affairs
Effective:October 1,2013
l.P.U.C.Gas Tariff
Second Revised Volume No.1
(Supersedes First Revised Volume No.1)
Sixth Revised Sheet No.14 (Page 1 of 2)
ity Intermountaln Gas Company
I.P.U.C.Gas Tariff
Fifth Revised Sheet No.16 (Page 1 of 2)
NameofUtility Intermountain Gas Company
Exhibit No.2
Case No.INT-G-13-05
Intermountain Gas Company
Page 9 of 10
APPLICABILITY:
Rate Schedule IS-R
RESIDENTIAL INTERRUPTIBLE SNOWMELT SERVICE
Applicable to any new residential or Customer using natural gas to melt snow andlor ice on
sidewalks,driveways or any other similar appurtenances.Any and all such applications meeting
the above criteria will be subject to service under Rate Schedule lS-R and will 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 facility and equipment costs,prior to the installation of the
meter set.Any request to alter the physical location of the meter set and related facilities 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 billing periods ending April through November
Customer Charge -$2.50 per bill
Commodity Charge -$0.69762 per therm*
For billing periods ending December through March
Customer Charge -$6.50 per bill
Commodity Charge -$0.69762 per therm*
*lncludes:
Temporary purchased gas cost adjustment of $(0.03126)
Weighted average cost of gas of $0.37341
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.
Issued by:Intermountaln Gas Company
By:Michael P.McGrath Title:Director —Regulatory Affairs
Effective:October 1,2013
I I.P.U.C.Gas Tariff I
I Fifth Revised Sheet No.17 (Page 1 of 2)I
I NameofUtility Intermountain Gas Company
Exhibit No.2
Case No.NT-C-i 3-05
Intermountain Gas Company
Page 10 of 10
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 andlor ice on sidewalks,driveways or any other
similar appurtenances.Any and all such applications meeting the above criteria will be subject to
service under Rate Schedule IS-C and will 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 facility and equipment costs,prior to the installation of the
meter set.Any request to alter the physical location of the meter set and related facilities 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 billing periods ending April through November
Customer Charge —$2.00 per bill
Commodity Charge —First 200 therms per bill $0.71 872*
Next 1,800 therms per bill @ $0.69752*
Over 2,000 therms per bill @ $0.67706*
For billing periods ending December through March
Customer Charge —$9.50 per bill
Commodity Charge —First 200 therms per bill @ $0.71 872*
Next 1,800 therms per bill @ $0.69752*
Over 2,000 therms per bill $0.67706*
*Includes:
Temporary purchased gas cost adjustment of $(0.02360)
Weighted average cost of gas of $0.37341
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:Michael P.McGrath Title:Director —Regulatory Affairs
Effective:October 1,2013
EXHIBIT NO.3
CASE NO.INT-G-13-05
INTERMOUNTA1N GAS COMPANY
PERTINENT EXCERPTS FROM INTERSTATE PIPELINES AND RELATED
FACILITIES
(13 pages)
Exhibit No.3
Case No.INT-G-13-05
Intermountain Gas Company
Page 1 ofl3
Northwest Pipeline GP
FERC Gas Tariff
Fifth Revised Volume No.I
FERC GAS TARIFF
FIFTH REVISED VOLUME NO.1
(Superseding Fourth Revised Volume No.1)
Of
NORTHWEST PIPELINE GP
Filed with
FEDERAL ENERGY REGULATORY COMMISSION
Communications concerning this Tariff should be sent to:
David J.Madsen,Director,Rates &Tariffs
Northwest Pipeline GP
295 Chipeta Way
Salt Lake City,Utah 84108
P.O.Box 58900
Salt Lake City,Utah 84158
Telephone:[phone]
Facsimile:[phone]
Exhibit No.3
Case No.INT-G-13-05
Intermountain Gas Company
Page 2 of 13
Northwest Pipeline GP
FERC Gas Tariff Fourth Revised Sheet No.5
Fifth Revised Volume No.I Superseding
Third Revised Sheet No.5
STATEMENT OF RATES
Effective Rates Applicable to
Rate Schedules TF-l,TF-2,TI-i,TFL-l and TIL-l
(Dollars per Dth)
Currently
Effective
Tariff Rate(3)
Minimum Maximum
Rate Schedule TF-l (4)(5)
Reservation
(Large Customer)
System-Wide
15 Year Evergreen Exp.
25 Year Evergreen Exp.
(Small Customer)(6)
Scheduled Overrun
Rate Schedule TF-2 (4)(5)
Reservation
Volumetric
Scheduled Daily Overrun
.nnual Overrun
Rate Schedule TI-i
Volumetric (7)
Rate Schedule TFL-l (4)(5)
Reservation
Volumetric
Scheduled Overrun
Rate Schedule and
Type of Rate
Base
Tariff Rate
Minimum Maximum ACA(2)
Volumetric
(Large Customer)
System-Wide
15 Year Evergreen Exp.
25 Year Evergreen Exp.
-.00000
-.00000
—.00000
.00000
.00 000
.00000
.00813
.00813
.00813
.41000
.3 6263
.342 34
.03000
.00813
.00813
.41000
36263
.34234
.03180
.00993
.00993
.00180
.00180
.00180
.00993
.00993
.00993
.00813 .72155 .00180 .00993 .72335
.00813 .44000 .00180 .00993 .44180
.00000 .41000 —.00000 .41000
.00813 .03000 -.00813 .03000
.00813 .44000 -.00813 .44000
.00813 .44000 -.00813 .44000
.00813 .44000 .00180 .00993 .44180
Rate Schedule TIL-l
Volumetric
Exhibit No.3
Case No.INT-G-13-05
Intermountain Gas Company
Page 3 of 13
Northwest Pipeline GP
FERC Gas Tariff Fourth Revised Sheet No.7
Fifth Revised Volume No.1 Superseding
Third Revised Sheet No.7
STATEMENT OF RATES (Continued)
Effective Rates Applicable to Rate Schedules SGS-2F and SGS-21
(Dollars per 0th)
Currently Effective
Rate Schedule and Tariff Rate Cl)
Type of Rate Minimum Maximum
Rate Schedule SGS-2F (2)(3)(4)(5)
Demand Charge
Pre-Expansion Shipper 0.00000 0.01552
Expansion Shipper 0.00000 0.04056
Capacity Demand Charge
Pre-Expansion Shipper 0.00000 0.00057
Expansion Shipper 0.00000 0.00348
Volumetric Did Rates
Withdrawal Charge
Pre-Expansion Shipper 0.00000 0.01562
Expansion Shipper 0.00000 0.04056
Storage Charge
Pre-Expansion Shipper 0.00000 0.00057
Expansion Shipper 0.00000 0.00348
Rate Schedule SGS-21
Volumetric 0.00000 0.00224
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-13-05
Intermountain Gas Company
Page 4 of 13
Northwest Pipeline GP
FERC Gas Tariff Third Revised Sheet No.8-A
Fifth Revised Volume No.1 Superseding
Second Revised Sheet No.8-A
STATEMENT OF RATES (Continued)
Effective Rates Applicable to Rate Schedules LS-2F and LS-21
(Dollars per Dth)
Currently Effective
Rate Schedule and Tariff Rate (1)
Type of Rate Minimum Maximum
Rate Schedule LS-2F (3)
Demand Charge (2)0.00000 0.02587
Capacity Demand Charge (2)0.00000 0.00331
Volumetric Bid Rates
Vaporization Demand-Related Charge (2)0.00000 0.02587
Storage Capacity Charge (2)0.00000 0.00331
Liquefaction 0.90855 0.90855
Vaporization 0.03386 0.03386
Rate Schedule LS-21
Volumetric 0.00000 0.00662
Liquefaction 0.90855 0.90855
Vaporization 0.03386 0.03386
Footnotes
(1)Shippers receiving service under these rate schedules are required to
furnish fuel reimbursement in-kind at the rates specified on Sheet No.
14.
(2)Rates are daily rates computed on the basis of 365 days per year,
except that rates for leap years are computed on the basis of 366 days.
Exhibit No.3
Case No.INT-G-13-05
Intermountain Gas Company
Page 5 of 13
Northwest Pipeline GP
FERC Gas Tariff Seventh Revised Sheet No.14
Fifth Revised Volume No.1 Superseding
Sixth 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.6,6,7,8 and 8-A 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
Conditions contained herein.
The fuel use reimbursement furnished by Shippers shall be as follows
for the applicable Rate Schedules included in this Tariff:
Rate Schedules TF-l,TF-2,TI-l,and DEX-l 1.61%
Rate Schedule TF-l -Evergreen Expansion
Incremental Surcharge (1)0.50%
Rate Schedule TFL-1 -
Rate Schedule TIL-l -
Rate Schedules SGS-2F and SGS-2I 0.57%
Rate Schedules LS-l,LS-2F,and LS-2I
liquefaction 2.28%
vaporization 1.48%
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,
Jackson Prairie injection,Plymouth liquefaction,Plymouth vaporization,or
for deferred exchange,as applicable.
Footnote
(1)In addition to the Rate Schedule TF-l 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.
Exhibit No.3
Case No.INT-G-13-05
Intermountain Gas Company
Page 6 of 13
NOVA Gas Transmission Ltd.
GAS TRANSPORTATION TARIFF
OF
NOVA GAS TRANSMISSION LTD.
Effective Date:November 1,2010
Exhibit No.3
Case No.INT-G-13-05
Intermountain Gas Company
Page 7 of 13
NOVA Gas Transmission Ltd.Auachment2
Table of Rates,Tolls and Charges
Page I of5
FT-D Demand RateGroupi IT-DRat.
Delivery Point Group 1 Delivery Point Name Pdce Point par Day
Number ($IGJ)(SIGJ)
2000 ALBERTA-B.C.BORDER 5.38 0.1945
31111 ALLIANCE CLAIRMONT INTERCONNECT APN 3.12 0.1128
31110 ALLIANCE EDSON INTERCONNECTAPN 3.12 0.1128
31112 ALLIANCE SHELL CREEK INTERCONNECTAPGC 3.12 0.1128
3002 BOUNDARY LAKE BORDER 3.33 0.1204
1958 EMPRESS BORDER 5.29 0.1912
3886 GORDONDALE BORDER 3.33 0.1204
6404 MCNEILL BORDER 5.29 0.1912
Group 2 FT-D Dernend Rate IT-D Rate Subject to ATCO
DeliveryPoint Group 2 Delivery PaintName Point “r’per Day Pipelines
Number t$IGJ)I$!G])Franchise Fees’
31000 A.T.PLASTICS SALES APN 3.39 0.1226 Yes
31001 ADM AGRI INDUSTRIES SALES APN 3.39 0.1226 Yes
3880 AECO INTERCONNECTION 3.12 0.1128
31003 AGRIUM CARSELAND SALES APS 3.12 0.1128
31002 AGRIUM FT.SASK SALES APN 3.12 0.1128 Yes
31004 AGRIUM REDWATER SALES APN 3.12 0.1128
31005 AINSWORTH SALES APGP 3.39 0.1226
31006 AIR LIQUIDE SALES APN 3.39 0,1226
3214 AKUINURIVERWESTSALES 3.12 0.1128
31007 ALBERTA ENVIROFUELS SALES APN 3.39 0.1226 Yes2
31008 ALBERTA HOSPITAL SALES APN 3.39 0.1226 Yes
3668 ALBERTA-MONTANA BORDER 3.33 0.1204
3059 ALLISON CREEK SALES 3.12 0.1128
31009 ALTASTEEL SALES APN 3,39 0.1226 Yes2
3562 AMOCO SALES (BP SALES TAP)3.12 0.1128
31012 APL JASPER SALES APN 3.39 0.1226 Yes
3488 ARDLEY SALES 3.12 0.1128
3216 AURORANO2SALES 3.12 0.1128
3135 AURORASALES 3.12 0.1128
3423 BASHAW WEST SALES 3.12 0.1128
31013 BAYMAG SALES APS 3.12 0.1128
31014 BEAR CREEK COGEN SALES APGP 3.39 0.1226
3068 BEAVER HILLS SALES 3.12 0.1128
3933 BIG EDDY INTERCONNECTION 3.12 0.1128
3067 BIGSTONE SALES 3.12 0.1128
3468 BLEAK LAKE SALES 3.12 0.1128
3225 BOTHASALES 3.12 0.1128
3164 BRAINARDLAKESALES 3.12 0.1128
3918 BUFFALO CREEK INTERCONNECTION 3.12 0.1128
31015 BURDETTCOGEN SALES APS 3.12 0.1128
3204 CABIN SALES 3.12 0.1128
3109 CALDWELL SALES 3.12 0.1128
31016 CALGARY ENERGY CENTRE SALES APS 3.12 0.1128 Yes
3634 CANOE LAKE SALES 3.12 0.1128
3165 CANOE LAKE SALES NO 2 3.12 0.1128
3866 CARBON INTERCONNECTION 3.12 0.1128
3484 CARIBOU LAKE SALES 3.12 0.1128
3157 CARIBOULAKESOUTHSALES 3.12 0.1128
3106 CARMON CREEK SALES 3.12 0.1128
3101 CAROLINE SALES 3.12 0.1126
31017 CARSELAND COGEN SALES APS 3.12 0.1128
3495 CAVALIER SALES 3.12 0.1128
31018 CHPINLAKESCOOPSALESAPS 3.12 0.1128
3907 CHANCELLOR INTERCONNECTION 3.12 0.1128
3151 CHEECHAM WEST NO 2 SALES 3.12 0.1128
3622 CHEECHAM WEST SALES 3.12 0.1128
6014 CHEVRON AURORA SALES 3.12 0.1128
31019 CHEVRON FT.SASK SALES APN 3.39 0.1226 Yes
3097 CHICKADEE CREEK SALES 3.12 0.1128
3305 CHIGWELL NORTH SALES 3.12 0,1128
3496 CHIPEWYAN RIVER SALES 3.12 0.1128
TARIFF Effective:January 1,2013 (Amended April 28,2013)
Exhibit No.3
Case No.INT-G-13-05
Intermountain Gas Company
Page 8 of 13
Gas Transmission Northwest CLC
FERC Gas Tariff
Fourth Revised Volume No.1-A
FERC GAS TARIFF
FOURTH REVISED VOLUME NO.1-A
OF
GAS TRANSMISSION NORTHWEST LLC
FILED WITH THE
FEDERAL ENERGY REGULATORY COMMISSION
Communications Concerning This Tariff
Should Be Addressed To:
Joan Collins
Manager,Tariffs and Compliance
Gas Transmission Northwest LLC
Mailing Address:P.O.Box 2446
Houston,TX 77252-2446
Courier Address:717 Texas Street,Suite 2400
Houston,TX 77002-2761
Phone:[phone]
fax:($32)320-6651
Exhibit No.3
Case No.INT-G-13-05
Intermountain Gas Company
Page 9 of 13
Gas Transmission Northwest LLC PART 4.1
FERC Gas Tariff 4.1 -Statement ofRates
Fourth Revised Volume No.1-A fTS-1 and LFS-1 Rates
v.9.0.0 Superseding v.8.0.0
STATEMENT OF EFFECTIVE RATES AND CHARGES FOR
TRANSPORTATION OF NATURAL GAS
Rate Schedules fTS-I and LFS-1
RESERVATION
DAILY DAILY
MILEAGE (a)NON-MILEAGE (b)DELIVERY (c)FUEL (d)
(0th-MILE)(0th)(Dth-MILE)(0th-MILE)
Max.Mm.Max.Mm.Max.Mm.Max.Mm.
BASE 0.000498 0.000000 0.039216 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 CHARGES
MEDFORD
E-1 (f)0.003290 0.000000 0.005498 0.000000 0.000026 0.000026
E-2 (g)(l)0.009884 0.000000 ------0.000000 0.000000
(WWP)
E-2 (h)(l)0.002972 0.000000 —---0.000000 0.000000
(Diamond 1)
E-2 (h)(I)0.001166 0.000000 ------0.000000 0.000000
(Diamond 2)
COYOTE SPRINGS
E-3 (1)0.001412 0.000000 0.001420 0.000000 0.000000 0.000000
OVERRUN CHARGE (j)
SURCHARGES
ACA(k)------—-—0.001800 0.001800
Issued:November 30,2012 Docket No.RPI3-331-000
Effective:January 7,2013 Accepted:December 17,2012
Exhibit No.3
Case No.NT-C-i 3-05
Intermountain Gas Company
Page 10 of 13
Foothills Pipe Lines Ltd.Page 1
PHASE I
GAS TRANSPORTATION TARIFF
OF
FOOTHILLS PIPE LINES LTD.
This Gas Transportation Tariff is subject to the National Energy Board Act,is available for
inspection during normal business hours and is also available electronically at
www.transcanada.com.Communications concerning this Gas Transportation Tariff should be
addressed to:
foothills Pipe Lines Ltd.
450 First Street S.W.
Calgary,Alberta
T2P5HI
Attention:Greg Szuch
TARIFF —PHASE I Effective Date:April 1,2007
Exhibit No.3
Case No.INT-G-13-05
Intermountain Gas Company
Page 11 ofl3
Foothills Pipe Lines Ltd.Page 1
TABLE OF EFFECTIVE RATES
1.Rate Schedule FT,Firm Transportation Service
Demand Rate
(S/GJfKmIMonth)
Zone 6 0.0072162549
Zone 7 0.00685027 12
Zone 8*0.0 135260538
Zone 9 0.004755367 1
2.Rate Schedule OT,Overrun Transportation Service
Commodity Rate
($/GJ/Km)
Zone 6 0.0002602584
Zone 7 0.0002470590
3.Rate Schedule IT,Interruptible Transportation Service
Commodity Rate
($/GJ1Km)
Zone $*0.0004878249
Zone 9 0.0001715050
*For Zone 8,Shippers Haul Distance shall be 170.7 kim
TARIFF —PHASE I Effective Date:January 1,2013
Exhibit No.3
Case No.INT-G-13-05
Intermountain Gas Company
Page 12 of 13
FERC GAS TARIFF
SECOND REVISED VOLUME NO.1
of
QUESTAR PIPELINE COMPANY
filed with the
FEDERAL ENERGY REGULATORY COMMISSION
Communications regarding this Tariff should be addressed to:
L.Bradley Burton,
General Manager Federal Regulatory Affairs and Chief Compliance Officer
Questar Pipeline Company
333 South State Street (84111)
P.0.Box 45360
Salt Lake City,UT 84145-0360
Telephone:[phone]
FAX:[phone]
Exhibit No.3
Case No.INT-G-13-05
Intermountain Gas Company
Page 13 of 13
Questar Pipeline Company
FERC Gas Tariff Statement of Rates
Second Revised Volume No.1 Section Version:5.0.0
STATEMENT OF RATES
Base Annual currently
Rate Schedule/Tariff Charge Effective
Type of Charge Rate (S Adjustment 1/($)Rate C$i(a)(b)Cc)(U)
TRANSPORTATION
FIRM TRANSPORTATION -T-1
Systemwide Monthly Reservation Charge
Maximum /5.28804 -5.28804/Dth
Minimum 0.00000 -0.00000/0thSSXPMonthiyReservationCharge/
Maximum /7.82712 -7.82712/0thMinImum0.00000 -0.00000/0th
Usage Charge
Maximum 0.00267 0.00180 0.00447/0th
Minimum 0.00267 0.00180 0.00447/0th
Systemwlde Authorized Overrun Charge
Maximum 0.17652 0.00180 0.17832/0th
MinImum 0.00267 0.00180 0.00447/0th
Systemwide Unauthorized Overrun Charge
Critical 10.00000 -10.00000/0th
Non-Critical 0.35304 -0.35304/DthSSXPAuthorizedOverrunCharge
Maximum 0.26000 0.00 180 0.26 180/Dth
Minimum 0.00267 0.00180 0.00447/0th
SSXP Unauthorized Overrun Charge
Criticai 10.00000 -10.00000/Dth
Non-Critical 0.52000 -0.52000/Dth
PARKING AND LOANING SERVICE -PAL2
Initiation Charge
Maximum 0.20846 0.20846/0th
Minimum 0.03276 0,03276/DthDailyInventoryCharge
Maximum 0.17570 0.17570/0th
Minimum 0.00000 0.00000/Dth
NO-NOTICE TRANSPORTATION -NNT
Monthiy Reservation Charge
Maximum /0.86753 -0.86753/DthMinimum0.00000 -0.00000/0thINTERRUPTIBLETRANSPORTATION-T-2
Systemwide Usage Charge
Maximum 0.17652 0.00180 0.17832/Dth
Minimum 0.00267 0.00180 0.00447/0thSystemwideUnauthorizedOverrunCharge
Critical 10.00000 -10.00000/0th
Non-Critical 0.35304 -0.35304/DthSSXPUsageCharge/
MaxImum 0.26000 0.00180 0.26180/0th
Minimum 0.00267 0.00180 0.00447/0thSSXPUnauthorizedOverrunCharge
Critical 10.00000 -10.00000/0thNon-Critical 0,52000 -0.52000/0th
FUEL REIMBURSEMENT -l.72%in-kind for Rate Schedules T-1 and T-2.
OPTIONAL VOLUMETRIC RELEASES .IFIRMTRANSPORTATION-T-1
Systemwlde Volumetric Charge
Maximum /0.17385 -0.17385/0thMinimum0.00000 -0.00000/0thSSXPVolumetricCharge
Maximum /0.25733 -0.25733/0thMinimum0.00000 -0.00000/DthPipeilneUsageChargesApplicabletoVolumetricReleases4]Maximum 0.00267 0.00180 0.00447/0thMinimum0.00267 0.00180 0.00447/0th
Filed On:November 30,2012 EffectIve On:January 1,2013
EXHIBIT NOS.4-11
CASE NO.INT-G-13-05
INTERMOUNTA1N GAS COMPANY
(8 pages)
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3
0
6
1,2
6
1
,
8
5
2
2)
15
0
,
6
7
4
69
0
,
4
5
4
41
1
,
3
2
6
9,
3
9
8
14
Ca
p
a
c
i
t
y
10
,
9
6
2
,
3
5
0
0.0
0
0
3
9
1,5
6
0
,
4
9
1
re
18
6
,
3
3
4
85
3
,
8
6
1
50
8
,
6
7
3
11
,
6
2
3
15
li
q
u
e
f
a
c
t
i
o
n
10
,
9
6
2
,
3
5
0
0.0
6
4
1
1
70
2
,
7
9
6
83
,
9
1
9
38
4
,
5
5
3
22
9
,
0
9
0
5,
2
3
4
16
Va
p
o
r
i
z
a
t
i
o
n
10
,
9
6
2
,
3
5
0
0.
0
4
1
8
4
45
8
,
6
6
5
54
,
7
6
8
25
0
,
9
7
0
14
9
,
5
1
1
3,
4
1
6
17
TF
-
2
Re
s
e
r
v
a
t
i
o
n
10
,
9
6
2
,
3
5
0
0.0
4
0
2
1
44
0
,
8
4
4
52
,
6
4
0
24
1
,
2
1
9
14
3
,
7
0
2
3,
2
8
3
18
TF
-
2
Re
d
e
l
i
v
e
r
y
Ch
a
r
g
e
10
,
9
6
2
,
3
5
0
0.0
0
3
0
0
32
,
8
8
7
3,9
2
7
17
,
9
9
5
10
,
7
2
0
24
5
19
Oth
e
r
St
o
r
a
g
e
Fa
c
i
l
i
t
i
e
s
3,
2
4
1
,
5
6
4
38
7
,
0
6
5
1,
7
7
3
,
7
0
3
1,0
5
6
,
6
5
3
24
,
1
4
3
20
To
t
a
l
Fix
e
d
Ga
s
Co
s
t
Ch
a
r
g
e
s
$
64
,
6
7
9
,
9
1
9
$
7,7
2
3
,
2
3
6
$
35
,
3
9
1
,
2
3
4
$
21
,
0
8
3
,
7
1
3
$
48
1
,
7
3
6
21
No
r
m
a
l
i
z
e
d
Sa
l
e
s
Vo
l
u
m
e
s
(I
N
T
-
G
-
1
3
-
0
5
Es
t
i
m
a
t
e
d
Vo
l
u
m
e
s
)
35
,
5
2
0
,
0
7
5
18
9
,
6
6
5
,
1
6
1
10
7
,
8
3
5
,
3
7
3
4,
4
9
2
,
7
7
2
22
Fi
x
e
d
Co
s
t
Co
l
l
e
c
t
i
o
n
pe
r
Th
e
r
m
(l
i
n
e
20
d
i
v
i
o
e
d
by
lin
e
21
)
$
0.
2
1
7
4
3
$
0.1
8
6
6
0
$
0.
1
9
5
5
2
$
0.1
0
7
2
2
23
Cu
r
r
e
n
t
Fix
e
d
Co
s
t
Co
l
l
e
c
t
i
o
n
pe
r
Th
e
r
m
$
0.
2
3
1
4
7
$
0.1
9
4
8
1
$
0.
1
9
6
3
2
$
0.0
8
3
3
4
24
Ad
j
u
s
t
m
e
n
t
to
Fi
x
e
d
Co
s
t
Co
l
l
e
c
t
i
o
n
(l
i
n
e
22
min
u
s
li
n
e
23
)
$
)0
.
0
1
4
0
4
)
$
(0
.
0
0
8
2
1
)
$
(0
.
0
0
0
8
0
)
$
0.0
2
3
8
8
__
_
_
_
_
_
_
__
_
_
_
_
_
__
_
_
_
_
_
CD
-
25
FI
X
E
D
CO
S
T
CO
L
L
E
C
T
I
O
N
RA
T
E
CA
L
C
U
L
A
T
I
O
N
:
z
26
Ad
j
u
s
t
e
d
Fi
x
e
d
Co
s
t
Co
l
l
e
c
t
i
o
n
Pe
r
T
h
e
r
m
(U
s
e
22
)
$
0.
2
1
7
4
3
$
0.1
8
6
6
0
$
0.1
9
5
5
2
$
0.1
0
7
2
2
27
In
c
r
e
m
e
n
t
a
l
Fi
x
e
d
Co
s
t
Co
l
l
e
c
t
i
o
n
0.
0
0
7
4
7
0.
0
0
6
5
0
0,0
0
6
7
3
0.0
0
4
4
7
1
28
IN
T
-
G
-
1
3
-
0
5
Fix
e
d
Co
s
t
s
Co
l
l
e
c
t
e
d
$
0.
2
2
4
9
0
$
0.1
9
3
1
0
$
0.
2
0
2
2
5
$
0.
1
1
1
6
9
9
U)0
o
Se
e
Wo
r
l
c
p
a
p
e
r
No
.
5,
Li
n
e
8
Pr
i
c
e
Re
f
l
e
c
t
s
Da
i
l
y
Ch
a
r
g
e
;
An
n
u
a
l
Ch
a
r
g
e
(C
o
l
u
m
n
(d
)
)
eq
u
a
l
s
Pr
i
c
e
(C
o
l
u
m
n
(c
)
)
ti
m
e
s
An
n
u
a
l
Th
e
r
m
s
(C
o
l
u
m
n
(b
)
)
ti
m
e
s
36
5
.
Se
e
Ex
h
i
b
i
t
4,
Lin
e
s
1-
1
9
IN
T
E
R
M
O
U
N
T
A
I
N
GA
S
CO
M
P
A
N
Y
Su
m
m
a
r
y
of
Pr
o
p
o
s
e
d
Te
m
p
o
r
a
r
y
Su
r
c
h
a
r
g
e
s
(C
r
e
d
i
t
s
)
Co
s
t
of
Se
r
v
i
c
e
Al
l
o
c
a
t
i
o
n
of
De
f
e
r
r
e
d
Ga
s
Co
s
t
s
Li
n
e
No
.
De
s
c
r
i
p
t
i
o
n
(a
)
1
Ma
n
a
g
e
m
e
n
t
of
Pi
p
e
l
i
n
e
Tr
a
n
s
p
o
r
t
a
t
i
o
n
Ca
p
a
c
i
t
y
2
Pr
o
p
o
s
e
d
Te
m
p
o
r
a
r
y
Su
r
c
h
a
r
g
e
(C
r
e
d
i
t
)
-
Fi
x
e
d
De
f
e
r
r
a
l
(2
)
3
Pr
o
p
o
s
e
d
Te
m
p
o
r
a
r
y
Su
r
c
h
a
r
g
e
(C
r
e
d
i
t
)
-
Va
r
i
a
b
l
e
De
f
e
r
r
a
l
4
LN
G
Sa
l
e
s
Cr
e
d
i
t
s
RS
-
1
(b
)
$
(0
.
0
1
3
3
6
)
(0
.
0
3
7
6
2
)
0.
0
0
9
0
2
(3
)
(0
.
0
0
0
0
1
)
RS
-
2
(c
)
$
(0
.
0
1
1
6
2
)
(0
.
0
2
8
6
5
)
0.
0
0
9
0
2
(0
.
0
0
0
0
1
)
GS
-
1
LV
-
f
(d
)
fe
)
$
(0
.
0
1
2
0
4
)
$
(0
.
0
0
8
0
0
)
(0
.
0
2
0
5
7
)
(0
.
0
2
7
5
6
)
(3
)
0.
0
0
9
0
2
(3
)
(4
)
(0
.
0
0
0
0
1
)
(0
.
0
0
0
0
1
)
5
To
t
a
l
Pr
o
p
o
s
e
d
Te
m
p
o
r
a
r
y
Su
r
c
h
a
r
g
e
s
(C
r
e
d
i
t
s
)
$
(0
.
0
4
1
97
)
$
(0
.
0
3
1
26
)
$
(0
.
0
2
3
6
0
)
$
(0
.
0
2
7
0
8
)
(1
)
Se
e
Ex
h
i
b
i
t
No
.
7,
Li
n
e
5,
Co
l
u
m
n
s
(c
)
-
(f
)
(2
)
Se
e
Ex
h
i
b
i
t
No
.
8,
Li
n
e
10
,
Co
l
u
m
n
s
fc
)
-
(f
)
(3
)
Se
e
Ex
h
i
b
i
t
No
.
9;
Li
n
e
4,
Co
l
u
m
n
(b
)
pl
u
s
Li
n
e
12
,
Co
l
u
m
n
(b
)
(4
)
Se
e
Ex
h
i
b
i
t
No
.
9;
Li
n
e
4,
Co
l
u
m
n
(b
)
pl
u
s
Li
n
e
20
,
Co
l
u
m
n
(b
)
(5
)
Se
e
Ex
h
i
b
i
t
No
.
10
,
Li
n
e
5,
Co
l
u
m
n
s
(c
)
-
(f
)
w(
CD
Cs)
D
CD
C
D
_o
Z
oO
Z
—.
0
-•
)
ZQ
)
G)
O
Cs)Ob
Jo
’
IN
T
E
R
M
O
U
N
T
A
I
N
GA
S
CO
M
P
A
N
Y
Al
l
o
c
a
t
i
o
n
of
An
n
u
a
l
i
z
e
d
Cr
e
d
i
t
s
Re
s
u
l
t
i
n
g
fr
o
m
Ma
n
a
g
e
m
e
n
t
of
Pi
p
e
l
i
n
e
Tr
a
n
s
p
o
r
t
a
t
i
o
n
Ca
p
a
c
i
t
y
Co
s
t
of
Se
r
v
i
c
e
Al
l
o
c
a
t
i
o
n
of
De
f
e
r
r
e
d
Ga
s
Co
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
)
fd
)
fe
)
(f
)
1
Lo
n
g
Te
r
m
No
r
t
h
w
e
s
t
Pi
p
e
l
i
n
e
Ca
p
a
c
i
t
y
Re
l
e
a
s
e
s
$
(3
1
3
6
1
6
5
)
$
(3
7
4
4
8
0
)
$
(1
,
7
1
6
0
3
1
)
$
(1
,
0
2
2
,
2
9
6
)
$
(2
3
,
3
5
8
)
2
Up
s
t
r
e
a
m
Pi
p
e
l
i
n
e
Ca
p
a
c
i
t
y
Re
l
e
a
s
e
s
(7
5
0
,
0
0
0
)
(8
9
,
5
5
5
)
(4
1
0
3
8
1
)
(2
4
4
,
4
7
8
)
(5
,
5
8
6
)
3
To
t
a
l
Ma
n
a
g
e
m
e
n
t
of
Pi
p
e
l
i
n
e
Tr
a
n
s
p
o
r
t
a
t
i
o
n
Ca
p
a
c
i
t
y
$
(3
,
8
8
6
,
1
6
5
)
$
(4
6
4
,
0
3
5
)
$
(2
,
1
2
6
,
4
1
2
)
$
(1
,
2
6
6
,
7
7
4
)
$
(2
8
,
9
4
4
)
4
No
r
m
a
l
i
z
e
d
Sa
l
e
s
Vo
l
u
m
e
s
(1
/
1
/
1
2
-
12
/
3
1
/
1
2
)
34
,
7
3
4
,
8
5
9
18
2
,
9
8
5
,
7
3
9
10
5
,
1
8
1
,
4
2
7
3,
6
1
6
,
8
4
8
5
Pr
o
p
o
s
e
d
Pr
i
c
e
Ad
j
u
s
t
m
e
n
t
Pe
r
Th
e
r
m
$
(0
.
0
1
3
3
6
)
$
(0
.
0
1
1
6
2
)
$
(0
.
0
1
2
0
4
)
$
(0
.
0
0
8
0
0
)
(I
)
Se
e
Wo
r
k
p
a
p
e
r
No
.
5,
Li
n
e
8
rn
L
(D
W
CD
(
D
ö
_•
o
Z”
oc
°
Z
-
0
00
C,,J0
1
IN
T
E
R
M
O
U
N
T
A
I
N
GA
S
CO
M
P
A
N
Y
Pr
o
p
o
s
e
d
Te
m
p
o
r
a
r
y
Su
r
c
h
a
r
g
e
s
(C
r
e
d
i
t
s
)
-
Fi
x
e
d
Co
s
t
s
De
f
e
r
r
e
d
Ac
c
o
u
n
t
18
6
0
Es
t
i
m
a
t
e
d
Co
s
t
of
Se
r
v
i
c
e
Al
l
o
c
a
t
i
o
n
of
De
f
e
r
r
e
d
Ga
s
Co
s
t
s
(2
)
Li
n
e
Se
p
t
.
3
0
,
2
0
1
3
No
.
De
s
c
r
i
p
t
i
o
n
Ba
l
a
n
c
e
RS
-
1
RS
-
2
GS
-
1
LV
-
1
(a
)
(b
)
(c
)
(d
)
(e
)
(f
)
1
Fi
x
e
d
Co
s
t
s
:
2
Fr
o
m
NT
-
G
-
1
2
-
0
1
(A
c
c
o
u
n
t
s
18
6
0
.
2
0
5
0
-
2
0
9
0
)
$
(9
7
,
8
8
8
)
$
(5
,
7
6
2
)
$
53
,
9
7
4
$
(1
6
1
,
5
3
5
)
$
15
,
4
3
5
3
Fi
x
e
d
Co
s
t
Co
l
l
e
c
t
i
o
n
Ad
j
u
s
t
m
e
n
t
(
A
c
c
o
u
n
t
s
18
6
0
.
2
2
0
0
)
2,
3
0
8
,
4
8
3
14
,
1
3
2
67
4
3
0
6
1,
6
5
9
,
5
6
7
(3
9
5
2
2
)
4
Ca
p
a
c
i
t
y
Re
l
e
a
s
e
s
&
Pu
r
c
h
a
s
e
s
(A
c
c
o
u
n
t
18
6
0
.
2
3
2
0
)
(9
,
9
8
5
,
2
4
7
)
(1
,
1
9
2
,
3
0
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Cii
01
Exhibit No.9
Case No.INT-G-13-05
Intermountain Gas Company
Page 1 of 1
INTERMOUNTAIN GAS COMPANY
Proposed Temporary Surcharges (Credits)-Variable Costs
Line
No.Description Amount
(a)(b)
Account 1860 Variable Amounts Which Apply to RS-1,RS-2,GS.1,and LV-1:
2 Account 1860 Variable Costs $3,103,433 (1)
3 Normalized Sales Volumes (1/1/12 -12/31/12)326,518,873
4 Proposed Temporary Surcharge (Credit)-Variable Costs $0.00950
5 Lost and Unaccounted For Gas Amounts Which Apply to RS-1,RS.2,and GS-1:
6 Lost and Unaccounted For Gas Amounts from INT-G-1 2-01 (Account 1860-2120)$1,603,665 (2)
7 Lost and Unaccounted For Gas Amortization (Account 1860-21 30)(1,542,253)(3)
8 (Over)/Under Collection of Lost and Unaccounted For Gas from INT-G-12-01 61,412
9 Lost and Unaccounted For Gas INT-G-13-05 (217,686))4)
10 Total Lost and Unaccounted For Gas Amounts Which Apply to RS-1,RS-2,and GS-1 $(156,274)
11 Normalized Sales Volumes (1/1/12 -12/31/1 2)322,902,025
12 Proposed Temporary Surcharge (Credit)-Lost and Unaccounted For Gas Costs $(0.00048)
13 Lost and Unaccounted For Gas Amounts Which Apply to LV-1,T-3,T-4,and T-5:
14 Lost and Unaccounted For Gas Amounts from INT-G-12-01 (Account 1860-2120)$)
15 Lost and Unaccounted For Gas Amortization (Account 1860-2140)(749,998)(6)
16 (Over)/Under Collection of Lost and Unaccounted For Gas from INT-G-12-01 (215,443)
17 Lost and Unaccounted For Gas INT-G-13-05 (72,599)(7)
18 Total Lost and Unaccounted For Gas Amounts Which Apply to LV-1,T-3,T-4 and T-5 $(288,042)
19 Normalized Sales Volumes (1/1/12 -12/31/1 2)284,589,597
20 Proposed Temporary Surcharge (Credit)-Lost and Unaccounted For Gas Costs $(0.00101)
(1)See Workpaper No.6,Page 1:Line 7,Column (e);Line 11,Column (e);Line 12 Column (e)&Line 17,Column (e)
(2)See Workpaper No.6,Page 1,Line 20,Column (c)
(3)See Workpaper No.6,Page 1,Line 26,Column (d)
(4)See Workpaper No.6,Page 1,Line 41,Column (d)plus Line 47,Column fe)
(5)See Workpaper No.6,Page 1,Line 21,Column (c)
(6)See Workpaper No,6,Page 1,Line 30,Column (d)
(7)See Workpaper No.6,Page 1,Line 42,Column (d)plus Line 51,Column (e)
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__
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NEWS RELEASE
and
CUSTOMER NOTICE
CASE NO.INT-G-13-O5
INTERMOUNTAIN GAS COMPANY
(2 Pages)
NEWS RELEASE
A INTERMOUNTAINfGASCOMPANY
A Subsidiary otMVU Resources Group,Inc.
555 S.Cole Rd.
Boise,ID 83709
[phone]
Intermountain Gas Company files to Increase Prices
BOISE,IDAHO —August 9,2013 --Intermountain Gas Company filed its annual Purchased Gas Cost
Adjustment (PGA)application with the Idaho Public Utilities Commission to change prices by an overall
average increase of 4.15%,or $10.3 million,and if approved,would be effective October 1,2013.The main
reason for the filing is an increase in the price of natural gas that Intermountain purchases for its customers.
The cost to move natural gas through the interstate pipelines to the Intermountain system has also increased.
Intermountain’s earnings will not increase as a result of the proposed change in prices and revenues.
If approved,residential customers using gas for space and water heating will see an average increase of 3.92%,
or $1.25 per month.Customers using natural gas for space heating only will see an average increase of $0.68
per month,or 1.88%,based on average weather and usage.Commercial customers,on average,would see an
increase of $14.18 per month or 7.26%.
The company is also proposing to eliminate the temporary credits that have been included in its current prices
during the past year.Newer temporary credits will be included going forward.Even with this requested
increase,the aforementioned gas-cost portion of Intermountain’s prices will be 49%lower than in 2005.
Scott Madison,Executive Vice President and General Manager of Intermountain said,“The United States
economy is slowly recovering,and with this recovery,we are seeing more demand placed on our substantial
North American natural gas reserves.Increasing natural-gas-fueled electrical generation is also placing
additional demand on supplies and delivery capacity.While this increased demand is causing some upward
price movement,overall natural gas prices remain much lower than they were just a few years ago.The
continued development of shale gas production in North America is expected to keep pace with increasing
demand,maintaining overall price stability.”
Intermountain continues to urge all its customers to use energy wisely.Conservation tips,information on
government payment energy assistance,and programs to help customers level out their energy bills over the
year can be found on the company’s website,vww.intas.con.t
A Purchased Gas Cost Adjustment application is filed each year to ensure the costs Intermountain incurs on
behalf of its customers are reflected in its sales prices.The request is subject to public review and approval by
the Idaho Public Utilities Commission.A copy of the application is available at the Commission offices and on
both the Commission’s and Intermountain’s websites.
Intermountain Gas Company is a natural gas distribution company serving approximately 320,000 residential,
commercial and industrial customers in 74 communities in southern Idaho.Intermountain is a subsidiary ofMD U
Resources Group,Inc.,a multidimensional natural resources enterprise traded on the New York Stock Exchange as
“MDU “for more information about MDUResources,visit the company’s website at www.nitht.corn.for more
information about Intermountain,visit wwiv.in/gas,corn.
**********
Media Contact:Byron Defenbach at (20$)377-6000
A iNTERMOUNTA1N
In the Community to Serv?
Customer Notice
Intermountain Gas Company files to Increase Prices
On August 9,2013 -Intermountain Gas Company filed its annual Purchased Gas Cost Adjustment
(PGA)application with the Idaho Public Utilities Commission to change prices by an overall average
increase of 4.15%,or $10.3 million,and if approved,would be effective October 1,2013.The main
reason for the filing is an increase in the price of natural gas that Intermountain purchases for its
customers.The cost to move natural gas through the interstate pipelines to the lntermountain system
has also increased.Intermountain’s earnings will not increase as a result of the proposed change in
prices and revenues.
If approved,residential customers using gas for space and water heating will see an average increase
of 3.92%,or $1.85 per month.Customers using natural gas for space heating only will see an average
increase of $0.68 per month,or 1.88%,based on average weather and usage.Commercial customers,
on average,would see an increase of $14.18 per month or 7.26%.
The company is also proposing to eliminate the temporary credits that have been included in its current
prices during the past year.Newer temporary credits will be included going forward.Even with this
requested increase,the aforementioned gas-cost portion of Intermountain’s prices will be 49%lower
than in 2005.
Scott Madison,Executive Vice President and General Manager of Intermountain said,“The United
States economy is slowly recovering,and with this recovery,we are seeing mote demand placed on
our substantial North American natural gas reserves.Increasing natural-gas-fueled electrical
generation is also placing additional demand on supplies and delivery capacity.While this increased
demand is causing some upward price movement,overall natural gas prices remain much lower than
they were just a few years ago.The continued development of shale gas production in North America
is expected to keep pace with increasing demand,maintaining overall price stability.”
Intermountain continues to urge all its customers to use energy wisely.Conservation tips,information
on government payment energy assistance,and programs to help customers level out their energy bills
over the year can be found on the company’s website,www.intqas.com.
A Purchased Gas Cost Adjustment application is filed each year to ensure the costs Intermountain
incurs on behalf of its customers are reflected in its sales prices.The request is subject to public review
and approval by the Idaho Public Utilities Commission.A copy of the application is available at the
Commission offices and on both the Commission’s and Intermountain’s websites.
Intermountain Gas Company is a natural gas distribution company serving approximately 320,000
residential,commercial and industrial customers in 74 communities in southern Idaho.Intermountain is
a subsidiaiy of MDU Resources Group,Inc.,a multidimensional natural resources enterprise traded on
the New York Stock Exchange as “MD U.”For more information about MDU Resources,visit the
company’s website at www.mdu.corn.For more information about Intermountain,visit www.intqas.corn.
WORKPAPER NOS.1-9
CASE NO.INT-G-13-05
INTERMOUNTAIN GAS COMPANY
(11 pages)
Workpaper No.1
Case No.NT-G-13-05
Intermountain Gas Company
Page 1 of 1
INTERMOUNTAIN GAS COMPANY
Summary of Northwest Pipeline TF-1 Full Rate Demand Costs
Line INT-G-f 2-01 INT.G-f 2-01 INT-G-1 2-Of
No.Transportation Annual Therms Prices Annual Cost
(a)(b)(c)(U)
1 TF-i Demand 1 Contract#i 412,537,600 $0.041064 $16,940,550
2 IF-i Demand 1 Contract #2 25,550,000 0.054360 1,388,910
3 IF-i Demand 1 Contract #3 73,000,000 0.040214 2,935,648
4 IF-i Demand 1 Contract #4 64,389,650 0.040214 2,589,386
5 IF-i Demand 1 Contract #5 46,230,900 0.040214 i,859,i47
6 IF-i Demand 1 Contract #6 36,500,000 0.040214 1,467,823
7 IF-i Demand 1 Contract #7 87,600,000 0.040214 3,522,778
8 IF-i Demand 1 Contract #8 36,500,000 0.0402i4 1,467,823
9 IF-I Demand I Contract #9 104,495,850 0.040214 4,202,235
10 Total Annual Cost 886,804,000 $0.041017 $36,374,300
Line INT-G-1 3-05 INT-G-1 3-05 INT-G-f3-05
No.Transportation Annual Therms Prices Annual Cost
(a)(b)(c)(d)
ii IF-i Demand I Contract #1 412,537,600 $0.041850 $17,264,663
12 IF-i Demand 1 Contract #2 25,550,000 0.055146 1,408,984
13 IF-i Demand 1 Contract #3 73,000,000 0.041000 2,993,000
i4 IF-i Demand I Contract #4 37,927,150 0.041000 i,555,0i5
15 IF-i Demand I Contract #5 43,489,750 0.041000 1,783,084
16 TF-i Demand 1 Contract#6 36,500,000 0.041000 1,496,500
17 IF-i Demand I Contract #7 87,600,000 0.041000 3,591,600
18 IF-i Demand 1 Contract #8 18,250,000 0,041000 748,250
19 IF-i Demand 1 Contract #9 104,495,850 0,041000 4,284,334
20 TF-i Demand 1 Contract#iO 26,462,500 0.041000 1,084,966
2i IF-i Demand 1 Contract #ii 51,081,750 0.041000 2,094,351
22 Total Annual Cost 916,894,600 $0.041777 $38,304,747
23 Total Annual Cost Difference (Row 22 minus Row 10)$1,930,447 t1)
(1)See Exhibit 4,Line 3,Column (h)
Workpaper No.2
Case No.INT-G-13-05
Intermountain Gas Company
Page 1 of 1
INTERMOUNTAIN GAS COMPANY
Summary of Northwest Pipeline TF-1 Discounted Demand Costs
Line INT-G-1 2-01 INT-G-12-01 INT-G-12-01
No.Transportation Annual Therms Prices Annual Cost
(a)(b)(C)(ci)
1 IF-I Demand I Contract#i 14052,500 $0.020107 $282,559
2 IF-i Demand 1 Contract #2 29,404,400 $0.021330 $627,190
3 TF-i Demand 1 Contract #3 58,400,000 0.022118 1,291,685
4 IF-i Demand I Contract#4 36,500,000 0.026139 954,085
5 IF-i Demand 1 Contract #5 32,850,000 0.008503 279,320
6 Iota!Annual Cost 171,206,900 0.020063 3,434,839
Line INT-G-1 3-05 INT-G-1 3-05 INT-G-1 3-05
No.Transportation Annual Therms Prices Annual Cost
(a)fb)(c)(d)
7 IF-I Demand 1 Contract #1 18,250,000 $0.026650 $486,366
8 TF-i Demand 1 Contract #2 29,404,400 0.021747 639,444
9 IF-i Demand I Contract #3 58,400,000 0.022550 1,316,920
10 IF-i Demand 1 Contract #4 36,500,000 0.026650 972,725
ii IF-i Demand I Contract #5 32,850,000 0.008499 279,201
12 Total Annual Cost 175,404,400 0.021064 3,694,656
13 Total Annual Cost Difference (Row 12 minus Row 6)$259,817 (1)
(1)See Exhibit 4,Line 4,Column (h)
INTERMOUNTAIN GAS COMPANY
Workpaper No.3
Case No.INT-G-13-05
Intermountain Gas Company
Page 1 of 1
Summary of Upstream Capacity Costs
10 Upstream Agreement #1
11 Upstream Agreement #2
12 Upstream Agreement #3
13 Upstream Agreement #4
14 Upstream Agreement #5
15 Upstream Agreement #6
16 Total Annual Cost
INT-G-1 2-01
Annual Therms
(b)
INT-G-12.01
Prices
(c)
INT-G-1 2-01
Annual Cost
(d)
$
207,704
2,749,310
8,298,168
3,331,666
2,406,560
$16,993,407
$(500,000)
$16,493,407
$192,410 (1)
Line
No.Transportation
(a)
1 Upstream Agreement #1
2 Upstream Agreement #2
3 Upstream Agreement #3
4 Upstream Agreement #4
5 Upstream Agreement #5
6 Upstream Agreement #6
$$
25,933,250 0.009924 257,359
155,025,220 0.017735 2,749,310
477,215,600 0.017201 8,208,667
378,465,810 0.009930 3,758,103
164,786,200 0.011090 1,827,558
$16,800,997
INT-G-1 3-05
7 Total Annual Cost
8 Estimated Upstream Capacity Release Credits
9 Total Annual Cost Including Capacity Release Credits
Line
No.
________________________
$(500,000)
Transportation
(a)
$16,300,997
INT-G-1 3-05
Annual Cost
(ci)
INT-G-1 3-05
Annual Therms
(b)
25,933,250
155,025,220
489,899,350
415,754,210
164,618,300
$
Prices
(c)
0.008009
0.01 7735
0.01 6939
0.008014
0.014619
17 Estimated Upstream Capacity Release Credits
18 Total Annual Cost Including Capacity Release Credits
19 Total Annual Cost Difference (Row 18 minus Row 9)
(1)See Exhibit 4,Line 5,Column (h)
INTERMOUNTAIN GAS COMPANY
Summary of Other Storage Facility Costs
Workpaper No.4
Case No.INT-G-13-05
Intermountain Gas Company
Page 1 of 1
Storage Facilities
fa)
I Demand Costs -
2 Clay Basin I Reservaton
3 Clay Basin II Reservation
4 Clay Basin Ill Reservation
5 Clay Basin I Capacity
6 Clay Basin II Capacity
7 Clay Basin Ill Capacity
8 Total Demand Costs
9 Cycling Costs -
10 Clay Basin Cycling Costs
11 Rexburg LNG Facility
$75,971 $911,652
63,299 759,588
60,780 729,360
75,977 911,724
63,314 759,768
60,782 729,384
$400,123 $4,801,476
0.001033 $86,929 $1,043,148
12 Transportaton Reservation
13 Variable Transportation
14 Total Rexburg LNG Facility Costs
15 Storage Demand Charge Credit
16 Total Costs Including Storage Credit
INT-G-13-05
$7,245 $86,940
10,000
$96940
$(2,700,000)
$3,241,564
Line
No.
______________
17 Demand Costs-
16 Clay Basin I Reservation
19 Clay Basin II Reservation
20 Clay Basin Ill Reservation
21 Clay Basin I Capacity
22 Clay Basin II Capacity
23 Clay Basin Ill Capacity
24 Total Demand Costs
25
26
Cycling Costs -
Clay Basin Cycling Costs
266,250 (1)$
221,880 (1)
213,010 (1)
31,950,000 (21
26,625,000 (2)
25,560,000 (2)
84,135,000 (3)
84,135,000 $0.001367 $114,993 $1,379,915
27 Rexburg LNG Facility
28 Transportation Reservation
29 Variable Transportation
30 Total Rexburg LNG Facility Costs
31 Estimated Storage Demand Charge Credit
32 Total Costs Including Storage Credit
33 Total Annual Cost Difference Including Storage Credit (Row 32 minus Row 16)
$5,500 $66,000
22800
$88,800
$(2,700,000)
$3,570,335
$328,771 (4)
(1)Charge Based on Maximum Daily Withdrawal
2 Charge Based on Maximum Contractual Capacity
3)Non Additve Billing Determinants;Includes only Capacity Volumes
4)See Exhibit 4,Line 19,Column (h)
Line
No.
INT-G-12-01
Monthly Cost
(d)
INT-G-12-O1
Annual Cost
(e)
INT-G-12-O1
Prices
(c)
$0.285338
0.285338
0.285338
0.002378
0.002378
0.002378
INT-G-12-O1
Monthly
Billing Determinant
(b)
266,250 (1)
221,840 (1)
213,010 (1)
31,950,000 (2)
26,625,000 (2)
25,560,000 (2)
84,135,000 (3)
84,135,000
Monthly INT-G-13-05 INT-G-13-05 INT-G-13-05
Storage Facilities Billing Determinant Prices Monthly Cost Annual Cost
(a)(b)(c)(U)(e)
0.285338 $75,971 $911,652
0.285338 63,311 759,732
0.285338 60,780 729,360
0.002378 75,977 911,724
0.002378 63,314 759,768
0.002378 60,782 729,384
$400,135 $4,801,620
Workpaper No.5
Case No.INT-G-13-05
Intermountain Gas Company
Page 1 of 1
INTERMOUNTAIN GAS COMPANY
Peak Day Analysis for Demand Allocators
Line Peak Firm Sales
________
Total
No.Description RS-2 GS.1 LV-1 Peak Sales
(a)(b)(c)fd)(e)ft)
1 DEMAND ALLOCATORS PER CASE NO.1NT-G-12-01:
2 Peak Daylherms 368,330 1,678,530 1,001,461 13,150 3,061,471
3 Percentof Total 12.0311%54.8276%32,7118%0.4295%100.0000%
4 PROPOSED DEMAND ALLOCATORS PER CASE NO.INT-G-13-05:
5 Peak Day Usage Per Customer 5.66 7.61 32.72
6 January 2012 Actual Customers 65,570 223,478 30,964 320,012
7 INT-G-13-05 Peak Day Therms (Line 5 mulitplied by Line 6)371126 1,700,668 1013,142 23,150 3,108,086
8 Percent ofTotal 11.9407%54.7175%32.5970%0.7448%100.0000%
Contract Demand Therms
)NTERMOUNTA)NGAS COMPANY
Analysis olAccount 1860 Surcharas (Credits)
Eshmatad September 30,2013
Workpaper No.6
Case No.INT-G-13-05
Intermountain Gas Company
Page 1 of 2
IS
II
12
13
14
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it
17
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to
20
21
22
23
24
22
22
27
28
22
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32
33
34
35
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40
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Derull D &Us DS8:Ts60
A)cl )d(ci
6 (11940217)
3164.45624
165 764 41)
(75834)
(154,031.81)
)290,455.D6)
(97.607.76)
3.10(943352
444,316 02)
AL Desnñplbr loW
(9
ACCOUNT 1860VARIABLEAMOUNTS:
Net Cumulalts.SersuedSee Balancein 2260.2017cc or101102 8 (1.26035489)
AnatetonnltlO2O2Oee&&30113 B 1,069,44050
Eetmelrd 75mm SelecT/I trough 9/30113 24.644,359
knnct%or 6*$0 00350 97.42312
E06maOWArncteSon n 18409020919430163 1,116 472.72
22744.4.4 Belsucehr78402510.49430173
Deterred Gus Costs FromFrcduc.nsupp4.n in 1864.2160919011112 6 /597.84545)
Defrnmrd OneCosta FromF4o&nertasupyhernn 1500 2160 &no4r 6730113 3310 875.62
&40rmtedDelwnd Cc06 In 1660.2180 tornlit Snogir5130173 1.061.22016
45*6.4 Balance61e002160919430173
OncrnmvercdinCce40 Balnrnnrn 76602670915130113
DeSy Gas ExcessGatesDderrsd er7960334091404413
htenssIDslrnredInlBfiO.2340at101512 6 20.56)
romeOOseOnd619402340hm4r 6.39173 7351.93)
EnloratedInterestfrom 7/IfrogS 5130113 6709
frothnulsd Balance in 18402340 at9430163
ESTIMATED ACCoUNT3860 VARIABLE BALANCE At 9130113
ACCOUNT isoo LOST AND UNACCOUNTED FOR AMOSNTS:
CanCLcruAuSueDeterred GusU&ornen 18602130 sed05ttI2 1 1603.66499
i*n944 CancfloeDeterredGasBeWne669602120end1011/12 534.00500
NdCwnuitfrsoelsm.dcaetatarcshls602l2t.snllWltl2 $2.138219.99
CeeArnotoNcnrnIBOc2lXsadtGeII3 $ii 4340372)
Edhneted7/urn Sates SI trough9430173 23.797.353
ArncWotecR*8 /506474))i1L79954)
Ecd5medkrenloeturn 16402722919130113 1.542.23330)
isbo*al4erratabona 78802640 re0744224t3 9 00500394)
Es40n&edTherrn Sales 7/I macgIn9/30163 59651386
Mente*r ReIn 9 2)00255)154.41451)
Ezrneladkrncta56n17860214091350193 (749.999 44)
filtrated 8.1cm.in r860.2120s19i39113
LestI Uraccoonl Forces Xsl.rrsl 91186c.2ltgstlGlI72 t 107.02446
TotaiLcct&UnsmoouoedFeroasrnnt4r6.34t13 t 599,28063
frcSmoledLeO &Ureacouterd FmGee711 SnoopS9730113 627,494.52
Essex/ed TotalLest&Groccocrtrd FmGsa.79730113 5 766,77575
BaseRote Co4eo6onclimb Unsmrcded FmGsaSnoopS 5139113 5 962.39925
GalmetndonenReteCo%eotnndicdosremocm91dFeroenTtl RooupfrSt22itU 151,00093
EesrnotedsoseRstnCcten4nndioo&hrancountrdlerGenstt0wt3 7,974.26577
ScUrrIed Lcd 6 Unecenuoted FmDelerral (Total metes.Raatctacscn 1011112tancgh 900173)(397,57002)
Es4mstrdR&enon91 79602154et9t22i13 (750,405,54)
Curs49oua4oosliest&Ursoccuntrd ForGesGelernal 75%(277.864.17)
irduainsl%/frcofionofio4UUranocuded For TsrDefend 25%(72.626.39)
EstcmatsdBalancein 16602150 at 900113
ConsLostaUrancourt Forinterest Datarred911860242091 1911112 5 22.65
CreLost&UneoucortrdFrmntmrnl0eterrdrn t160242080nog54439113 75026
EssrrrotedCoretnlereo Born 717 tnoughs/3Ui3 256)
frsthratsdBalancein38602420 et 900173
IndustrialLest &Unsocsurt.4 For Intsr.st Deterred In1$6c.2364st 751162 $222
indushielLost &Unaccounted ForIrtmeiDeterredin1940236060045 609173 26.61
freOuslrdirduchielLcd6Unaccounted FrmntmedhcmUIUncuph 900113 6,71)
Esthratsd Bolerca In 1860.2360.8 909113
ESTIMATEDACCOUNT 1860 LOST ANDUNACCOUNTED FORBALANCE AT 900(13
ACCOUNT 1860 FIXEDAMOUNTS:
NetCumuiotinsDsrsmsdSastalaroshi1860,2050a1 1941112 8 0,604,02569)
6446 fInned Gas Uciacce n 7960 3060 at 1017113 9 (16,89962)
Rrrorloalcrfor 65-I in1660 2040sttd3Oil3 465,97026
Ea6meted6441 Them Soles711 800045 900113 1,033,405
RS-t%erortaa4crRete 9 007395 25,577.12
DO/rated6441 lolorce 9176602060919730113 474,65776
6442Entered SosUolenor 61660 2070 st 1017112 $28,33050
knot/eaterbor60-26 660.2070.16.00113 2,144,87627
Eelerreted6442ThermSsInsTitSnsugh 9134413 13.119,017
65.2Anrortshon Rate 9 0 01273 667.00509
Esleneted6442Balance 6860 0270 sI 9130113 2,340,27194
DLI Deterred GeeBalance 611603060.91017112 9 (161,463.94)
OratsborloGS-I In 7040208091404413 1.805,929.76
Essrrated Therm Dales 711 trough900173 8,944,490
SLlAroteSnnReIe t 007615 160,53475
Eesreted0447 Balance er 16602060915130113 9,605,04067
otoufli Xelmed Sac Balance er 18602056 911011112 9 /4733)
AimotoSorborLU.l rn1540.3U50916O513 647219.91
EflroledLVI Bosh 10223mm Salesliienough 9139113 944.667
LV-lAnnctebncR*9 202159 16.907,05
DO/notedIchorcol Baiaxe61860205691943603 94.27367
Extenarsd CrarciatinaBalance91186620509190513
77933
22,92
Workpaper No.6
Case No.INT-G-13-05
Intermountain Gas Company
Page 2 of 2
EL Dssofln&n
INTERMOUNTAIN GAS COMPANY
Analysts of Account1N60 Surchsrqes Credits)
EstimatedSeptember30,2013
1 FindCostCollection Dslnmsd InlStO.22COul 1011112
2 Fond CodCoteohonDeterreder1840 2250Snoogh6730113
3 EnOmolod FixedCod CuNnohonDeferredfrom711tonugh 0130113
4 Esbmslsd NslsnosIn10602206sf0130113
5 Cspsrlly RslssssdlPurohsssd Deferred ix lttO.2320st 1011112
o CspeodyRsleurthmeohesedDeferred in 10002320 nnouyh 0130113
7 Es*relndCepso4y RelnoondFreohonedDnlermed from 7/I trough0007/3
o Estixrstsd OulseosIn1006.2320at 0/30113
O htsnsst ir lOtO.2436sf1010112
ID Inlmrdorlmmndm 78602430OnnughOflWl3
II EotmelndInternetfrom711 Snough 0730113
12 Estkestsd Nslsros in IttO2430sf0130113
13 Msrsgnot ofPlpsfiesTrurspodatlorCapacityDslsrrsdix 10602030 sf101102
14 MenegnmedefPty&meTrsnrmIebrnCapno4yDe4erredin1060.2SaDOnugh0130113
ID frssmstedDeoomslin 1060.2530from711 Ooouph 0130113
It Do6metndDeismein 10602530t500I13
IT 6011Mmer&nbonix 11602540.40130773
IS EMmeledRS.lTherm Sebohom711 0nouh 0130113
10 R54 Ammtotorfret.
20 Eoumefod651 dmodoetorer 1085.2540sf0130113
21 RU-2Amer&sbon’m 18602540.10130113
22 Eohnebd 0162Therm 5Mm from 711 Omoogh5730113
23 0012 Vnm&sitooPete
24 Eefmreled6012Ammtsbonin10402540.407301l3
25 OS.IdmcetehoninI1002SdOefD3OII3
28 Estmnlod 55-I Therm Saixohom7ll trough 0130113
27 05.1 AmuloehonRein
20 Eshmelnd 55-I Vormtshnn In 10602540 st500113
25 Eshmefnd CernAmatsbon’er 10402540sf0130113
30 10.1 AmmISsOonix 10002550 sf0130113
31 Eshmeled LVI Dm4162ThermOMenfrom7/I8nouolr0730173
32 10.1 Vmmtston RsIn
33 EsOmnlnd LV-lOmmthehonix 1840 2550 e7600113
20 Ee8meled IrdustiolAmerlusOon m 11602500 sf000113
35 Esfbnafsd EetsnoeIn 10602530sf 0130113
36 LNOOsbs CredOsDslsesd ix 104020004sf1011112
37 008RmoveryCredd Deterredin1060 2320Onough 800113
30 NeonDhnnngCr404DnlermndmOOD2100Omough 0130113
30 Esbmstsd Oulsoosin 1066.2000 sf000113
40 ESTIMATED ACCOUNT 1860 FIDEDBALANCEAT 6)30)13
41 TOTAL DEFENSESACCOUNT 1860 BALANCE
Uetoll aNti UUbJs6)
(7)Ic)(d(Is)(I)
O 2,330,16300
(12,217.22744)
12,11517721
2,308,482,77
$(1,101.36374)
(7,544,35043)
II.270,524 521
O 140.101
(1.120 50)
161414)
3,834071
14,114.446 061
1518.415 DVI
O (4,73640613)
S 423,41003
1,125465
8 001302 23,57107
441,26105
0 1,645,61356
13,115,077
S 0.01134 146,264.41
2,060,17800
1 1,043,46266
8,844,060
001125 06,50507
1,142,01707
8 14,84134
866,847
8 5 00404 4.20232
10,12616
16.005.240161
(1340.53)
(7.031,11145)
6)53056)
3,660,45757
16,12610
(78505)
14,54500)
1 )l,lIl.862.III
$18.150,70460)
4 Proposed Adjustment to LV-1 Tariff “
5 LV-1 Therm Sales (1/1/12 -12/31/12)
6 Annualized Adjustment (Line 4 multiplied by Line 5)
Total
(e)
0 3,616,848
3,616,848
100.000%
$0.02945
3,616,848
$106,516
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 Adjustment/Therm Block 1 and 2 (Line 9 divided by Line 10)
12 WACOG Commodity Charge Change (2)
13 Total Price Adjustment/Therm Block 1 and Block 2
14 Price Adjustment/Therm Block (3)
15 WACOG Commodity Charge Change (2)
16 Eliminate INT-G-12-01 Variable Temporary
17 Total Price Adjustment/Therm Block 3
(1)See Exhibit No.4;Line 30,Column (I)minus the difference of Line 21,Column (f)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),plus Line No.4,Column (e)
$106,516
100.000%
$106,516
3,616,848
$0.02945
0.03852
$0.06797
$0.00848
0.03852
0.001 36
$0.04836
Line
No.
Workpaper No.7
Case No.INT-G-13-05
Intermountain Gas Company
Page 1 of 1
Description
INTERMOUNTAIN GAS COMPANY
Analysis of LV-1 Tariff Block 1,Block 2,and Block 3 Adjustments
Block I Block 2 Block 3
Therm Sales Therm Sales Therm Sales
(a)(b)(c)(U)
1 LV-1 Therm Sales (1/1/12 -12/31/1 2)3,616,848 0
2 Blocks 1 and 2 Therm Sales 3,616,848 0
3 Percent Therm Sales between Blocks 1 and 2 100.000%0.000%
Workpaper No.8
Case No.INT-G-13-05
Intermountain Gas Company
Page 1 of 2
2 Projected Oct 12 -Sep 13 L&U (Therms)
3 Estimated Oct 12 -Sep 13 Sales (1)
1,977,331
612,244,601
4 Oct 12 -Sep 13 L&U Factor (line 2 divided by line 3)
5 Lost and Unaccounted for Gas INT-G-13-05 (Dollars)
0.323%
6 Lost &Unaccounted for Gas (1860-2150)(2)
7 Estimated Oct 12-Sep 13 Sales (1)
8 L&U rate per therm embedded in base rates
612,244,601
$0.00182
$716,775
9 Oct 12 -Sep 13 Collection of Lost &Unaccounted for Gas
10 Projected L&U (Over)/Under Collection (Line 6 minus Line 9)
1,114,285
$(397,510)
(1)Estimated Oct 12 -Sep 13 Sales (Therms)
34,914,148
180,228,743
107,608,828
289,492,882
612,244,601
INTERMOUNTAIN GAS COMPANY
Analysis of Lost and Unaccounted for Gas (“L&U”)
Line
No.
_________
I Lost and Unaccounted for Gas INT-G-13-05 (Therms)
Description
(a)
Detail
(b)
Amount
(c)
RS-1
RS-2
GS-1
Industrial
Total Sales
(2)See Workpaper No.6,Page 1,Line 35,Column (c)
INTERMOUNTAIN GAS COMPANY
Lost and Unaccounted for Statistics
June 2013
ANNUAL STATISTICS
Workpaper No.8
Case No.INT-G-13-05
Intermountain Gas Company
Page 2 of 2
Check for Dead Orders
Year Check for Dead Orders Found dead Percent Found Dead
2008 5,088 708 13.00%
2009 6,481 542 8.36%
2010 12,441 569 4.57%
2011 10,093 795 7.87%
2012 5,089 513 10.08%
2013 2,971 608 20.46%
Drive Rate Errors
Year Drive Rate Errors
2007 43
2008 26
2009 18
2010 13
2011 14
2012 3
2013 2
Pressure Errors
15
20
19
8
15
6
Pressure Errors
Gas Loss from Line Breaks
2007 —656 occurrences 254,455 therms of gas loss calculated
2008 —495 occurrences 182,920 therms of gas loss calculated
2009—301 occurrences 130,251 therms of gas loss calculated
2010 —175 occurrences 88,947 therms of gas loss calculated
2011 —154 occurrences 49,856 therms of gas loss calculated
2012—177 occurrences 68,221 therms of gas loss calculated
2013 -87 occurrences 27,128 therms of gas loss calculated
Year
2008
2009
2010
2011
2012
2013
IN
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