20150807Application.pdf

EXECUTIVE OFFICES
Irurenr,aouNTArN Gls Coupn ruv
555 SOUTH COLE ROAD . P.O. BOX 7608 . BOISE,IDAHO 83707 . (2081377-6000 . FAX [phone]
Ft,l ,1. ,olll u'r-,
August 7,2015
Ms. Jean Jewell
Commission Secretary
Idaho Public Utilities Commission
472W. Washington St.
P.O. Box 83720
Boise, D 83720-0074
RE: Case No. INT-G-15-02
Dear Ms. Jewell:
Attached for consideration by this Commission are the original and seven (7) copies of lntermountain Gas
Company's Application for Authority to Decrease lts Prices on October 1,2015.
If you should have any questions regarding this Application please contact me at377-6168.
Sincerely,
7/f/@
,/vi"nul P. McGrath
Director-Re gu latory Affairs
lntermountain Gas Company
Enclosure
cc: Scott Madison
Ronald L. Williams
INTERMOUNTAIN GAS COMPANY
CASE NO. INT.G.15.O2
APPLICATION,
EXHIBITS,
AND
WORKPAPERS
In the Matter of the Application of INTERMOUNTAIN GAS COMPANY
For Authority to Decrease lts Prices on October 11 2015
(October lr20l5 Purchased Gas Cost Adjustment Filing)
Ronald L. Williams, ISB 3034
Williams Bradbury PC
l0l5 W. Hays St.
Boise, Idaho 83702
Telephone: [phone]
Attomey for Intermountain Gas Company
t, I
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
Case No. INT-G-I5-02
APPLICATION
In the Matter of the Application of
TNTERMOTJNTAIN GAS COMPANY
for Authority to Decrease Its Prices
Intermountain Gas Company ("lntermountain" or "Company"), a subsidiary of MDU
Resources Group, Inc. with general offices located at 555 South Cole Road, Boise, Idaho, pursuant
to the Rules of Procedure of the Idaho Public Utilities Commission ("Commission"), hereby
requests authority, pursuant to Idaho Code Sections 6l-307 and 6l-622, to place into effect October
1,2015 new rate schedules which will decrease its annualized revenues by $15.3 million. Because
of changes in Intermountain's gas related costs, as described more fully in this Application,
Intermountain's eamings will not decrease as a result of the proposed decrease in prices and
revenues. Intermountain's current rate schedules showing proposed changes are attached hereto as
Exhibit No. I 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
Ronald L. Williams
Williams Bradbury PC
1015 W. Hays St.
Boise. Idaho 83702
In support of this Application, Intermountain does allege and state as follows:
APPLICATION - 2
I.
Intermountain is a gas utility, subject to the jurisdiction of the 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 - Arimo, 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;
Blaine County - Bellevue, Hailey, Ketchum, and Sun Valley;
Bonneville County - Ammon, Idaho Falls, Iona, and Ucon;
Canyon County - Caldwell, Greenleaf, Middleton, Nampa, Parma, and Wilder;
Caribou County - Bancroft, 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 - Heybum, 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, a compressor station, distribution mains, services, meters and
regulators, and general plant and equipment.
I
Intermountain seeks with this Application to pass through to each of its customer classes
changes in gas related costs resulting from: 1) costs billed to Intermountain from firm transportation
providers including Northwest Pipeline LLC ("Northwest" or "Northwest Pipeline"),2) a decrease
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 ("PGA")
APPLICATION - 3
provision, 4) the inclusion of temporary surcharges and credits for one year relating to natural gas
purchases and interstate transportation costs from Intermourtain'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-14-01. The aforementioned changes would result in a price decrease to Intermountain's
customers.
These price decreases are applicable to service rendered under rate schedules affected by
and subject to Intermountain's PGA, initially approved by this Commission in Order No. 26109,
Case No. INT-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: l) Intermountain's base rate gas costs, 2) its rate class allocation,
and 3) adjusting temporary surcharges or credits flowing through to Intermountain'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. 33139, Case No. INT-G-14-01.
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-14-01.
The Company's Application includes $1.4 million related to the acquisition of additional
Plymouth LNG storage capacity on Northwest's delivery system. The Plymouth facility has
been a valuable asset for the Company given its ability to help ensure supply and delivery to
Intermountain's core market customers during extreme weather events. Additionally, extreme
weather events in the Northwest typically bring with them considerably higher natural gas spot
market prices. Plymouth LNG supplies have helped to insulate Intermountain's customers from
these extreme weather related price spikes. The Company recently was able to acquire an
incremental amount of Plymouth capacity of 378,900 MMBtu with a daily deliverability of
APPLICATION - 4
41,975 MMBtu. In addition to the operational and price mitigating benefits this added capacity
brings to Intermountain's customers, had this incremental Plymouth capacity not been subscribed
to, Intermountain would have been faced with a rise in costs associated with its existing (lower)
Plymouth capacity in excess of the costs associated with this incremental acquisition.
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 20 of Exhibit No. 4 include Sl.8 million in savings from
Intermountain's management of these storage assets.
Exhibit No. 4, Lines I through 20, 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$0.32764 per therm, as shown
on Exhibit No. 4, Line 22, Col. (f). This compares to $0.39482 per therm currently included in the
Company's tariffs.
Deliverable shale gas reserves in North America continue to be significant which, combined
with the anemic growth in our nation's economy, contributed towards the decrease in the
Company's WACOG. From a historical perspective, robust natural gas supplies combined with
significant storage balances have kept natural gas prices lower as compared to just a year ago.
Additionally, the proposed WACOG includes benefits to Intermountain'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 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 2015-2016 PGA period. Intermountain will employ, in
addition to those fixed price agreements already in place, cost effective price arrangements to
APPLICATION - 5
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
customers to any significant 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 any pending natural gas price
changes.
VI.
Pursuant to the Commission's Order in Case No. INT-G-14-01, Intermountain included
temporary credits in its October 1, 2014 pices for the principal reason of passing back to its
customers deferred gas cost benefits. Line 27 of Exhibit No. 4 reflects the elimination of these
temporary credits.
vII.
Intermountain's PGA tariff includes provisions whereby Intermountain's proposed prices
will be adjusted for updated customer class sales volumes and purchased gas cost allocations,
pursuant to the Company's approved cost of service methodology. Intermountain's proposed prices
include a fixed cost collection adjustment pursuant to these PGA provisions, as outlined on Exhibit
No. 5, Line 25. The price impact of this adjustment is included on Exhibit No. 4, Line 28. The
Fixed Cost Collection Rate resulting from the adjustment plus the annual difference in demand
charges from Exhibit No.4, Lines I -20, Col. (h) is shown on Exhibit No. 5, Line29. 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 l. 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. l9l balance to
its customers through temporary price adjustments to be effective during the l2-month period
ending September 30,2016, as follows:
l) Intermountain has deferred fixed gas costs in its Account No. l9l. The debit amount
shown on Exhibit No. 8, Line 7 , Col. (b) of $ I .l 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 debits and credits, as detailed on Exhibit No. 8 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. l9l a variable gas cost debit of $0.7
million, as shown on Exhibit No. 9, Line 2, Col. (b). This defened debit is attributable to
Intermountain's variable gas costs since October 1,2014. Intermountain proposes to collect this
balance via a per therm debit, as shown on Exhibit No. 9, Line 4, Col. (b) and included on Exhibit
No. 6, Line 3.
3) Finally, Intermountain has deferred in its Account No. l9l deferred gas costs related to
Lost and Unaccounted For Gas as shown on Exhibit No. 9, Lines 5 through 20, Col. (b). This
deferral results in net per therm decreases to Intermountain's sales customers, as illustrated on
Exhibit No. 9, Line 12, Col. (b), and included on Exhibit No. 6, Line 3. The Lost and Unaccounted
For Gas deferral 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. 33139, Case No. INT-G-14-01, Intermountain has
deferred in its Account No. l9l variable gas cost credits associated with sales of liquefied natural
gas at its Nampa, Idaho facility. Intermountain proposes to pass back this $689,367 sales credit as
outlined on Exhibit No. 10, Line 7 . Exhibit No. l0 is attached hereto and incorporated herein by
reference.
APPLICATION - 7
xI.
Intermountain has allocated the proposed price decreases to each of its customer classes
based upon Intermountain's PGA provision. However, a straight cent per therm price decrease was
not utilized for the LV-l tariff as no fixed costs are currently recovered in the tail block of the LV-l
tariff. The proposed changes in the WACOG, and variable defened 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-l tariff.
XII.
As outlined on Exhibit No. l, Page l, Lines 33 through 44, the T-3, T-4 and T-5
tariffs include the following adjustments: a) removal of existing temporary price changes; b) the
uniform Lost and Unaccounted For Gas decrease from Exhibit No. 9, Line20, Col. (b) is applied to
each tariff; and c) the LNG Sales Credits are applied to T-4 and T-5 as illustrated on Exhibit No.
10, Line 7, Cols. (g-h).
xIII.
Exhibit No. I I is an analysis of the overall price decreases by class of customer. Exhibit
No. 1l is attached hereto and incorporated herein by reference.
xIv.
The proposed price decreases herein requested among the classes of service of
Intermountain reflect a just, fair, and equitable passthrough of changes in gas related costs to
Intermountain' s customers.
xv.
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.
xVI.
Intermountain requests that this matter be handled under modified procedure pursuant to
Rules 201-204 of the Commission's Rules of Procedure. Intermountain stands ready for immediate
consideration of this matter.
APPLICATION - 8
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 I,2015 in the manner shown on Exhibit No.
2.
b. That this Application be heard and acted upon without hearing under modified procedure,
c. For such other relief as this Commission may determine proper herein.
DATED at Boise, Idaho, this 7th day of August,2015.
INTERMOI.INTAIN GAS COMPANY Williams Bradbury PC
and
By i?a t h/4/;
Ronald L. Williams
Attomey for Intermountain Gas Company
APPLICATION - 9
CERTIFICATE OF MAILING
I HEREBY CERTIFY that on this 7th day of August, 2015,I served a copy of the
foregoing Case No. INT-G-15-02 upon:
Ed Finklea
Northwest Industrial Gas Users
326 5th St
Lake Oswego, OR 97034
R. Scott Pasley
J. R. Simplot Company
PO Box 27
Boise,lD 83707
Chad Stokes
Cable Huston et al.
l00l SW Fifth Avenue, Suite 2000
Portland, Oregon 97204-1136
Don Sturtevant
J. R. Simplot Company
PO Box 27
Boise,ID 83707
by depositing true copies thereof in the United States Mail, postage prepaid, in envelopes addressed
to said persons at the above addresses.
rector - Regulatory Affairs
APPLICATION - IO
EXHIBIT NO. 1
CASE NO. INT-G.15.02
INTERMOUNTAIN GAS COMPANY
CURRENT TARIFFS
Showing Proposed Price Changes
(12 pages)
Exhibit No. 1
Case No. INT-G-15-02
lntermountain Gas Company
Page 1 of 12
INTERMOUNTAIN GAS COMPANY
Comparison of Proposed October 1,20,l5 Prlces
To October 1, 2014 Prices
Line
No.Rate Clase
Prices per
tNT.G.t&01
PropGed
Adjuttment
(c)
Proposed
Oclober l, 2015
Pricee
(d)
0.87267
0.7601 1
0.71 t85
0.67822
0.729'18
0.70745
0.68643
0,67833
0.657'13
0.63667
0.63667
0.67822
0.67822
0.67833
0,6s713
0.63667
0.67833
0.65713
0.63667
0.49512
0.45663
03v42
0.05465
0.02205
0,00792
0.05777
0.01928
0.00455
0.84253
0.00111
0.04370
4
5
6
7
8
I
'10
11
12
13
14
15
16
1 RS-l
2
3
(a)
April - November
December - March
(b)
0.90500
0.79244
0.76036
0.72673
0.7706/t
0.7489'l
0.72789
0.71979
0.69859
0.67813
0,67813
0.72673
0.72673
0.71979
0.69859
0,67813
0.71979
0.69859
0,67813
0.53796
0.49947
0.4't818
0.05617
0.02357
0.00944
0.05983
0.02134
0.00661
0.84253
0.00279
0.04538
(0.03233)
(0.03233)
(0.04851)
(0.04851)
(0.04146)
(0.04146)
(0.04146)
(0.04146)
(0.04146)
(0.04146)
(0.04146)
(0.04851)
(0.04851)
(0.04146)
(0.04146)
(0.04146)
(0.04146)
(0.04146)
(0.04146)
(0.04284) (3)
(0.04284) 0)
(0.08376) (1)
(0.oots21 tsl
(0.00152) 6)
(0.00152) 6)
(0.00206) (6)
(0.00206) (6)
(0.00206) (6)
(0.00168) (6)
(0.00168) (6)
RS.2
April - November
December - March
GS-1
April - November
Block'l
Block 2
Block 3
December - March
Block'l
Block 2
Block 3
CNG Fuel
17 s-R (i)
18 Apnl - November
19 December- March
20
21
22
23
24
25
26
27
28
E.C (4
April - November
Block'l
Block 2
Block 3
December - March
Block 1
Block 2
Block 3
LV.l
Block'l
Block 2
Block 3
29
30
31
32
33 T.3
u
35
36
37 T.4
38
eo
40
41 T.5
42
43
44
Block 1
Block 2
Block 3
Block'l
Block 2
Block 3
Demand Charge
Commodity Charge
Over-Run Service
{!rThe lS-R price is based on he R92 Decembsr - March pdce and receives the same PGA adiustments.
{2)The lS-C price is based on he GS-l December - March price and recoives the same PGA adlustments.
(3)See Workpaper No. 6, Line '13, Column (e)
(a)See Workpaper No. 6, Line 17, Column (e)
(5) Remove INT-G'14{1 temporary and add the t€mporary from Exhibit 9, Line 20.
(6)RemovelNT-Gl+0ltemporaryandaddthetemporariesfomExhibitg,Line20and Exhibitl0,LineT
Exhibit No. 1
Case No. INT-G-15-02
lntermountain Gas ComPany
Page 2 of L2
IDAHO PUBLIC UTILITIES COMMISSION
Approved
MareHgra0+E
Jean D. Jewell Secretary
Rate Schedule RS-l
RESIDENTIAL SERVICE
APPLICABILIW:
Applicable to any customer using natural gas for residential purposes, who does not have bolh natural
gas water heating and natural gas space heating.
RATE:
Monthly minimum charge is the customer charge.
For billing oeriods endino April through November
Customer Charge - $2.50 per bill
Comrnodity Charge - $O3O50O per therm' 150-:8?16rl
For billino periods endino December throuoh March
Customer Charge - $6.50 per bill
Commodity Charge - $€+9ryH per therm'trd.?60-1il
'lncludes:
Temporary purchased gas cost adjustment of 9€ft5'o+) If(o-iio85il
weignediverage cosiof gas of Sb3€rl02l$o-rzo_4.l
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 Schedule.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the Company's Tanff, of
which this rate schedule is a parl.
Effectiveerfir#e4+Sheel No 01 (Page 1 of 1)
lntermountain Gas Company
Irssueo uy Intermountain Gas Company
lBy. Michael P. McGralh Title: Director - Regulatory Affairs
Lrjgs!rys$'tl#qcla6Ea,ro-El
Exhibit No. 1
Case No. INT-G-15-02
lntermountain Gas Company
Page 3 of 12
IDAI{O P['BLIC UTILITIES COMMISSION
Approvedrffiort Effectiverrp+f#+SForty- Ellr$r ReriseOMil Sheet No. 02 Jean D. Jewell Secretary
Namo
of Utility lntermountain Gas Company
Rate Schedule RS-2
RESIDENTIAL SERVICE. SPACE AND WATER HEATING
APPLICABIUTY:
Applicable to any cuslorner using natural gas for residential purposes, which must include at a
minimum, both natural gas water heating and natural gas space heating.
RATE:
Monthly minimum charge is the customer charge.
For billino perbds endinq April throuoh November
Customer Charge - $2.50 per bill
Commodity Charge - $e#6€36pertherm' lSb'7fEEl
For billino oeriods endino December throuqh March
Customer Charge - $6.50 per bill
Commodity Charge - $ffi73pertherm. 15:6?8zzl
'lncludes:
Temporary purchased gas cost adjustment of $(0f,270rt ls(o-oor68il
Weighted average cost of gas of $O3'9rt8* lSo.gzzo+ |
PURCHASED GAS COST ADJUSTMENT:
This tariff is subriect to an adjustment for cost of purchased gas as provided for in lhe Company's
Purchased Gas Cost Adjustment Schedule.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the Company's Tariff,
of which thas rate schedule is a part.
l.P U C. Gas Tariff
Exhibit No. 1
Case No. INT-G-15-02
lntermountain Gas Company
Page 4 of t2
IDAHO PUBLIC UTILITIES COMMISSION
Approvedlvffits EffectiveAflil{ff+6
Jean D. Jewell Secretary
Rate Schedule GS-1
GENERAL SERVICE
APPLICABILITY:
Applicable to customers urhose requirements for natural gas do not exceed 2,000 therms per day, at anypoini on the Company's distribution system. Reguirements in excess of 2,000 therms per day may be
served under this rale schedule upon execution of a one-year written service contract.
RATE:
Monlhly minimum charge is the customer charge.
For billinq periods endino April throuoh November
Cuslomer Charge - $2.00 per bill
Commodity Charge - First
Nexl
Over
2oo therms per bill @ g€i7+€6.t' l$o-79181
1,800 therms p€r bill @2,000 therms per bill @ $ffi2789'
For billino oeriods endino December throuqh March
Cuslomer Charge - $9.50 per bill
Commodity Charge - First 200 therms per bil @ g€J{€79' t-O-i?8ttNext 1,800 therms per bill @ g,O€,gtiso' 806s75lOver 2,000 therms per bill @ S'e67gt3'FOil6-6-7.|
'lncludes:
Temporary purchased gas cost adJustment gLgtorQ3{FO) f(o-jl-3i3ll
Weighted average cost of gas of $Ot9t+€'2 150.32764 |
Itsst,eo oy: lntermountaan Gas Compiny
lBy. Mrchael P. McGrath rtle: Director - Regulatory Alfairs
I Effective zqot*ffit+ loctober 1, 2015 |t_,_ ! l
Exhibit No. 1
Case No. INT-G-15-02
lntermountain Gas Company
Page 5 of 12
IDAHO PUBLIC UTILITIES COMMISSIONl.P U.C. Gas Tarifl
Raie Schedules
€iftiaitr Revised
Approved
lllarch+Ar2O+s
Effective
*prit+,+OfgSheel No 03 (Jean D. Jewell Secretary
Rate Schedule GS-I
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 - $Of,,i8tii per therm'lS0-:656-6il
'lncludes:
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 Schedule.
SERVICE CONDITIONS:
1. All natural gas service hereunder is subjeci to the General Service Provisions of the Company's Tariff,
of which this rate schedule is a part.
BILLING ADJUSTMENTS:
1. Any G$1 customer who leaves the GS-1 service will pay to lntermounlain Gas Company, upon
exiting the GS-1 service, all gas and transportation related costs incurred to serve the customer
during the GS-'l servico period not paid by the customer during the time the custorner was using GS-
1 service. Any GS-l customer who leaves the GS-l service will have refunded to them, upon exiting
the GS-1 service, any excess gas commodity or lransportation payments made by the customer
during the time they were a GS-1 customer.
Temporary purch ased gas cost adjustme nt,of S{€€35p0} lS ( 0-: 0 13, X I
WeQhted average cost of gas of 1E$39{€2 150.32764 |
By. Michael P. McGrath
Effective: Xffil-l#+F October 1, 2015
fitle: Director - Regulatory Affarrs
Exhibit No. 1
Case No. INT-G-15-02
lntermountain Gas ComPanY
Page 6 of t2
IDAHO PUBLIC UTILITIES COMMlSSION
Rate Schedules
-@Bcvqed lElggl
i tF.u.c. Gas iiiitt
Neme
et_14!!!!v
i
Sheel No. 4 -A*.frfZf -,]
Approved
UltrcHei20ts
EffectivelrpnltffitS
lntermountain ,qg9 Qo.Epqny Jean D. Jewell Secretary
Rate Schedule lS-R
RESIDENTIAL INTERRUPTIBLE SNOWMELT SERVICE
APPLIGABILITY:
Applicable to any resilentral customer otherwise eligible to receive service under Rate Schedule RS-1 or
RS-2 who has added nalural gas snowmelt equipment after 6111201O. The intended use of the snowmelt
equipment is to melt snorv and/or ice on sidewalks, driveways or any other similar appurtenances. Any and
all such applixUons meeting the above criteria will be subiect to service under Rate Schedule lS-R and will
be separately and individually metered. All service hereunder is intenuptible at the sole discretion of ihe
Company.
FACILITY REIMBURSET|ENT CHARGE:
All new intemrptible Snormelt service cuslomers are required to pay for the cost of the Snorrmelt meter set
and other related hility and equipment costs, prior to the installation of the meter set. Any requesl to alter
the physixl location of the meter set and related lacilities lrom Company's initial design may be granted
provided, howBver, the Company can reasonably accommodaie said relocation and Customer agrees to
pay all relsted costs.
RATE:
Monthly minimum charge as lhe Customer Charge.
For billino periods endinq April throuoh November
Custorner Charge - $2.50 per bill
Commodity Charge per therm' 150-6?8rrl
For billino oeriods endino December throuoh March
Customer Charge - $6.50 per bill
Commodity Charge per therm' 1506?8rl
'lncludes:
Temporary purchased gas cost adjustment,{ 0€€2794) Ift--oor58il
Weighted average cost of gas of $e3&B? 150.32764 I
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 Schedule.
SERVICE CONDITIONS:
1 All natural gas service hereunder is subject to the General Service Provisions of the Company's
Tariff, of wltich this Rate Schedule is a parl
rssuad by: lntermountain Gas Company
ey: Michael P. McGralh
Effective:
- Regulatory Affairs
Exhibit No. 1
Case No. INT-G-15-02
lntermountain Gas Company
Page 7 of 1,2
IDAHO PUBLIC UTILITIES COMMISSlONIted- casiaiitt
I Rale Schedules
I s-mtt neviseo lElEh-t6l
'lncludes
Commodity Charge - First
Nexl
q!9q! ltS, ! (Pase 1 ol !)
200 therms per bill @ $s*+979' S03z8=31
Approvedlvffits Effectiveep*#e{5
lntermountain Gas Company Jean D. Jewell Secretary
Rate Schedule lS-C
SMALL COMMERICAL INTERRUPTIBLE SNOWMELT SERVICE
APPLICABILITY:
Applicable to any customer otherwise eligible to receive gas service under Rate Schedule GS-1 who has
added natural gas snowmelt equipment after 6/1/2010. The intended use of the snowmell equipment is to
melt snow and/or 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-C and will be
separalely and individually metered. All service hereunder is interruptible at lhe sole discretion of the
Company.
FACILITY REIMBURSETUENT CHARGE:
All new interruptible Snowmelt service customers are required to pay for lhe cost of the Snowmelt meter set
and olher relaled tacility and equipment costs, prior to the inslallation of the meter set. Any request to alter
the physical location of the meter set and related facilities ftom Company's initial design may be granted
provided, however, ihe Company can reasonably accommodate said relocation and Customer agrees to
pay all related c,osts
RATE:
Monthly minimum charge is the Customer Charge.
For billino periods endinq April throuoh November
Customer Charge - $2.00 per bill
200 therms per bill @ $e-7*979' I5037ZTI|
1,800 therms per bill @$0€9859" F05571T|Over 2,000 therms per bill @$€$#&t3- B-o-j366? I
PURCHASED GAS COST ADJUSTMENT:
This lariff is sublect to an ad.lustment for cosl of purchased gas as provrded for in the Company's Purchased
Gas Cost Adjustment Schedule
Temporary purchased gas cost adiustment of $(€€!,5,5ei lS(o-O13nn
Weighted average cosiof gas of $i3:3€n,e2 lso-i7%-fr.l
1,800 therms per bill @ $€$e859' m.69l3l
Over 2,000 therms per bill @ $otr+Ets- E_o6366il
For billino periods endino December throuqh March
Cuslomer Charge - $9.50 per bill
Commodily Charge - First
Next
I
Irssueouy lntermountain Gas Company
ley Mrchael P McGrath rrrle Director - Regulatory Affairs
I Eirectrve *p,r*+, zsr"s Iatole.I4HI
Exhibit No. 1
Case No. INT-G-15-02
lntermountain Gas Company
Page 8 of 12
IDAHO PUBLIC UTILITIES COMMISSIONl.P U C. Gas Tarifl
Rate Schedules
fiffy eqr'rtft n"r,."O @ Sltgq! !!9. 7 ( Page 1 of 2)
ApprovedwffiHott Effective
n+*++,+l+
Nanre
of Utrlrty lntermountain Gas Company
Block 1: First 250,000 therms per bill @ $Of€#96'
Block 2: Next 500,000 therms per bill @ $fr99ti7'
Block 3: Amount Over 750,000 therms per bill @ $'0ffi'-
Jean D. Jewell Secretary
Rate Schedule LV-1
LARGE VOLUME FIRM SALES SERVICE
AVAILABILITY:
Available al any mutually agreeable delivery point on the Company's distribution system to any existing
customer receiving servae under the Company's rate schedule LV-1 or any customer not previously served
under this schedule 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:
F6:a0mt
lF^334-4-zl
The above prices include weighted average cosl of gas e1 569a62'lSa:27@-' lncludes temporary purchased gas cost adjustment of $(0*+a5e1 F(0.02707)l" lncludes temporary purchased gas cost adjustment of $&31675 |Id.ooo1fl
PURCHASED GAS COST ADJUSTMENT:
This tariff is subJect to an adjustment for cost of purchased gas as provided for rn the Company's Purchased
Gas Cost Adjustnrenl Schedule.
SERVICE CONDITIONS:
All natural gas service hereunder is sublect lo lhe General Service Provisions of the Company's
Tariff, of which this Rate Schedule is a part.
The customer shall negotiate with the Company, a Maximum Daily Firnr Quanlity (MDFQ)
amount, which will be stated in and wrll be in effect throughout the term of the service
contract
ln the evenl the Customer requires daily usage in excess of the MDFQ, and sublect to the
availability of firm tnterstate transportation to serve lntermountain's system, all such usage
may be transported and billed under either secondary rate schedule T-3 or T-"1. The secondary
rale schedule to be used shall be predetermined by negotiat,on between lhe Cr-rslomer and
Company, and shall be rncluded in the service conlract All volumes transported under the
secondary rate schedule are subject to the provisions of the applicable rate schedule T-3 or T-
4.
Embedded in this service is the cost of purchased gas per the Company's PGA, ftrm interslate
pipeline reservation charges, and distribution system costs
tssued try lntermountain Gas Company
By Mrchael P McGrath Title: Director * Regulatory Affarrs
Eifectrve *6rnffits pcto5er f2o-Cl
Exhibit No. 1
Case No. INT-G-15-02
lntermountain Gas ComPanY
Page 9 of 12
IDAHO PUBLIC UTILITIES COMMISSlONIPUC Gaslarit{
Rate Schedules
Tq!!r Revlsed [f leventh I
Approved
Uare++araq+S
Effective
np+i++,+gf6
Namo
ol Utilrty
- ,Sheet No q lPqgg l of 2)
lntermountain Gas Company Jean D. Jewell Secretary
Rate Schedule T-3
INTERRUPTIBLE DISTRIBUTION TRANSPORTATION SERVICE
AVAILABILIW:
Available at any point on the Company's distribution system to any customer upon executlon of a one
year minimum written service contract.
MONTHLY RATE:
Block One:
Block Two:
Block Three
First
Next
Amount over
10O,OOO therms transporled @ SmSe+f' lso-ot.6n
50,000 therms transported @ $e+ae&7' l5d:dfoEl
150,000 therms transported @ $OffCaa' l$o-.mEl
'lncludes temporary purchased gas cost adjustment of $€footr ls(o-ooorrl
ANNUAL MINIMUM BILL:
The customer shall be subjecl 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 conlract to cover special
conditions.
PURCHASED GAS COST ADJUSTMENT:
This tarif, is subject to an adjustment for cost of purchased gas as provided for in the Company's Purchased
Gas Cost Ad.lustnrent Schedule
SERVICE CONDITIONS:
1. The Company, in its sole discretion, shall determine whether or not it has adequate capactty to
accommodale transportation of the customer's gas supply on the Company's distribution system.
2. All natural gas service hereunder is subiect to lhe General Service Provisions of the Company's
Tarifi, of which this Rate Schedule is a part.
3. lnterruptible Distribution Transportation Service may be made firm by a written agreement between
the parties if the customer has a dedicated line.
4 lf requesled by the Company, the customer expressly agrees to immediately curtarl or rnterrupt its
operations during periods of capacily constraints on the Company's distribution system
5 This service does not include the cost of the customer's gas supply or the rnterstate prpeline
capacity. The customer is responsible for procuring its own supply of natural gas and transportalion
to lnterrnountain's distribution syslem under this rate.
6 The customer underslands and agrees that the Company is nol responsible to deliver gas supplies
to the customer which have not been nominated and accepted for delivery by the tnterstate
pipeline
An existing LV-1, T-4, or T-5 custorner electing this schedule may concurrenlly utilize Rate
Schedule T-3 on the same or cont,guous properly.
rssued by: lntermountain Gas Company
ByMichaelP,McGrath_Tttle,Dtrector-RegulatoryAffarrs
Eflective *rpnfffi+S loctober 1, 2015 |
Exhibit No. 1
Case No. INT-G-15-02
lntermountain Gas Company
Page 10 of 12
IDAHO PUBLIC UTILITIES COMMISSIONl.P.U.C. Gas Tariff E
14 of
Rate Scheddes
Shaet No.8
.!,",1f* lntermountain Gas
Approved
fllarcffier2ef€
Effectivetpilffi
Jean D. Jewell Secrctary
Rate Schedule T-3
INTERRUPTIBLE DISTRIBUNON TRANSPORTATION SERVICE
(Continued)
BILLING ADJUSTf,EI{TS:
1. Any T-3 ciltstomer who lns exited the T-3 servbe at any time (including. but not limitad to, the
Exphation of the ontacl brm), will pay to lntormountain Gas Company, upon axitirq he T€
Barvice. all Purchased Gas Cost AdJustnent ('PGAI related costrs incuned on the cu$sner's
behaf nd pail by the customer durlng said contra6l pedod. Any T-3 cuslomer who has extted the
T-3 servlca uill haye refunded to them, upon exiting he T€ service. any PGA ,alatod cradits
attrifutable b 0n customer during said contrac't peiod.
tssued by: lntermountain Gas Gompany
By; Michael P. McGrath
Effective:2015
Title: Director - Regulatory Affairs
Exhibit No. 1
Case No. INT-G-15-02
lntermountain Gas Company
Page 11 of 12
IDAHO PUBLIC UTILITIES COMMISSION
ApprovedItffi+s Effectiveep*rffi+s
Jean D. Jewell Secretary
Rate Schedule T4
FIRM DISTRIBUTION ONLY TRANSPORTATION SERVICE
AVAILABILITY:
Available at any mutually agreeable delivery point on the Company's dislribution 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:
Commodily Charge:
Block One:
Block Two:
Block Three:
First
Next
Amount over
25O,OOO therms transported @ Se+6S83' lSoos???l
500.OOO therms transported @ $e+ar++' l-@tr|
750,000 therms transporled @ $Off6et' l-S:oo4-ss-l
PURCHASED GAS COST ADJUSTMENT:
This taritf is subject to an adjustment for cost of purchased gas as provided for in the Company's Purchased
Gas Cost Adjustment Schedule.
SERVICE CONDITIONS:
''l This service excludes the service and cost of firm interstate pipeline charges.
2 The customer is responsible for procuring its own supply oI 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 ts subject to the General Service Provisions of the Company's
Tariff, of which this Rate Schedule is a part
4 The customer shall nomtnale a Maximum Daily Firm Quantity (MDFO), which will be stated in the
contract and in effecl throughout the term of the service contract
5 An existing LV-1, T-3, or T-5 customer elecling this schedule may concurrently utilize Rate
Schedule T{ on the customer's sarne or contiguous property.
BILLING ADJUSTMENTS:
1. ln the event that total deliveries to any existing T-4 customerwithin the nrost recent three contract
periods mel or exceeded the 200,000 therm threshold, but the customer during the current conlract
period used less than the contract minimum of 200.000 thernrs, an addrtional amount shall be
billed The additional amount shall be calculaled by billing the defrcit usage below 200,000 therms
at the T-4 Block 1 rate. The customer's future eligrbility for the T-4 Rate Schedule nrill be
renegotiated with the Company
'lncludes temporary purchased gas cost adjustment of $€f,O00€ lTio-o,t 06i1
rssued by lntermountain Gas Company
By Michael P McGrath Title Direclor - Regulatory Affairs
Eifective Apc-++€{€ lo.t"b", lrf6-Gl
Exhibit No. 1
Case No. INT-G-15-02
lntermountain Gas Company
Page t2 of t2
IDAHO PUBLIC UTILITIES COMMISSIONI P U C Gas lariff
Rale Schedules
Hgih$+ Revised lruinttr I $h_ee! 1.,19 19 (Pese I cJ ?)
Gas Company
Approved
maremar+g+S
Effective
frerril-ffits
Name
of Ulrlity
Jean D. Jewell Secretarylntermountain
Rate Schedule T-5
FIRM DISTRIBUTION SERVICE WITH MAXIMUM DAILY DEMANDS
AVAILABILITY:
Available at any mutually agreeable delivery point on the Company's distribution system to any existing T-
5 customer whose daily contract demand on any given day meets or exceeds a predetermined level
agreed to by the customer and the Company upon execution of a one-year minimum written servrce
contract for lirm distribution service in excess of 200,000 therms per year.
MONTHLY RATE:
Firm Service
Demand Gharge:
Firm Daily Demand
Commodity Charge
For Firm Therms Transported
Rate Per Therm
$0 84253
$€€e2+9' l-Si-io11Tl
Over-Run Service
Commodity Charge.
For Therms Transported ln Excess Of MDFQ: $OS4S&' l-Si-j43rol
'lncludes temporary purchased gas cost adjustment of $,O€Og3& ls-00013r 1
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provrded for in the Company's Purchased
Gas Cosl Adjustment Schedule.
SERVICE CONDITIONS:
1. All natural gas service hereunder is sublect to lhe General Service Provisions of the Company's
Tariff, of whrch this Rate Schedule is a part
2. The customer shall nominate a Maximum Daily Firm Quantity (MDFO), which will be staled in and
will be in effect throughout the term of lhe service contract
3 The monthly Demand Charge will be equal to the MDFQ times the Firm Daily Demand rale. Frrm
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 rehef as warranted
4 The actual therm usage for lhe 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 lherms
5 All therms not billed at the commodity charge for firm therms transported rate wrll be billed
at the Overrun Service rate
I----'
I rssueci r,y lntermountain Gas Company
lBy Mrchael P Mccrath Title Direclor - Regulatory Affairs
i Eit".r,r" r+pn+-+,++s loctobaDdls I
EXHIBIT NO.2
CASE NO. INT.G.15.O2
INTERMOUNTAIN GAS COMPAI\Y
PROPOSED TARIFFS
(11 pages)
l.P.U.C. Gas Tariff
Rate Schedules
Forty-Ninth Revised SheetNo.0l (Page 1of 1)
Iiffi-, lntermountain Gas Gompany
Exhibit No. 2
Case No. INT-G-15-02
lntermountain Gas Company
Page 1 of 11
Rate Schedule RS-l
RESIDENTIAL SERVICE
APPLICABILlTY:
Applicable to any customer using natural gas for residential purposes, who does not haw both natural
gas water heating and natural gas space heating.
RATE:
Monthly minimum charge is the customer charge.
For billing periods ending April through Nowmber
Customer Charge - $2.50 per bill
Commodity Charge - $0.87267 per therm*
For billino periods endino December through March
Customer Charge - $6.50 per bill
Commodity Charge - $0.76011 per therm*
*lncludes:
Temporary purchased gas cost adjustment of $(0.00085)
Weighted average cost of gas of $0.32764
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment firr cost of purchased gas as provided for in the Company's
Purchased Gas Cost Adjustment Schedule.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the Company's Tarifi of
which this rate schedule is a part.
rssued by: lntermountain Gas Gom pany
By: Michael P. McGrath Title: Director - Regulatory Affairs
Effectiw: October 1, 2015
LP.U.C. Gas Tariff
Rate Schedules
Forty-Ninth Revised SheetNo. 02 (Pagel of 1)
iFffi-, lntermountain Gas Company
Rate Schedule RS-2
RESIDENTIAL SERVICE. SPACE AND WATER HEATING
APPLICABILITY:
Applicable to any customer using natural gas for residential purposes, which must include at a
minimum, both natural gas water heating and natural gas space heating.
RATE:
Monthly minimum charge is the customer charge.
For billing periods ending Aoril through Nowmber
Customer Charge - $2.50 per bill
Commodity Charge - $0.71185 per therm*
For billing oeriods ending December through March
Customer Charge - $6.50 per bill
Commodity Charge - $0.67822 per therm*
*lncludes:
Temporary purchased gas cost adjustment of $(0.00968)
Weighted a\erage cost of gas of $0.32764
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 Schedule.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Pror,isions of the Company's Tariff,
of which this rate schedule is a part.
tssuedby: lntermountain Gas Gom pany
By: Michael P. McGrath Tltle: Director - Regulatory Affairs
Effectiw: October 1, 2015
Exhibit No. 2
Case No. INT-G-15-02
lntermountain Gas Company
Page 2 of LL
l.P.U.C. Gas Tariff
Rate Schedules
First Revised Sheet No. 03 ( Page 1 ol 2\
)i,lli,, lntermountain Gas company
Exhibit No. 2
Case No. INT-G-15-02
lntermountain Gas Company
Page 3 of 11
Rate Schedule GS-1
GENERAL SERVICE
APPLICABILITY:
Applicable to customers whose requirements for natural gas do not exceed 2,000 therms per day, at any
point on the 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 wriften service contract.
RATE:
Monthly minimum charge is the customer charge.
For billinq periods endino Aoril throuoh November
Customer Charge - $2.00 per bill
Commodity Charge - First 200 therms per bill @ $0.72918-Next 1,800 therms per bill @ $0.70745.Over 2,000 therms per bill @ $0.68643.
For billino periods endinq December through March
Customer Charge - $9.50 per bill
Commodity Charge - First 200 therms per bill @ $0.67833.Next 1,800 therms per bill @ $0.65713.Over 2,000 therms per bill @ $0.63667.
*lncludes:
Temporary purchased gas cost adjustment of $(0.01323)
Weighted average cost of gas of $0.32764
tssued oy: lntermountain Gas Company
By: Michael P. McGrath Title: Director - Regulatory Affairs
Effective: October 1. 20'15
l.P.U.C. Gas Tariff
Rate Schedules
irst Revised Sheet No. 03 ( Page 2 ot 2\
Ii,lffi,, lntermountain Gas Company
Exhibit No. 2
Case No. INT-G-15-02
lntermountain Gas Company
Page 4 of 11
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 - $0.63667 per therm*
*lncludes:
Temporary purchased gas cost adjustment of $(0.01323)
Weighted average cost of gas of $0.32764
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 Schedule.
SERVIGE 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.
BILLING ADJUSTMENTS:
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 paid by the customer during the time the customer was using GS-
1 service. Any GS-1 customer who leaves the GS-1 service will have refunded to them, upon exiting
the GS-1 service, any excess gas commodity or transportation payments made by the customer
during the time they were a GS-1 customer.
tssued ny: lntermountain Gas Company
By: Michael P. McGrath Title: Director - Regulatory Affairs
Effective: October 1, 2015
l.P.U.C. Gas Tariff
Rate Schedules
Eiohth Revised Sheet No. 4 (Paoe 1 of
Name
of Utili lntermountain Gas Com
Exhibit No. 2
Case No. INT-G-15-02
lntermountain Gas Company
Page 5 of 11
Rate Schedule lS-R
RESIDENTIAL INTERRUPTIBLE SNOWMELT SERVICE
APPLICABILITY:
Applicable to any residential customer otherwise eligible to receive service under Rate Schedule RS-1 or
RS-2 who has added natural gas snowmelt equipment atter 61112010. The intended use of the snowmelt
equipment is to melt snow and/or 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 GHARGE:
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 sel 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 billinq periods endinq Aprilthrouqh November
Customer Charge - $2.50 per bill
Commodity Charge - $0.67 822 per therm*
For billinq oeriods ending December throuqh March
Customer Charge - $6.50 per bill
Commodity Charge - $0.67822 per therm*
*lncludes:
Temporary purchased gas cost adjustment of $(0.00968)
Weighted average cost of gas of $0.32764
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 Schedule.
SERV!CE 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.
rssued by: lntermOuntain
ey:Michael P. McGrath
Effective: October 1, 2015
Gas Company
Titte: Director - Regulatory Affairs
l.P.U.C. Gas Tariff
Rate SchedulesRevised Sheet No. 5 (Paqe 1
Name
of Util lntermountain Gas
Exhibit No. 2
Case No. INT-G-15-02
lntermountain Gas Company
Page 6 of 11
Rate Schedule lS-C
SMALL COMMERICAL INTERRUPTIBLE SNOWMELT SERVICE
APPL!CABILITY:
Applicable to any customer otherwise eligible to receive gas service under Rate Schedule GS-1 who has
added natural gas snowmelt equipment after 61112010. The intended use of the snowmelt equipment is to
melt snow and/or 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-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 billinq oeriods endinq Aprilthrouqh November
Customer Charge - $2.00 per bill
Commodity Charge -200 therms per bill @ $0.67833.
1,800 therms per bill @ $0.65713"
2,000 therms per bill @ $0.63667"
For billinq oeriods endino December through March
Customer Charge - $9.50 per bill
Commodity Charge - First 200 therms per bill @ $0.67833.Next 1,800 therms per bill @ $0.65713.Over 2,000 therms per bill @ $0.63667.
*lncludes:
Temporary purchased gas cost adjustment of $(0.01323)
Weighted average cost of gas of $0.32764
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 Schedule.
rssued by: lntermountain Gas
sy:Michael P. McGrath Title:
Effective: October 1, 2015
Company
Director - Regulatory Affairs
First
Next
Over
LP.U.C. Gas Tariff
Rate SchedulesRevised Sheet No. 7 (Pase 1
Namel,'r"jii,,, lntermountain Gas Compa
Exhibit No. 2
Case No. INT-G-15-02
lntermountain Gas Company
Page 7 of 11
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 customer not previously served
under this schedule 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:
Block 1: First
Block 2: Next
Block 3: Amount Over
250,000 therms per bill @ $0.49512.
500,000 therms per bill @ $0.45663.
750,000 therms per bill @ $0.33442".
The above prices include weighted average cost of gas of $0.32764* lncludes temporary purchased gas cost adjustment of $(0.02707)** lncludes temporary purchased gas cost adjustment of $0.00017
PURGHASED 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 Schedule.
SERVICE CONDITIONS:
1. All natural gas service hereunder is subject to the General Service Provisions of the Company's
Tariff, of which this Rate Schedule is a part.
2. The customer shall negotiate with the Company, a Maximum Daily Firm Quantity (MDFO)
amount, which will be stated in and will be in effect throughout the term of the service
contract.
ln the event the Customer requires daily usage in excess of the MDFQ, and subject to the
availability of firm interstate transportation to serve lntermountain's system, all such usage
may be transported and billed under either secondary rate schedule T-3 or T-4. The secondary
rate schedule to be used shall be predetermined by negotiation between the Customer and
Company, and shall be included in the service contract. All volumes transported under the
secondary rate schedule are subject to the provisions of the applicable rate schedule T-3 or T-
4.
3. Embedded in this service is the cost of purchased gas per the Company's PGA, firm interstate
pipeline reservation charges, and distribution system costs.
tssued oy: lntermountain Gas Company
By: Michael P. McGrath Title: Director - Regulatory Affairs
Effective: October 1, 2015
l.P.U.C. Gas Tariff
Rate Schedules
Eleventh Revised Sheet No. 8 ( Paoe 1 ol
Ii,lffi,* lntermountain Gas Com
Exhibit No. 2
Case No. INT-G-15-02
lntermountain Gas Company
Page 8 of 11
Rate Schedule T-3
INTERRUPTIBLE DISTRIBUTION TRANSPORTATION SERVICE
AVAILABILITY:
Available at any point on the Company's distribution system to any customer upon execution of a one
year minimum written service contract.
MONTHLY RATE:
Block One:
Block Two:
Block Three:
First
Next
Amount over
100,000 therms transported @ $0.05465.
50,000 therms transported @ $0.02205.
150,000 therms transported @ $0.00792.
*lncludes temporary purchased gas cost adjustment of $(0.00095)
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 Schedule.
SERV!CE GONDITIONS:
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. lnterruptible Distribution Transportation Service may be made firm by a written agreement between
the parties if the customer has a dedicated line.
4. lf requested by the Company, the customer expressly agrees to immediately curtail or interrupt its
operations during periods of capacity constraints on the Company's 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 lntermountain'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.
tssued oy: lntermountain Gas Company
By: Michael P. McGrath Title: Director - Regulatory Affairs
Effective: October 1, 2015
l.P.U.C. Gas Tariff
Rate Schedules
Third Revised Sheet No.8 ( Paqe 2 of
lntermountain Gas GName
of Utili
Exhibit No. 2
Case No. INT-G-15-02
lntermountain Gas Company
Page 9 of 11
Rate Schedule T-3
INTERRUPTIBLE DISTRIBUTION TRANSPORTATION SERVICE
(Continued)
BILLING ADJUSTMENTS:
'1. Any T-3 customer who has exited the T-3 service at any time (including, but not limited to, the
expiration of the contract term), will pay to lntermountain Gas Company, upon exiting the T-3
service, all Purchased Gas Cost Adjustment ("PGA") related costs incurred on the customer's
behalf not paid by the customer during said contract period. Any T-3 customer who has exited the
T-3 service will have refunded to them, upon exiting the T-3 service, any PGA related credits
attributable to the customer during said contract period.
lssued oy: lntermountain Gas Company
By: Michael P. McGrath Title: Director - Regulatory Affairs
Effective: October 1, 2015
l.P.U.C. Gas Tariff
Rate Schedules
Tenth Revised Sheet No.9 ( Paqe 1 of
lntermountain Gas CName
of Util
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 @ $0.05777.
Block Two: Next 500,000 therms transported @ $0.0'1928.
Block Three: Amount over 750,000 therms transported @ $0.00455.
*lncludes temporary purchased gas cost adjustment of $(0.00206)
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 Schedule.
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 (MDFO), 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.
B!LLING ADJUSTMENTS:
1. ln the event that total deliveries to any existing T-4 customer within the most recent three contract
periods met or exceeded the 200,000 therm threshold, but the customer during the current contract
period used less than the contract minimum of 200,000 therms, an additional amount shall be
billed. The additional amount shall be calculated by billing the deficit usage below 200,000 therms
at the T-4 Block 1 rate. The customer's future eligibility for the T-4 Rate Schedule will be
renegotiated with the Company.
tssued oy' lntermountain Gas Company
By: Michael P. McGrath Title: Director - Regulatory Affairs
Effective: October 1. 2015
Exhibit No. 2
Case No. INT-G-15-02
lntermountain Gas Company
Page 10 of 11
l.P.U.C. Gas Tariff
Rate Schedules
Ninth Revised Sheet No. 10 (Paoe 1 of
lntermountain Gas ComName
of Utili
MONTHLY RATE:
Firm Service
Demand Charge:
Firm Daily Demand
Commodity Charge:
For Firm Therms Transported
Over-Run Service
Commodity Charge:
For Therms Transported ln Excess Of MDFQ:
Exhibit No. 2
Case No. INT-G-15-02
lntermountain Gas Company
Page 11 of tl
Rate Schedule T-5
FIRM DISTRIBUTION SERVICE WITH MAXIMUM DAILY DEMANDS
AVAILABILITY:
Available at any mutually agreeable delivery point on the Company's distribution system to any existing T-
5 customer whose daily contract demand on any given day meets or exceeds a predetermined level
agreed to by the customer and the Company upon execution of a one-year minimum written service
contract for firm distribution service in excess of 200,000 therms per year.
Rate Per Therm
$0.842s3
$0.00111.
$0.04370.
*lncludes temporary purchased gas cost adjustment of $(0.00135)
PURGHASED 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 Schedule.
SERVICE CONDIT!ONS:
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.
The customer shall nominate a Maximum Daily Firm Quantity (MDFO), which will be stated in and
will be in effect throughout the term of the service contract.
The monthly Demand Charge will be equal to the MDFQ times the Firm Daily Demand rate. Firm
demand relief will be afforded to those T-5 customers paying both demand and commodity charges
for gas when, in the Company's judgment, such relief is warranted.
The actual therm usage for the month or the MDFQ times the number of days in the billing month,
whichever is less, will be billed at the applicable commodity charge for firm therms.
All therms not billed at the commodity charge for firm therms transported rate will be billed
at the Overrun Service rate.
tssued by: lntermountain Gas Company
By: Michael P. McGrath Title: Director - Regulatory Affairs
Effective: October 1, 2015
3.
4.
5.
EXHIBIT NO.3
CASE NO. INT.G.15-02
INTERMOUNTAIN GAS COMPAI\Y
PERTINENT EXCERPTS PERTAINING TO INTERSTATE PIPELINES AND RELATED
FACILITIES
(37 pages)
Exhibit No. 3
Case No. INT-G-15-02
lntermountain Gas Company
Page 1 of 37
NORTHWEST PIPELINE LLC
(10 pages)
Exhibit No.3
Case No. INT-G-15-02
lntermountain Gas Company
Page 2 of 37
2ot2t221-3o40 FERC PDF (Unofficial) t2/20/2072
FEDERAL ENERGY REGULATORY COMMISSION
WASHINGTON, D.C. 20426
OFFICE OF ENERGY MARKET REGULATION
In Reply Refer To:
Letter Order Pursuant to $ 375.307
Northwest Pipeline GP
Docket No. RP I 2-490-00 I
Issued: December 20, 2012
Northwest Pipeline GP
P.O. Box 58900
Salt Lake city, UT 84158-0900
Attention: Ms. Pam Bames
Manager, Certificates and Tariffs
Reference: Filing to Place Settlement Rates into Effect
Dear Ms. Barnes:
On November 27,2012, Northwest Pipeline GP (Northwest) filed revised tariff
recordsr to comply with an April26,2012, Commission Letter Order approving a rate
settlement filed by Northwest in Docket No. RPl2-490-000 (April 2012 order).2 The
April2012 order directed Nortlrwest to file tariff records consistent with thepro forma
tariff records set forth in Appendix F of the settlement, to be effective January 1,2013.
The tariff records identified in the Appendix are accepted effective January 1,2013, in
compliance with the April20l2 order.
Public notice of the filing was issued on November 28,2012, allowing for protests
to be filed as provided in section 154.210 of the Commission's regulations. No protests
or adverse conrments were filed.
This acceptance for filing shall not be construed as a waiver of the requirements of
section 7 of the Natural Gas Act, as amended; nor shall it be construed as constituting
approval of the referenced filing or of any rate, charge, classification, or any rule,
regulation, or practice affecting such rate or service contained in your tariff; nor shall
I See Appendix for identification of tariff records.
z Northwest Pipeline GP,l39 FERC fl 61,071 (2012).
Exhibit No.3
Case No. INT-G-15-02
lntermountain Gas Company
Page 3 of 37
20L21220-3040 FERC PDF (Unofficial\ 72/20/20L2
Docket No. RPI 2-490-001
such acceptance be deemed as recognition of any claimed contractual right or obligation
associated therewith; and such acceptance is without prejudice to any findings or orders
which have been or may hereafter be made by the Commission in any proceeding now
pending or hereafter instituted by or against your company.
This order constitutes final agency action. Requests for rehearing by the
Commission may be filed within 30 days of the date of issuance of this order, pursuant to
l8 c.F.R. $ 38s.713 (2012).
Sincerely,
Nils Nichols, Director
Division of Pipeline Regulation
.,
Exhibit No. 3
Case No. INT-G-15-02
lntermountain Gas Company
Page 4 of 37
20L21,220-3O40 FERC PDF (Unofficiall L2/20/2OL2
DocketNo. Ml2-490-001
Northwest Pipeline GP
Fifth Revised Volume No. I
FERC NGA Gas Tariff
Tariff Records Accepted Effective January 1,2013
SheetNo. 5. Statement of Rates:TF-I. TF-2. TI-1" TFL-l and TIL-1.4.0.0
Sheet No. 5-B. Statement of Rates: TF- l. TF-2" TI- I . TFL- l and TIL- 1. 3.0.0
Sheet No. 5-C. Statement of Rates: TF-1. TF-2. Tl-1. TFL-l and TIL-1. 3.0.0
Sheet No. 5-D. Statement of Rates: TF-1. TF-2. TI-1. TFL-l and TIL-1. 2.0.0
SheetNo.6. Statement of Rates: DEX-I and PAL.3.0.0
Sheet No. 7. Statement of Rates: SGS-2F and SGS-21. 4.0.0
SheetNo. 8. Statement of Rates: LS-1.3.0.0
Sheet No. 8-A" Statement of Rates: LS-2F and LS-21. 3.0.0
-3-
Appendix
Exhibit No. 3
Case No.lNT-G-15-02
lntermountain Gas Company
Page 5 of 37
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. I
Fifth Revised Sheet No. 5
Superseding
Fourth Revised Sheet No. 5
STATEMENT OF RATES
Effective Rates Appficable to
Rate Schedul-es TF-1, TE-2, 'II-1, TFL-1 and TIL-1(Do11ars per Dth)
Rate Schedule and
Type of Rate
Rate Schedule TF-1 (4) (5)
Reservation
(Large Customer)
System-V{ide
15 Year Evergreen Exp.
25 Year Evergreen Exp.
Volumetric (2)
(Large Customer)
System-Wide
15 Year Evergreen Exp.
25 Year Evergreen Exp.
(Sma11 Customer) (6)
Schedul-ed Overrun (2)
Rate Schedule TF-2 (4) (5)
Reservation
Volumetric
Scheduled Daily Overrun
Annuaf Overrun
Rate Schedule T1-1 (2)
Volumetric (7)
Rate Schedul,e TFL-1 (4) (5)
Reservation
Volumetric (2)
Scheduled Overrun (2)
Rate Schedule TIL-1 (2)
Volumetric
BaseTarlff Rate (1), (3)
Mini-mum Maximum
.00000 .41000.00000 .36263.00000 .34234
. 008 13 .03000.00813 .00813.00813 .00813
.00813 .12755
.00813 . 44000
.00000 .41000.00813 .03000.00813 .44000.00813 .44000
.00813 .44000
Exhibit No.3
Case No. INT-G-15-02
lntermountain Gas Company
Page 6 of 37
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. I
Fifth Revised Sheet No. 7
Superseding
Fourth Revised Sheet No. 7
STATEMENT OE RATES (Contlnued)
Effective Rates Applicable to Rate Schedufes SGS-28 and SGS-2I
(Dollars per Dth)
Rate Schedule and
Type of Rate
BaSe
Tariff Rate (L)Minimum Maximum
Rate Schedule SGS-2F (2) (3) (4)
Demand Charge
Pre-Expansion Shipper
Expansion Shipper
Capacity Demand Charge
Pre-Expansion Shipper
Expansion Shipper
Volumetric Bid Rates
Withdrawaf Charge
Pre-Expansion Shipper
Expansion Shipper
Storaqe Charge
Pre-Expansion Shipper
Expansion Shlpper
Rate Schedule SGS-2I
Vofumetric
(s)
0. 00000
0 .00000
0 .00000
0 .00000
0.00000
0.00000
0 .00000
0 .00000
0.00000
0.01s62
0.04056
0.00057
0.00348
0.01562
0.04056
0 .00057
0.00348
0.00224
Footnotes(1) Shippers receiving service
furnrsh fuel reimbursement
No. 14 .
under thesein-kind at
rate schedules are required
the rates specified on Sheet
to
Exhibit No. 3
Case No. INT-G-15-02
lntermountain Gas Company
?age7 of 37
Northwest Pipeline LLC
FERC Gas Tarilf
Fifth Revised Volume No. I
Fifth Revised Sheet No.8-A
Superseding
Fourth Revised Sheet No. 8-A
STATEMENT OF RATES (Continued)
Effective Rates Appficable to Rate Schedules LS-2E and LS-2I
(Doll-ars per Dth)
Rate Schedule and
Type of Rate
Rate Schedule LS-2E (3)
Demand Charge (2)
Capacity Demand Charge (2)
Volumetric Bid Rates
Vaporization Demand-Related Charge (2)
Storage Capacity Charge (2)
Liquefaction
Vaporization
Rate Schedule LS-2I
Volumetric
Liquefaction
Vaporization
BaseTariff Rate (1)
Minimum Maximum
0 .00000
0 .00000
0. 00000
0 .00000
0.90855
0.03386
o.02581
0.00331
o -02581
0 .00331
0.90855
0.03386
0.00000 0.o0662
0.90Bss 0.908550.03386 0.03386
Footnotes
(1) Shippers recelving service under these rate schedules are required tofurnish fuel reimbursement in-kind at the rates specified on Sheet No.
14.
(2) Rates are daily rates computed on the basis of 365 days per year,
except that rates for leap years are computed on the basis of 366 days.
(3) Rates are also applicabl-e to capacity release service except for short-
term capacity refease transactions for a term of one year or less that
take effect on or before one year from the date on which Transporter is
notified of the release, which are not subject to the stated Maxlmum
Base Tariff Rate. (Section 22 of the General- Terms and Conditions
describes how bids for capacity release wilf be evaluated. ) The
Vaporj-zatj-on Demand-Related Charge and Storage Capacity Charge are
applicable to Repfacement Shippers bidding for capacity released on a
one-part vofumetric bid basis.
Exhibit No.3
Case No. INT-G-15-02
lntermountain Gas Company
Page 8 of 37
Northwest Pipeline LLC
FERC Gas Tariff Fourteenth Revised Sheet No. 14
Fifth Revised Volume No. I Superseding
Thirteenth Revised Sheet No. 14
STATEMENT OF PUEL USE REQUIREMENTS TACTORS
FOR REIMBURSEMENT OF EUEL USE
Applicable to Transportation Service Rendered Under
Rate Schedules Contained in this Tarlff, Eifth Revised Volume No. 1
The rates set forth on Sheet Nos- 5, 6, J, B and B-A are exclusive of
fuel use requirements. Shipper shalf reimburse Transporter in-kind for its
fuel use requirements in accordance with Section 14 of the Generaf Terms and
Conditions contained herein.
The fuef use reimbursement furnished by Shlppers shafl- be as follows
for the applicable Rate Schedules included in this Tariff:
Rate Schedules TF-1, 'IF-2, TI-1, and DEx-l I.l7Z
Rate Schedufe TF-1 - Evergreen Expansion
Incrementa.I Surcharge (1) 0.50?
Rate Schedul-e TPL-1
Rate Schedu]e TIL-1
Rate Schedu.Ies SGS-2F and SGS-2I 0.402
Rate Schedul-es LS-1, LS-2E, LS-3F and LS-2I
Liquefaction I .05%
Vaporization 0. 85?
Rate Schedufe LD-4I
Liquefactlon I .05?
The fuel use factors set forth above shal-f be calculated and adjusted
as expJ-ained in Section 14 of the General Terms and Conditions. Fuef
reimbursement quantities to be supplled by Shippers to Transporter shafl 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 rnjection, Pl-ymouth Iiquefaction, P1\mouth vaporization, or
for deferred exchange, as appficabfe.
Eootnote
(1) In addrtion Lo the Rate Schedufe TE-1 fuef use requirements factor, the
Evergreen Expansion fncremental Surcharge will apply to the quantity of gas
nominated for receipt at the Sumas, SIPI or Pacific Pool recelpt points under
Evergreen Expansion service agreements.
Exhibit No. 3
Case No. INT-G-15-02
lntermountain Gas Company
Page 9 of 37
wnr{fli;9tr
Norlhrvest PlPoline
P.O' BuxOr$osalrt6k ctly, uT t1t68.o9c0
Phom: t80l)68{-71rCFAx: (aor)6ra-7076
MEMORANDUM OF UNDERSTANDING
This Memorandum of Underelanding ('Memorandum') ie mada and sntered lnlo on Ju[y 4.2-,
2015, by and belureen Nothwest Pipellne LLC ("Northwesf' or ''Transportef), and
lntermountaln Gas Company (nlntormountain'or"Shippor")i Northwesl and lntsrmountaln are
sometlmee referred lo individually as'Partf and collectively as the'Partiee,"
RECITALS:
A. Northwest owns and oparates an lnlereta(a natural gas transmission syslom subJoct to
lho furlsdlollon of lho Fedoral Energy Rogulatory Comntlseion ('FERC");
B. lntormountain doskes to acqulre 378,900 Dlh of Slorage Capeclty and 41,975 Dlh/d of
Storago Damand at Northwest'e Plymouth LNG storage facillty; and
C. lntumounlaln dsslres to aoqulre TF-2 elorage redelfuary lranoporlation eervloe from
Plymoulh lo the dallvery pcints lletod on lntermountaln's TF-1 Conlract No. 100004 with an
Annual Contracl Quantity of 378,900 Dth,
NOW, THEREFORE, in conslderation of the mulual covenants and agreemente herein
containod, and aubJecl to all of lhe lernrs, condltlone, and provisions haroin set forth, Northwest
and lntermountain do ltereby momorialize thelr underetanding as followe:
ART]CLE I: CAPAGIW COI1IIMITMENTS
1. On or before August 15,2015,lntormounlaln will submit a blndlng bid for Rate Schedule
LS.2F service lrom Northvrest's Plymouth LNG storage faclllly consisting of 378,900 Dth
of Storage Capacity and 41,975 Dltr/d oI Storage Demand at the rnaximum tariff rates
(aa lhey may chango frorn time to time).
a. The primary term effective date will be the date that Northwest posts that its
Plymouih LNG storage capacities have been restored back to their fultdesign
capacitiee.
b, The prlmary torm ond date will be March 31,2023.
c. The bid wlll oontaln tho following Noti-Conforming Provieion: The RP12-490
Plyrnouth LNG firm annual demand bllling deterrnlnante of 111,434,500 (305,300
Dtrud X 365 days) and tlrm annual capaclty bllling detormlnant$ of 871,620,000
(2,3B8,000 Dth X 365 days) will be used in derivlng ths reoourso rates for flrm
Plymouth LNG servicee that become effecliue on or belore January 1 ,2018,
2 Within five (5) liusiness Days of lnlermountain submillirrg a request for ilre capaclty
speclfled in Article l, Paragraph 1 abovo, Northwest wlll poot such capacity for
compolitlve bld with lntennounlain ag tho pre-anangod shipper. The capacity will bo
r,, C!;r.ts $t/ - Srit t.rJo Crl, U$ t$ot
Exhibit No. 3
Case No. INT-G-15-02
lntermountain Gas Company
Page 10 of 37
awarded pursuant to Section 25 of Northwest's Tariff. Northwest will calculate the
lncremental Economic Value of any competilive bids according to the net present value
of bids for a porlion or all of the posted capacity, and may aggregate bids for differenl
portions of capacity frorn multiple shippers if doing so would produce a higher net
present value. lncluded in the posting will be a provision that will allow the winning
Shipper to request up to 41,975 Dth/d ol TF-2 capacity from Plymouth.
3 Within live (5) Business Days of awarding the capacity pursuant to Article l, Paragraph 2
above, provided the capacity is awarded to lntermountain, lnlermountain will, at
Norlhwest's sole discretion, submit a request for Rate Schedule TF-2 capacity with a
Transportation Contract Demand equal to the Storage Demand and an Annual Contract
Quantity equal to the Storage Capacity that lntermountain is awarded pursuant to Article
l, Paragraph 2; or (2) accept a permanent release with similar terms frorn a third party
that Nodhwest will identify.
a. The primary term effective date will be the date that Norlhwest posts that
its Plymouth LNG storage capacities have been restored back to their full
design capacities.
b. The primary term end date will be March 31, 2023.
ARTICLE ll: TERMINATION
1. This MOU will terminate upon the final execution of all the contracts and {uture
amendments contemplated in this MOU.
ARTICLE lll: NOTIFICATIONS AND COMMUNICATIONS
Except as otherwise provided herein, any notice contemplated or required by this
Memorandum will be in writing, and will be considered duly delivered when sent by registered or
certified mail, or by facsimile, to the appropriate Party at the appropriale address or phone
number, as applicable, set forlh below, or at such other address or phone number as a Party
may from time to time designate by express written notice.
Norlhwest Pipeline LLC
295 Chipeta Way
Salt Lake City, UT 84108
Phone.: [phone]
Altn: Mike Rasmuson
lntermounlaln Gas Company
400 North 4th Street
Bismarck, ND 58501
Phone No: [phone]
Attn: Bob Morman
ARTICLE IV: ENTIRE AGREEMENT
This Memorandum contains lhe entire agreement between Northwest and lntermountain with
respect to the subject matter hereof, and supersedes any and ail prior agreements,
understandings and commitments, whether oral or written, concerning the subject matter hereof.
No amendments to or modifications of this Memorandum will be effective unless agreed upon in
a written inslrument executed by Northwest and lntermountain, which expressly refers to this
Memorandum.
ARTICLE V: GOVERNING LAW AND DISPUTE RESOLUTION
l9i (:tuFlr lvr'i. Sr't I :(. C{!. !:lrh !ll0l
Exhibit No.3
Case No. INT-G-15-02
lntermountain Gas Company
Page 11 of 37
l. The construclion, lnlerpretatlon, and enforcement of thls Mamorandum wlll be govamed
by the laws of the State of Utah, notwllhstandlng any conlfct of law rule, uvtildr would
refer any matte to the latw of another furlsdlctlon.
2. ln the etsnt of atry dlspule arlslng oul of or relaling to thle Memoranchrm whlch lhe
Partles have been unablo to seltlo wllt{n ten (10} daya after lhe dleputa aroee, lhen
elther Party may rsfer the dlspute to a meeffng of aenlor managemenl ln wlrlch case
each Parly shall nomhate a senlor officer of lle managoment to msot at a mulually
agreed tlme and plme nd lator lhan lhlrly (30) days afterlhe dhpule arose to attenrpt to
r€oolve the dhpute. lf a resoludon le not reached withh slxty (60) dap after ttre meellng
of $nlor offfoere, then eilhsr Party mey refer the dlspde to medstlon. The parllee wlll
mulually selocl a medlato6 provHed that lf the prtles cannot mutually agm06 to a
medlalor, the msdator ehafl bo tte Drootor of FERCb Offloe of Dbpule Reeolullon
Sorvloos or suo€8sor poslbn to the extonl ll le wllllng lo serve ln lhal capaclty.
ARTICLE Vl: GOUNTERPARTS
Thle iromorandum may be executed ln one or more oounlorparle (dellvsry of whlch may be
made by facehnlle). each of wtrlch eha[ be deemed an orlglnal but all of wtrloh together shall
constitute one and lhe eflne.
lN WTNESS WHEREOF,Ihe Partlos hereto have causod thle Memorandum lo be duly
execuled as o, the day and yearllot abow wdtten.
NORTHWEST PIPELINE LLCW--
Mlke Rasmuson
Dhec{or Markellru SeMces
EVP Cornblned Ullllly Support
lfrCl*d rr?-tl lI.Cin tnl AlGl
Exhibit No. 3
Case No. INT-G-15-02
lntermountain Gas Company
Page L2 ol 37
NOVA GAS TRANSMISSION LTD.
(4 pages)
Exhibit No. 3
Case No. INT-G-15-02
lntermountain Gas Company
Page 13 of 37
o TransCanada
ln business to deliver
450- I Street S.W.
Calgary, Alberra T2P 5Hl
Phone: [phone]
Fax: [phone]
Email: [e-mail]
July 29,2015 Filed Electronically
National Energy Board
517 Tenth Avenue SW
Calgary, Alberta T2R 0A8
Attention: Ms. Sheri Young, Secretary of the Board
Dear Ms. Young:
Re: NOVA Gas Transmission Ltd. (NGTL)
Gas Transportation Tariff (Tariff)
Updated Attachments I and 2 to the Table of Final 2015 Rates, Tolls and Charges
(Final20l5 Rates)
NGTL attaches for filing with the Board pursuant to section 60(l)(a) of the National Energt
Boord Act an updated Attachment I (Receipt Point Specific Rates) and Attachment 2 (Delivery
Point Specific Rates) to the Table of Final 2015 Rates (Table) for the Tariff, effective August l,
2015.
The updates to Attachments I and 2 to the Table of Final 2015 Rates are required to reflect meter
stations expected to go into service shortly.
Attachment I to the Table has been updated to include new receipt points at the Ansell South
receipt meter station, Cynthia receipt meter station, Elk River Southwest receipt meter station,
Livingstone Creek receipt meter station, Minnow Lake West receipt meter station and
Yellowhead receipt meter station. The 2015 FT-R and IT-R rates for the stations are provided in
the following table:
Exhibit No.3
Case No. INT-G-15-02
lntermountain Gas Company
Page L4 of 37
luly 29 2015
Ms. S. Young
Page 2 of 2
Attachment 2 to the Table has been updated to include the Scotford Hydrogen Sales APN
delivery meter station, Alder Flats South No. 2 Sales delivery point at the existing Alder Flats
South No. 2 receipt meler station, the Ricinus Sales delivery point at the existing Ricinus receipt
rneter station and the Virginia Hill No. 2 Sales delivery point at the existing Virginia Hills
receipt meter station. The 2015 FT-D and IT-D rates for the stations are provided in the
following table:
The rates were determined in accordance with NGTL's current rate design rnethodology
approved by the Board in Reasons for Decision RHW-l-2010 and Order TG-04-2010 on
August 12,2010.
If the Board requires additional information regarding this filing, please contact Mark Manning
by phone at (a03) 920-6098 or by ernail at [e-mail].
Yours truly,
NOVA Gas Transmission Ltd.
Originol signed by Mark Manningfor
Bernard Pelletier
Director, Tolls and Tariffs
Regulatory Affairs
Attachments
cc: l'l-[rP
NG't'L System Shippcrs
Station
Number Station Name Legal Description
FT-R Demand Rate
($/103m3/month)
lT-R Rate
(g/1o3mr)
Page No. on
Attachment 1
5154 ANSELL SOUTH 15-02-053-18-W5 154.60 5.85 1
5166 CYNTHIA NW-'t0-049-11-W5 139.83 5.29 5
5165 ELK RIVER SOUTHWEST 11-03-047-'14-W5 139.83 5.29 6
5144 LIVINGSTONE CREEK NW-26-078-18-W6 294.O3 11.12 10
5170 MINNOW LAKE WEST NW-09-052-17-W5 161.75 6.12 11
5'r64 YELLOWHEAD 12-02-U6-14-W5 139.83 5.29 '18
Station
Number Station Name Legal Description
FT-D Demand Rate
($/GJ/month)
lT-D Rate
($/GJ)
Page No. on
Attachment 2
3297 ALDER FLATS SOUTH NO
2 SALES 10-09-045-08-W5 4.55 0.1646 1
3298 RICINUS SALES NW-02-037-10-W5 4.55 0.1646 4
3112s SCOTFORD HYDROGEN
SALES APN 06-31-055-2'1-W4 4.55 0.1646 4
3296 VIRGINIA HILLS NO 2
SALES 09-'17-064-13-W5 4.55 0.1646 5
Exhibit No. 3
Case No. INT-G-15-02
lntermountain Gas Company
Page 15 of 37
Table of Rates. Tolls and ChargesNOVA Gas'I'ransmission [,td.
of
Sen'ice Rates, Tolls and Oharges
| - Rate Schedule FT-R Refer to Attachment "1" for applicable FT-R Dcmand Rate per month based on a three
year term (Price Point "B") & Surcharge for each Receipt Point
Averas,e Firm Service Receiot Price (AFSRP)S 225.731103m3
2. Rate Schedule F'l -RN Refer to Attachment "l" for applicable FT-RN Demand Rate per month & Surcharge
for each Receipt Point
3. Rate Schedule FI'-D I Refer to Attachment "2" for applicable FT-D Demand Rate per month based on a one
year term (Price Point'.Z") & Surcharge for each Group I or Group 2 Delivery Point
Average II|-D Demand Rate for Croup I Delivery Points
FT-D Demand Rate for Group 2 Delivery Points
FT-D Demand Rate lor Group 3 Delivery Points
$ 5.32lGJ
$ 4.55/GJ
$ 5.46lGJ
4. Rate Schedule S'[FT STFT Bid Price : Minimum of I 007o of the applicable FT-D Demand Rate based on a
one year term (Price Point "Z") for each Group I Delivery Point
5. Rate Schedule FT-DW FT-DW Bid Price : Minimurn of I 25% of the applicable F'I-D Demand Rate based on
a three vear term (Price Point "Y") for each Group I Deliverv Point
6. Rate Schedule Irl-P I Refer to Attachment "3" fbr aoolicable FT-P Demand Rate oer month
7. Rate Schedule I-RS Contract I'enn
l-5 years
20 vears
Elfective LRS Rate ($/10'rn'/day)
11.s2
'7.66
8. Rate Schedule LRS-3 LRS-3 Demand Rate per rnonth $ I 29.55/ I 0'rn
9. Rate Schedule Il--R Refer to Attachment "l" for applicable IT-R Rate for each Receipt Poinl
10. Rate Schedule l'l'-D I Refer to Attachment "2" for aoolicable IT-D Rate lbr each Deliverv Point
I l. Rate Schedule FCS The FCS Charge is determined in accordance rvith Attachment "1" to the applicable
Schedule of Service
12. Rate Schedule PT Schedule No.
9009-0I00r-r
PT Ratc
660.00/d
PT Cas Rate
50.0 tohr/d$
13. Rate Schedule OS Sch
201
201
201
201
201
201
201
201
)o1
edule No. Charec5659057 S 878.00 /rnonth5659060 $ 1347.00 /rnonth565'1921 $ 12.00 /month5657920 $ 122.00 /month5657919 $ 67.00 /month5657918 $ 18.00 /rnonth5657917 $ 303.00 /month14757'/2 $ 9.250.00 /rnonth5657S15 S 175900 /monlh
2003004522 Aonlicable I'l -R and IT-D Rate
20lL476052 /
201 l4'76054
S 0.1496 / G.l subiect to
S 717.000.00 Minirnum Annual Chars.e
20|475056 / 2011476092 /
)ot 14760\(\
s
q
0.095 / GJ and
I OO0 O0 / rnnnth
14. Rate Schedule CO2 Tier
I
2
-l
CO: Rate ($/l03nrr)
542.06
428.98
279.71
15. Monthly Abandonment
Surcharge r $ 12.45/l0rmr/rnonth $0.33/GJ/nronth
16. Daily Abandonrnenl
Surcharse l $ 0.41ll03rnr/day $0.0108/CJ/da1'
201 I 4'7 6092. are subjecr to the ATCO Pi peli nes Fr anchi se F'ees ptrrsuanl to paragraph I 5. I 3 of the Gcncral l enn s and Conditions.
2. l\lonthlyAbandonmerlSurchargeapplicablctoRate SchedulesFT-R.FT-D.F1:P.F1--RN.FT-DW.Sl'l:l.andLRS-3.
3. Daill' Abandonntent Snrcl)arge applicable to Rate Schedules IT-R. Il'-D. t-RS. the follorving Rate'Schedules OS: 2011476052.2011476054.
20 I I 475056. 201 1476092.20 I I 476050, 2003004522. and i f applicable Over-Run Cas.
I:Il'ectivc l)ate: January l. 2015 (Amcnded March 1.2015 - Rcplaces the Version ol'the Table Filed F-ebruary 26.2015)
Oroup t
D.llv.ry PointNmbr.
Oioup I D.,tr.y Pokrl ilm.
FT-O O.m.nd Rrt. lT_D Rrhst ffonln
P;c. Polit'z" ffi;'
NOVA Gas Transmission Ltd.
ALLIANCE CLAIRMONT INTERCONNECT APN
ALLIANCE EOSON INTERCONNECT APN
ALLIANCE SHELL CREEK INTERCONNECTAPGC
BOUNDARY LAKE BORDER
EMPRESS BORDER
GORDONDALE BORDER
MCNEILL BORDER
Exhibit No.3
Case No. INT-G-15-02
lntermountain Gas Company
Page 16 of 37
Attachmenl2
Table of Rates, Tolls and Charges
Pag6 I of 5
311t1
31 110
31 112
3002
1958
3888
0404
5.01
4.55
4.55
4.55
4.55
5.82
4.55
5.62
0.1811
0.14t6
0.1646
0.1646
0.1646
0.2034
0.1640
0.2034
0..l640
0.1846
0.1646
0.1646
0-'16.16
0.1646
0.1646
0.1648
0.1646
0.'l6rto
0_t6tl0
o.1 646
0.1046
0. t 640
0.1646
0.1646
0.1640
0.1640
0.1646
0.1640
0.1646
0.1 646
0.1046
0.1640
0.16,06
0.1646
0.r646
0.1646
0.1e46
0.16/t6
0.1049
0.1640
0.1846
0.1040
0.1646
0.1646
0.1646
0.1646
0.1646
0.1846
0.1648
0.1646
0.1646
o.1646
0.1646
0.1646
0.'t646
0.1846
0.1 848
0.1 646
0.'18/+0
0.1646
0.l6tl6
0.1 646
0.1 646
0.1646
0.1646
0.1 646
0.1646
0.1646
0.1646
31000
31001
3880
31003
31002
3.l004
31005
3'r006
3214
31007
3t008
3868
3257
3059
31009
3562
31012
348E
3237
1216
3135
3288
3423
3.l013
31014
3068
3268
3933
3067
3285
3468
3295
3225
3259
3164
3289
3918
3101s
3265
3204
3293
3109
310r6
3634
3165
3886
3484
3t57
31 06
3248
3101
31017
3275
3,195
310r8
3907
3151
3622
6014
31019
s097
3305
TARIFF
A.T. PLASTICS
ADM AGRI INDUSTRIES SALES APN
AECO INTERCONNECTION
AGRIUM CARSELAND SALES APS
AGRIUM FT. SASK SALES APN
AGRIUM REDWATER SALES APN
AINSWORTH SALES APGP
AIR LIQUIDE SALES APN
AKUINU R]VER WESTSALES
ALBERTA ENVIROFUELS SALES APN
ALBERTA HOSPTTAL SALES APN
ALBERTA-MONTANA BORDER
ATDER FLATS SOUTH NO 2 SALES
ALLISON CREEK SALES
ALTASTEEL SALES APN
AMOCO SALES (BP SALES TAP)
APL JASPER SALES APN
ARDLEY SALES
ASPEN SALES
AURORA NO 2 SALES
AUROM SALES
BANTRY SALES
BASHAW WEST SALES
BAYMAG SALES APS
BEAR CREEK COGEN SALES APGP
BEAVER HILLS SALES
BENBOW SOUTH SALES
BIG EDDY INTERCONNECTION
BIGSTONE SALES
BILBO SALES
BLEAK LAKE SALES
BOOTIS HILL SALES
BOTHA SALES
BOULDER CREEK SALES
BMINARD LAKE SALES
BRAZEAU EAST SALES
BUFFALO CREEK INTERCONNECTION
BURDETT COGEN SALES APS
BURNT TIMBER SALES
CABIN SALES
CADOGAN SALES
CALDWELL SALES
CALGARY ENERGY CENTRE SALES APS
CANOE LAKE SALES
CANOE LAKE SALES NO 2
CARBON INTERCONNECTION
CARIBOU LAKE SALES
CARIBOU LAKE SOUTH SALES
CARMON CREEK SALES
CARMON CREEK EAST SALES
CAROLINE SALES
CARSELAND COGEN SALES APS
CARSON CREEK SALES
CAVALIER SALES
CHAIN LAKES COOP SALES APS
CHANCELLOR INTERCONNECTION
CHEECHAM WEST NO 2 SALES
CHEECHAM WEST SALES
CHEVRON AUROM SALES
CHEVRON FT. SASK SALES APN
CHICIGDEE CREEK SALES
CHIGWELL NORTH SALES
4.55
4.55
4.55
4.55
4.55
4.55
,1.55
.1.55
4.55
.t.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
/+.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
4.55
Yes2
YBs
GElp ,
Otllv.ry Point
ilumbtt
Oroep, Irlllv.ty Poht Umt
FT-DO.mrnd Rfi tT{rR.a.p#'*'#:2" ?rllii
Effective: January l, 2015 (Amend6d Auqu6t 1, 201 5)
Exhibit No. 3
Case No. INT-G-15-02
lntermountain Gas Company
Page!7 of37
FOOTHILLS PIPE LINES LTI).
(3 pages)
Exhibit No.3
Case No. INT-G-15-02
lntermountain Gas Company
Page 18 of 37
o TransCanada
ln business to deliver
450- I StreetSW
Calgary, Alberta T2P 5Hl
Tel: [phone]
F*: [phone]
Ernail: [e-mail]
Filed Electronically
October 31,2014
National Energy Board
517 Tenth Avenue SW
Calgary, Alberta T2R 0A8
Attention: Ms. Sheri Young, Secretary of the Board
Dear Ms. Young:
Re: Foothills Pipe Lines Ltd. (Foothills)
Statement of Rates and Charges effective January l,2015
Foothills encloses for filing pursuant to section 60(l)(a) of the National Energt Board Actt rates
and charges for transportation service on Foothills Zones 6,7, 8 and 9 to be effective
January 1,2015 (Effective 2015 Rates).
The following attachments are included with this letter:
. Attachment I consists of supporting Schedules A through F
. Attachments 2 and 3 are black-lined and clean copies, respectively, of the relevant section of
the Tariff showing the Effective 2015 Rates
The rates and charges are based on the methodology approved by the Board in
Decision TG-8-2004, as amended by Order TG-03-2007.
In addition to the rates and charges included in the Table of Effective Rates, Foothills shippers
will be required to pay an abandonment surcharge as directed by the National Energy Board in
MH-001-2013 Decision and Order MO-095-2014. The abandonment surcharge will be contained
in a compliance filing to be made before December 5,2014.
Foothills met with shippers and interested parties on October 9,2014, and presented the
preliminary 2015 revenue requirement and preliminary Effective 2015 Rates. Updated cost and
related rate information were subsequently provided to shippers and interested parties. On the
basis of these consultations, Foothills is not aware of any objections to its proposal for
establishing the Effective 2015 Rates.
I R.S.C. I 985. c. N-7, as amended, and the regulations made thereunder.
Exhibit No. 3
Case No. INT-G-15-02
lntermountain Gas Company
Page 19 of 37
October 31,2014
Ms. S. Young
Page2 of2
Foothills understands that any party that is opposed to the rates and charges will advise the Board
accordingly.
Foothills will notify its shippers and interested parties of this filing and post a copy of it on
TransCanada's Foothills System website at:
http ://www.transcanada.com/customerexpress/934.html
Communication regarding this application should be directed to:
Danen Hoeving
Project Manager, Regulatory Services
TransCanada Pipelines Limited
450- I Street SW
Calgary, Alberta T2P 5Hl
Telephone: [phone]
Facsimile: (403) 920-23 47
Email : [e-mail]
Yours truly,
Foothills Pipe Lines Ltd.
Original signed by
Joel Forrest
Associate General Counsel, Regulatory, Pipelines Law
TransCanada Pipelines Limited
450- I Street SW
Calgary, Alberta T2P 5Hl
Telephone: [phone]
Facsimile: [phone]
Email: joel [e-mail]
Robert Tarvydas
Vice-President, Regulatory Affairs
cc: Foothills Firm Shippers, Interruptible Shippers and Interested Parties
Attachments
['oothills Pipe Lines Ltd.
Exhibit No. 3
Case No.lNT-G-15-02
lntermountain Gas Company
PaEe 20 of 37
Page I
TABLE OF EFFECTIVE RATES
l. Rate Schedule FT, Firm Transportation Service
Zone 6
ZoneT
ZoneS*
Zone9
2. Rate Schedule OT, Overrun Transportation Service
Demand Rate
($/GJ/KmiIr4onth)
0.0066077414
0.0051745157
0.0146248074
0.0110366323
Commodity Rate
($/GJiKm)
0.0002389649
0.000 I 871 332
Zone 6
ZoneT
3. Rate Schedule IT, Interruptible Transportation Service
Zone 8*
Zone9
4. Monthly Abandonment Surcharge**
All Zones
Commodity Rate
($/GJ/Km)
0.000528897r
0.0003991330
0. I 098584422 ($/GJ/Month)
5. Daily Abandonment Surcharge***
All Zones 0.00361l78aa ($/GJ/Day)
* For Zone 8, Shippers Haul Distance shall be 170.7 km.
**Monthly Abandonment Surcharge applicable to Rate Schedule Firm Transportation Service, and Short Term Firm
Transportation Service for all zones.
'I * *Daily Abandonment Surcharge applicable to Rate Schedule Ovemrn Transportation Service for zone 6 & 7 ,
Intemrptible Transportation Service for zone 8 & 9, and Small General Service for zone 9.
TARIFF - PHASE I Effective Date: January 1,2015
Exhibit No. 3
Case No.lNT-G-15-02
lntermountain Gas Company
Page 27 of 37
GAS TRANSMISSION NORTHWEST LLC
(12 pages)
Exhibit No. 3
Case No. INT-G-15-02
lntermountain Gas Company
Page 22 of 37
20150530-3048 FERC PDF (Unofficiall o6/30/2015
l5l FERC fl 61,280
FEDERAL ENERGY REGULATORY COMMISSION
WASHINGTON, DC 20426
June 30,2015
In Reply Refer To:
Gas Transmission Northwest LLC
Docket No. RPI 5-904-000
Gas Transmission Northwest LLC
700 Louisiana Street, Suite 700
Houston, TX 77002-2700
Attention: John A. Roscher
Director, Rates & Tariffs
Dear Mr. Roscher:
1. On April 23,2015, and as amended May 1,2015, Gas Transmission Northwest
LLC (GTN) submitted, pursuant to Rule 207(a)(5),1 a petition for approval of a
Stipulation and Agreement of Settlement (Settlement) regarding changes to GTN's
transportation service rates. GTN included proforma tariff sheets implementing the
revised rates and other tems of the Settlement, which is uncontested.
2. On August 12,201l, GTN filed a Petition for Approval of Stipulation and
Agreement of Settlement (201 I Settlement) that was approved by the Commission on
November 30,2OlL2 Article V.A. of the 201I Settlement established a four-year
moratorium period during which the parties were prohibited from taking certain actions,
including any filings under sections 4 and 5 of the Natural Gas Act (NGA) that would be
inconsistent with the 201I Settlement. Under the 201I Settlement, GTN was required to
file an NGA general section 4 rate case on or about June 30, 201 5, for rates to become
effective on January 1,2016. CTN states that its April23,20l5 Settlernent is filed in lieu
of its obligation to file a general rate case, and obviates the need for GTN to make that
NGA general section 4 rate filing.
' r8 c.F.R. g 385.207(a)(s) (20r4).
2 Gas Transmission Northwest LLC, 137 FERC tT 6l , I 63 (201 I ).
Exhibit No.3
Case No. INT-G-15-02
lntermountain Gas Company
Page 23 of 37
20150530-3048 FERC PDF (Unofficial) 05/30/20L5
Docket No. RPI 5-904-000 .|
3. GTN explains that it entered into settlement negotiations with interested parties,
including shippers and state regulators (Settling Parties) from February 2015 through
April 2015 to resolve their differences regarding issues that might have been raised in an
NGA general section 4 rate filing. GTN states that these meetings resulted in GTN and
the Settling Parties reaching agreement regarding GTN's rates, terms, and conditions of
service, reflected in the Settlement filed in this proceeding.
4. GTN states that it is mindful that the Commission encourages pipelines and their
customers to resolve rate and tariff matters before filing with the Commission3 to change
its rates or other tariff provisions as such a process enables the prompt, efficient
resolution of rate and tariff related matters for the benefit of all concerned, without the
expense of a hearing and lengthy litigation. GTN states the Settlement achieves this goal
and provides for interim rate relief to be effective on July 1,2015,4 and further rate
reductions conditioned as set forth in the agreement. Therefore, GTN submits that the
Settlement is in the public interest and should be approved, effective January 7,2016,
without modifi cation or conditions.
5. The terms of the Settlement are summarized below.
6. Article I provides background information about GTN's previous rate settlement.
It also discusses the negotiation process that GTN, its customers and other interested
parties engaged in to reach the instant Settlement.
7. Article II provides that the terms of the Settlement are an integrated package and
therefore the Settling Parties request that the Settlement be approved in its entirety.
8. Article III defines the terms "Settling Parties" and "Contesting Parties".
9. Article IV provides the proposed effective date and details the order of events to
occur if the Settlement is subject to modification or condition.
10. Article V requires GTN to file a NGA general section 4 rate case with an effective
date of no later than January 1,2022. It also provides that either GTN or any Settling
Pafty may make filings pursuant to the NGA, provided, however, that neither GTN nor
any Settling Party shall take any action that would result in rates other than the Phase I
Settlement Rates becoming effective prior to January 2,2016, except for the Interim Rate
Relief provided for in Article VI.B.
3 See Dominion Transmission, Inc.,l I I FERC fl 61,285, at P 30 (2005).
o GTN has separately filed, in Docket No. RPI 5- 1028-000, tariff records to
implement this interim rate relief, effective July 1,2015, consistent with the Settlement.
Exhibit No.3
Case No. INT-G-15-02
lntermountain Gas Company
Page 24 of 37
20150630-3048 FERC pDF (Unofficial-l 06/3O/2075
Docket No. RP1 5-904-000
I l. Article VI provides details regarding the Settlement Rates for all GTN mainline
transportation services. Article VI.B provides Interim Rate Relief for Settling Parties,
which GTN willfile to place into effect as of July 1,2015. Contesting Parties willnot be
entitled to Interim Rate Relief.
12. Article VII sets forth an annual depreciation rate of 3.5 percent for mainline
natural gas turbines and 1.8 percent for all other mainline transmission facilities.
13. Article VIII provides that GTN will file actualtariff records as they appear in
Appendix B-l at least 30 calendar days before the January 1,2016 effective date. Article
VIII also provides for contingencies if a Commission order approving the Settlement has
not been issued by December 1,2015.
14. Article IX describes how Post Retirement Benefits Other Than Pensions (PBOP)
will be funded, and the treatment of PBOPs in the next rate case. It also details PBOP
disbursements, and steps GTN must take if it seeks to terminate the PBOP trust.
I 5 . Article X provides that upon the effective date of the Settlement, it shall supersede
the 201I Settlement in its entirety.
16. Article XI generally states that no party shall be bound or prejudiced by the
Settlement unless it becomes effective in accordance with its provisions and that approval
of the Settlement does not constitute approval of, or precedent regardin g, any principle or
issue. Further, it provides that to the extent that the Commission considers any changes
to the terms of the Settlement prior to January 2,2016, the standard of review shall be the
most stringent standard permissible under applicable law.
17. Article XII provides that until the Settlement is approved by the Commission and
becomes effective, it shall be privileged and of no effect, and shall not be admissible in
evidence.
I 8. Article XIII provides that Commission approval of the Settlement shall constitute
Commission authorization and approval for GTN to implement the rates and tariff
changes reflected in the Settlement without suspension or conditions, other than those
specified in the Settlement. It also states that the Commission's approval of the
Settlement shall constitute all authorization necessary to carry out any provision of the
Settlement.
19. Article XIV provides that GTN and Settling Parties understand and agree that
GTN is responsible to maintain and operate its pipeline facilities in full compliance with
all applicable safety and reliability laws and regulations.
20. Public notice of the filing was issued on May 1,2015, allowing for protests to be
filed as provided in section 154.210 of the Cornmission's regulations (18 C.F.R.
S 154.210 (2014)). No protests or adverse comments were filed.
-J
Exhibit No.3
Case No. INT-G-15-02
lntermountain Gas Company
Page 25 of 37
20150630-3048 FERC PDF (Unofficiall 06/30/2075
Docket No. RPI 5-904-000 -4-
21. Consistent with the Commission's guidance for filing settlements outside the
context of an existing proceeding set forth in Dominion Transmission, Inc.,s the
Settlement resolves GTN's cost of service issues without the need for protracted litigation
and hearings. The Commission explained in Dominion that when a pipeline negotiates an
agreement with its customers and others to change its rates or terms and conditions of
service, and it desires approval of the agreement before making an actualNGA section 4
tariff filing, it may file, pursuant to Rule 207(a)(5),6 a petition for approval of the
agreement, along withproforma tariff sheets reflecting how the agreement will be
implemented. This is the procedure GTN has followed here.
22. Because the Settlement provides that the standard of review for any changes to the
terms of the Settlement considered by the Commission prior to January 2,2016 is "the
most stringent standard permissible under applicable law," we clarify the framework that
would apply if the Commission were required to determine the standard of review in a
later challenge to the Settlement.
23. The Mobite-Sierra1 "public interest" presumption applies to an agreement only if
the agreement has certain characteristics that justify the presumption. In ruling on
whether the characteristics necessary to justifu a Mobile-Sierua presumption are present,
the Commission must determine whether the agreement at issue embodies either (l)
individualized rates, terms, or conditions that apply only to sophisticated parties who
negotiated them freely at arm's length; or (2) rates, terms, or conditions that are generally
applicable or that arose in circumstances that do not provide the assurance ofjustness and
reasonableness associated with arm's-length negotiations. Unlike the latter, the former
constitute contract rates, terms, or conditions that necessarily qualifo for a Mobile-Sierua
presumption . ln New England Power Generators Ass'n, Inc. v. FERC,8 however, the
D.C. Circuit determined that the Commission is legally authorized to impose a more
rigorous application of the statutory 'Just and reasonable" standard of review on future
changes to agreements that fall within the second category described above.
t I I I FERC fl 61,285 (2005) (Dominion).
u l8 c.F.R. g 385.207(axs) (2014).
' fJrited Gas Pipeline Co. v. Mobile Gas Serv. Corp.,350 U.S. 332 (1956); FPC v.
Sierra Pac. Power Co., 350 U.S. 348 ( 1956) (collectively , Mobile-Sierra).
t z07 F.3d 364,370-7r (D.c. cir. z0r3).
Exhibit No.3
Case No. INT-G-15-02
lntermountain Gas Company
Page 26 of 37
20r-50630-3048 FERC pDF (Unofficj.all 06/3o/2o].s
DocketNo. RPl5-904-000 -5-
24. The Commission finds that the Settlement appears to be fair and reasonable and in
the public interest and it is hereby approved.e
25. The Commission's approval of this Settlement does not constitute approval of or
precedent regarding, any principle or issue in this proceeding.
By direction of the Commission.
Nathaniel J. Davis, Sr.,
Deputy Secretary.
e See t8 C.F.R. $ 38s.602(gx3) (2014).
Exhibit No. 3
Case No. INT-G-15-02
lntermountain Gas Company
Page27 of37
Gas Transmission Northwest LLC
FERC Gas Tarffi Fourth Revised Volume No. 1-A
Pro Forma (l/1/2016 - l2/31/20191
Clean Tariff
Tariff Section Version
4.l - Statement of Rates, v. I I .0.0
FTS-I and LFS-I Rates
4.2 - Statement of Rates,
ITS-l Rates
v.4.0.0
4.3 - Statement of Rates, v.8.0.0
Footnotes to Statement of Effective Rates and Charges
4.5 - Statement of Rates, v.3.0.0
Parking and Authorized Imbalance Services
Exhibit No. 3
Case No. INT-G-15-02
lntermountain Gas Company
Page 28 of 37
Gas Transmission Northwest LLC PART 4.1
FERC Gas Tariff 4.1 - Statement of Rates
Fourth Revised Volume No. l-A FTS-I and LFS-I Rates
v. I I .0.0 Superseding v. I 0.0.0 PRO FORMA (l ll /2016 - 12131 12019)
STATEMENT OF EFFECTIVE RATES AND CHARGES FOR
TRANSPORTATION OF NATURAL GAS
Rate Schedules FTS-l and LFS-l
RESERVATION
DAILY DAILY
MILEAGE (a) NON-MILEAGE (b)
BASE
STF (e)
0.000434 0.000000 0.034393 0.000000
(e) 0.000000 (e) 0.000000
(Dth-MILE)
Max. Min.
(Dth)
Max. Min.
DELIVERY (c)
(Dth-MrLE)
Max. Min.
0.000016 0.000016
0.000016 0.000016
FUEL (d)
(Dth-MrLE)
Max. Min.
0.0050% 0.0000%
0.0050% 0.0000%
EXTENSION CHARGES
MEDFORD
E-l (0 0.0027s9
E-2 (h)(r) 0.002e72
(Diamond 1)
E-2 (hxr) 0.001166
(Diamond 2)
COYOTE SPRINGS
0.000000 0.004641 0.000000
0.000000
0.000000
0.000026 0.000026
0.000000 0.000000
0.000000 0.000000
E-3 (i)0.00t282 0.000000 0.00r283 0.000000 0.000000 0.000000
oVERRUN CHARGE (i)
ST]RCHARGES
ACA (k)(k)(k)
Issued:
Effective:
Docket No.
Accepted:
Exhibit No. 3
Case No. INT-G-15-02
lntermountain Gas Company
Page 29 of 37
O Ln,T":s?"?3d'
Jury r5,20r5 iffI#3|.Tj8::J:f,[1'.T *"
Houston, TX 77OO2-27O0
Ms. Kimberly D. Bose, Secretary John A' Roscher
Federal Energy Regulatory commission Director' Rates & Tariffs
888 First Street, NE tel a3z.32o.s67s
washington' DC 20426 l"J.', i,if;1i3'?f,'"?.rranscanada.comweb www,gastransmissionnw.com
Re: Gas Transmission Northwest LLC
Compliance Filing, Docket No, CPl2-494-000
Docket No. RPl5-
Dear Ms. Bose:
Pursuant to Section 4 of the Natural Gas Act ("NGA") and Part 154 of the Federal Energy Regulatory
Commission's (*FERC" or "Commission") regulations,' Cas Transmission Northwest LLC ("GTN')
hereby submits for filing certain tariff sections2 to be part of its FERC Gas Tarifll Fourth Revised Volume
No. l-A ("Tariff'). These revised tariff sections are being submitted to comply with the Commission's
March 14,2013, Order Issuing Certificate in Docket No. CP12-494-000.r GTN requests that the
Commission accept the proposed tariff sections to become effective on the date the facilities are placed
into service, which is anticipated to occur on or about October I, 201 5.
Correspondence
The names, titles and mailing address of the persons to whom correspondence and communications
conceming this filing should be directed are as follows:
' t8 c.F.R. Part 154 (2015).
2 Specifically, Section 4.1 - Statement ofRates, FTS-l and LFS-l Rates ("Section 4.1"): Section 4.2 - Statement of
Rates, ITS-I Rates ("Section 4.2") and Section 4.3 - Statement of Rates, Footnotes to Statement of Effective
Rates and Charges ("Section 4.3").3 Gas Transmission Northwest LLC,l42 FERC tT 61,186 (2013) ("Order Issuing Certificate" or "Order").
Exhibit No. 3
Case No. INT-G-15-02
lntermountain Gas Company
Page 30 of 37
* Eva N. Neufeld
Associate General Counsel
Gas Transmission Northwest LLC
700 Louisiana Street, Suite 700
Houston, T exas 7 7 002-27 00
Tel. [phone]
Fax [phone]
eva_neufeld@transcanada. com
John A. Roscher
Director, Rates and Tariffs* Joan F. Collins
Manager, Tariffs and Compliance
Gas Transmission Northwest LLC
700 Louisiana Street, Suite 700
Houston, T exas 7 7 002-27 00
Tel. (832) 320-s6sl
Fax [phone]
joan_col I [e-mail]
* Persons designated for official service pursuant to Rule 2010.
Statement of Nature. Reasons and Basis for Filins
On July 31, 2012, GTN filed an abbreviated application pursuant to section 7(c) of the Natural Gas Act
('NGA-)4 and Part 157 of the Commission's Regulationss ("Application") for authorization to construct,
own and operate the Carty Lateral in Morow County, Oregon ("Carty Lateral") in order to provide up to
175,000 dekatherms ("Dth") per day of firm transportation service to Portland General Electric
Company's Carty Generating Station. In its Application, GTN submitted proforma tariff sections with
recourse rates applicable to service on the Carty Lateral, which were derived using a return on equity
("ROE") of 13 percent. On March 14, 2013, the Commission issued the Order Issuing Certificate,
wherein it denied GTN's proposed ROE of l3 percent and instructed GTN to make a filing no later than
60 days before the in-service date of the Carty Lateral to revise the recourse rates to reflect GTN's
currently authorized ROE.6
In compliance with the Commission's Order, CTN is submitting a revised Exhibit P for the Carty Lateral
that reflects a cost-of-service and recourse rates based upon an ROE of 12.20 percent, CTN's last
approved ROE.7 As a result of the change in ROE, the proposed recourse rate has decreased from
$0.172430 per dekatherm to $0.166475 per dekatherm. As further required by the Order, GTN is
n l5 u.s.c. i 7tlf (2012).
' t8 c.F.R. Part 157 (2014).
6 Order Issuing Certificate at P I8.
'CTN's last approved ROE is pursuant to the Section 4 proceeding in Docket No. RP94-149-000. See Pacific Gas
Transmission Company, T6 FERC n 61,246 (1996), reh'g sub nom, PG&E Gas Transmission, Northwest Corp.,82
FERC,tT6r.289 (1998).
Exhibit No. 3
Case No. INT-G-15-02
lntermountain Gas Company
Page 31 of 37
submitting, as Appendix A, live tariff sections to place into effect the revised recourse rates applicable to
service on the Carty Lateral.s
Effective Date
Regarding the proposed effective date for the tariffsections included in the instant filing, pursuant to the
FERC's Implementation Guide for Electronic Tariff Filing,e and for administrative ease, GTN is
reflecting an effective date of December 31, 9998, as a placeholder until the actual in-service date is
known. Upon the Carty Lateral' s in-service, GTN will submit a notification to the Commission of the
actual date to reflect in the tariff sections, anticipated to occur on or about October l, 2015. GTN
respectfully requests that the Commission grant all waivers of its regulations and GTN's Tariff necessary
to accept this filing and approve the tariff sections included at Appendix A to become effective as
requested herein.
Other Filines Which Mav Affect This Proceedine
There are no other filings before the Commission that may significantly affect the changes proposed
herein.
Contents of Filins
In accordance with Section 154.7 of the Commission's Regulations, GTN is submitting the following via
its electronic tariff filing:
l. This transmittal letter;
2. A clean version of the tariff sections (Appendix A);
3. A marked version of the tariff sections (Appendix B);
4. Revised Exhibit P (Appendix C).
Certificate of Service
As required by Sections 154.7(b) and 154.208 of the Commission's regulations, copies of this filing are
being served upon all parties in this proceeding, all of GTN's existing customers and interested state
regulatory agencies. A copy of this letter, together with the other attachments, is available during regular
business hours for public inspection at GTN's principal place of business.
8 Order Issuing Certificate at ordering paragraph (F). As GTN anticipates an in-service date ofOctober 1,2015, the
instant filing meets the requirement set forth in the Order that GTN make a filing no later than 60 days before the
in-service date ofthe Carty Lateral.
' Office of the Secretary of the Commission, Implementation Guide for Eleclronic Filing of Parts 35, 154,281 300
and 341 TariffFilings Q0l4).
Exhibit No. 3
Case No. INT-G-15-02
lntermountain Gas Company
Page 32 of 37
Pursuant to Section 385.2005 and Section 385.2011, the undersigned has read this filing and knows its
contents, and the contents are true as stated, to the best of his knowledge and belief. Additionally, the
undersigned possesses full power and authority to sign such filing.
Any questions regarding this filing may be directed to Joan Collins at [phone].
Respectfully subm itted,
GAS TRANSMISSION NORTHWEST LLC
WdW
John A. Roscher
Director, Rates & Tariffs
Enclosures
Exhibit No. 3
Case No. INT-G-15-02
lntermountain Gas Company
Page 33 of 37
PART 4.I
4.1 - Statement of Rates
FTS-I and LFS-I Rates
v. 13.0.0 Superseding v. I 2.0.0
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. 1-A
(Dth-MILE)
Max. Min.
MEDFORD
E-r (0 0.003290 0.000000
E-2 (hxl) 0.002972 0.000000
(Diamond l)
Issued: July 15, 2015
Effective: December 31, 9998
STATEMENT OF EFFECTIVE RATES AND CHARGES FOR
TRANSPORTATION OF NATURAL GAS
Rate Schedules FTS-l and LFS-l
RESERVATIONDAILY DAILY
MILEAGE (a) NON-MILEAGE (b)
BASE 0.000483 0.000000 0.038402 0.000000
STF (e) (e) 0.000000 (e) 0.000000
EXTENSION CHARGES
(Drh)
Max. Min.
0.005498 0.000000
DELIVERY (c)
(Dth-MrLE)
Max. Min.
0.000016 0.000016
0.000016 0.000016
FUEL (d)
(Dth-MrLE)
Max. Min.
0.0050% 0.0000%o
0.0050% 0.0000%
E-2 (h)(l) 0.00r 166 0.000000
(Diamond 2)
COYOTE SPRINGS
E-3 (i) 0.001412 0.000000 0.001420 0.000000
CARTY LATERAL
E-4 (p) 0.16647s 0.000000
OVERRUN CHARGE (i)
SURCHARGES
ACA (k)
0.000026 0.000026
0.000000 0.000000
0.000000 0.000000
0.000000 0.000000
0.000000 0.000000
(k)(k)
Docket No.
Accepted:
Exhibit No. 3
Case No. INT-G-15-02
lntermountain Gas Company
Page34 of 37
QUESTAR PIPELINE COMPANY
(3 pages)
Exhibit No.3
Case No. INT-G-15-02
lntermountain Gas Company
Page 35 of 37
201.4l-210-3032 FERC pDF (Unofficial\ 12/lO/201-4
FEDERAL ENERGY REGULATORY COMMISSION
WASHINGTON, D.C. 20426
OFFICE OF ENERGY MARKET REGULATION
In Reply Refer To:
Letter Order Pursuant to $ 375.307
Questar Pipeline Company
Docket No. RP1 5-207-000
December 10,2014
Questar Pipeline Company
333 South State Street
P.O. Box 45360
Salt Lake city, UT 84145-0360
Attention: L. Bradley Burton, General Manager
Federal Regulatory Affairs and FERC Compliance Officer
Reference: Fuel Gas Reimbursement Percentage Filing
Dear Mr. Burton:
On Novemb er 25,2014, Questar Pipeline Company (Questar) filed a tariff recordr
to reflect a change in its Fuel Gas Reimbursement Percentage (FGRP) as provided by
section 12.15 ofthe GeneralTerms & Conditions of its Tariff. The proposed tariff record
decreases Questar's FGRP from the currently effective 1.97%to 1.86%o. Questar's tariff
record is accepted effective January 1,2015, as proposed.
Public notice of the filing was issued on November 26,2014. Interventions and
protests were due as provided in section 154.210 of the Commission's regulations (18
C.F.R. $ 154.210 (2014)). Pursuant to Rule 214 (18 C.F.R. $ 385.214 (2014)), all timely
filed motions to intervene and any unopposed motions to intervene out-of-time filed
before the issuance date of this order are granted. Granting late interventions at this stage
of the proceeding will not disrupt the proceeding or place additional burdens on existing
parties. No protests or adverse comments were filed.
I Questar Pipeline Company, FERC NGA Gas Tariff, Tariffs, Statement of Rates.
Statement of Rates. 9.0.0.
Exhibit No.3
Case No. INT-G-15-02
lntermountain Gas Company
Page 36 of 37
201,4t270-3032 FERC pDF (Unofficial-l t2/L0/20L4
Docket No. RP1 5-207-000
This acceptance for filing shall not be construed as constituting approval of the
referenced filing or of any rate, charge, classification, or any rule, regulation, or practice
affecting such rate or service contained in your tariff; nor shall such acceptance be
deemed as recognition of any claimed contractual right or obligation associated
therewith; and such acceptance is without prejudice to any findings or orders which have
been or any which may hereafter be made by the Commission in any proceeding now
pending or hereafter instituted by or against your company.
This order constitutes final agency action. Requests for rehearing by the
Commission may be filed within 30 days of the date of issuance of this order, pursuant to
18 C.F.R. $ 38s.713 (2014).
Sincerely,
Nils Nichols, Director
Division of Pipeline Regulation
,|
Exhibit No. 3
Case No. INT-G-15-02
lntermountain Gas Company
Page 37 of 37
Questar Pipeline Company
FERC Gas Tariff
Second Revised Volume No. 1
Statement of Rates
Section Version: 9.0.0
STATEMENT OF MTES
Rate Schedule/
Type of Charge
(a)
PEAKING STORAGE
Firm Peaking Storage Service - PKS
Monthly Reservation Charge
Maximum 4/ ..-............... 2.87375Minimum......................:.:::::::::::::::::::::::::::::::::::::............. 0.00000
Usage ChargeInjection .0.03872Withdrawal 0.03872
CLAY BASIN STOMGE
Firm Storage Service - FSS
Monthly Reservation Charge
Deliverability
Maximum 4/ .................. 2.85338Minimum........ 0.00000
CapacityMaximum 0.02378Minimum........ 0.00000
Usage ChargeInjectionl/ 0.01049Withdrawal 0.01781
Authorized Overrun Charge ...........Maximuml/.... 0.30315Minimuml/..... 0.01781Interruptible Storage Service - ISS
Usage Charge
Inventory 5/Maximum O.O5927Minimum........ 0.00000Injectionl/ 0.01049Withdrawal 0.01781
OPTIONAL VOLUMETRIC RELEASES /
Peaking Storage Service - PKS
Maximum 4/ .................. .. 3.40890Minimum........ 0.00000
Firm Storage Service - FSS
Maximum 4/ .................. .. 0.57068Minimum........ 0.00000
Storage Usage Charges Applicable to Volumetric Releases 6/
Peaking Storage Service - PKS :...............
Withdrawal ..... 0.03872
Clay Basin Storage Service - FSS:
Withdrawal 0.01781
PARK AND LOAN SERVICE - PAL1
Daily ChargeMaximum . 0.30315Minimum........ 0.00000
Delivery Chargel/ 0.02830
FUEL REIMBURSEMENT - 2.0o/o (O.2o/o utility and 1.80/o compressor fuel) for Rate Schedule PAL1
Base
Tariff
Rate ($)
(b)
Filed On: November 25,2OL4 Effective On: January 1, 2015
EXHIBIT NOS. 4.11
CASE NO. INT.G.I5-02
INTERMOT]NTAIN GAS COMPAI\Y
(8 pages)
Exhibit No. 4
Case No. INT-G-15-02
lntermountain Gas Company
Page 1 of 1
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Exhibit No.5
Case No. INT-G-15-02
lntermountain Gas Company
Page 1 of 1
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Exhibit No.6
Case No. INT-G-15-02
lntermountain Gas Company
Page 1 of 1
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Exhibit No.7
Case No. INT-G-15-02
lntermountain Gas Company
Page 1 of 1
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o.EO'32
Exhibit No. 8
Case No. INT-G-15-02
lntermountain Gas Company
Page 1 of 1
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No.
INTERMOUNTAIN GAS COMPANY
Proposed Temporary Surcharges (Credits) - Variable Costs
Description
Exhibit No.9
Case No. INT-G-15-02
lntermountain Gas Company
Page 1 of 1
Amount
(a)
Account 1910 Variable Amounts Which Apply to RS-1, RS-z, GS-l, and LV-1:
Account'1910 Variable Costs
Normalized Sales Volumes (111114 - 12131114)
Proposed Temporary Surcharge (Credit)- Variable Costs
Lost and Unaccounted For Gas Amounts Which Apply to RS-1, RS-2, and GS-l:
Lost and Unaccounted For Gas Amounts from INT-G-14-01 (Account 1910-2120)
Lost and Unaccounted For Gas Amortization (Account 1910-2130)
(Over)/Under Collection of Lost and Unaccounted For Gas from INT-G-14-01
Lost and Unaccounted For Gas INT-G-15-02
Total Lost and Unaccounted For Gas Amounts Which Apply to RS-1, RS-2, and GS-1
Normalized Sales Volumes (111114 - 12131114)
Proposed Temporary Surcharge (Credit) - Lost and Unaccounted For Gas Costs
Lost and Unaccounted For Gas Amounts Which Apply to LV-1, T-3, T-4, and T-5:
Lost and Unaccounted For Gas Amounts from INT-G-14-01 (Account 1910-2120)
Lost and Unaccounted For Gas Amortization (Account 1910-2140)
(Over)/Under Collection of Lost and Unaccounted For Gas from INT-G-14-01
Lost and Unaccounted For Gas INT-G-'|5-02
Total Lost and Unaccounted For Gas Amounts Which Apply to LV-1, T-3, T-4 and T-5
Normalized Sales Volumes (111114 - 12131114)
Proposed Temporary Surcharge (Credit) - Lost and Unaccounted For Gas Costs
(1) See Workpaper No. 5, Page 1
(2) See Workpaper No. 5, Page 2,Line2, Column (c)
(3) See Workpaper No. 5, Page 2, Line 8, Column (d)
(4) See Workpaper No. 5, Page 2, Line 23, Column (d) plus Line 29, Column (e)
(5) See Workpaper No. 5, Page 2, Line 3, Column (c)
(6) See Workpaper No. 5, Page 2,Line 12, Column (d)
(7) See Workpaper No. 5, Page 2,Line24, Column (d) plus Line 33, Column (e)
(b)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
'15
16
17
't8
19
20
696,361 (1)
333,850,840
477,$0 t2l
(435,680) (3)
41,850
(771,881)(4)
$ (730,031)
328,045,0't4
$ (0.00223)
$ t56,stz (5)
(158,981)(6)
(2,444)
(257,308) o)
$ (259,752)
273,541,337
(0.000s5)
0.00209
Exhibit No. 10
Case No. INT-G-15-02
lntermountain Gas Company
Page 1 of 1
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Exhibit No. 11
Case No. INT-G-15-02
lntermountain Gas Company
Page 1 of 1
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I\EWS RELEASE
and
CUSTOMER NOTICE
CASE NO.INT-G-15-02
INTERMOUNTAIN GAS COMPAI\TY
(2 Pages)
INTERMOUNTAIN
CAS COMPANY
A Subsidiary ol MDU Bewurces Grwp, lnc.
555 S. Cole Rd.
Boise, lD 83709
Intermountain Gas Company files annual PGA
BOISE,IDAHO -August 7,2015 -- Intermountain Gas Company filed its annual Purchased Gas Cost
Adjustment (PGA) application with the Idaho Public Utilities Commission to change its prices by an overall
average decrease of 5.690/o, or $15.3 million. If approved, the decrease would be effective Oct.l, 2015. The
primary reason behind the proposed decrease is a decline in the price of natural gas that Intermountain
purchases for its customers. With this proposed decrease, Intermountain's combined residential and
commercial prices would be 35o/o lower as compared to 2005. Intermountain's earnings will not decrease as a
result ofthe proposed change in prices and revenues.
If approved, residential customers using natural gas for space and water heating will see an average decrease of
6.170 , or $3.12 per month. Customers using natural gas for space heating only will see an average decrease of
$ I .36 per month, or 3.56oh, based on average weather and usage. Commercial customers, on average, would
see a decrease of $ 12. l5 per month or 5.66%o.
The company is also proposing to eliminate the temporary surcharges and credits that have been included in its
current prices during the past year. Newer temporary surcharges and credits will be included going forward.
Scott Madison, Executive Vice President and General Manager of Intermountain said, "The decrease in the cost
of natural gas is mainly a supply and demand issue, and natural gas supplies remain plentiful. Additionally, last
winter's warm weather in the western U.S reduced demand on natural gas storage levels in our region, adding to
the availability of natural gas heading into next winter. We continue to see increased domestic natural gas
production, and we anticipate prices will remain fairly stable in the coming year."
Even with this proposed price decrease, 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.inlgas.com.
A Purchased Gas Cost Adiustment 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 a proposal, and is subject to public review
and approval by the Idaho Public Utilities Commission. A copy of the application is available at the
Commission's office and on its homepage at u,ww.pr"rc.idaho.gov as well as on Intermountain's website at
rvu'u,.inlgas.com . Written comments regarding the application may be filed with the Commission. Customers
may also subscribe to the Commission's RSS feed to receive periodic updates via email.
httermountain Gas Contpany is a natural gas distribution cornpany serving approxinrutely 331,000 residenlial,
commercial and industrial cuslomers in 75 communilies in soulhern ldaho. Inlermountain is a subsidiary of MDU
Resources Group, Inc., a mullidimensional nalural resources enterprise traded on the Neu, York Stock Exchange as
"MDU." For more information about MDU Resources, visil the conry)any's website al vvv.rtrdtr.t'rttn. For ntore
iffirmal i on ab oul In te r ntoun t ain, vis i I v'trv. i t t t {trs. t' t t t t t.
Media Contact: Byron Defenbach at [phone].
NBWS RELEASE
AHIE&fRUNTATN'ASuEidiatyol HDU BerMGtut9 fiu.
Customer Notice
Intermountain Gas Company files annual PGA
On August7,2015 -- lntermountain Gas Company filed its annual Purchased Gas Cost Adjustment
(PGA) application with the ldaho Public Utilities Commission to change its prices by an overall average
decrease of 5.69%, or $15.3 million. lf approved, the decrease would be effective Oct.1 , 2015. The
primary reason behind the proposed decrease is a decline in the price of natural gas that lntermountain
purchases for its customers. With this proposed decrease, lntermountain's combined residential and
commercial prices would be 35% lower as compared to 2005. lntermountain's earnings will not
decrease as a result of the proposed change in prices and revenues.
lf approved, residential customers using natural gas for space and water heating will see an average
decrease of 6.1 1o/o, or $3.12 per month. Customers using natural gas for space heating only will see
an average decrease of $1.36 per month, or 3.56%, based on average weather and usage.
Commercial customers, on average, would see a decrease of $12.15 per month or 5.66%.
The company is also proposing to eliminate the temporary surcharges and credits that have been
included in its current prices during the past year. Newer temporary surcharges and credits will be
included going forward.
Scott Madison, Executive Vice President and General Manager of lntermountain said, "The decrease in
the cost of natural gas is mainly a supply and demand issue, and natural gas supplies remain plentiful.
Additionally, last winter's warm weather in the western U.S reduced demand on natural gas storage
levels in our region, adding to the availability of natural gas heading into next winter. We continue to
see increased domestic natural gas production, and we anticipate prices will remain fairly stable in the
coming year."
Even with this proposed price decrease, lntermountain 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. intgas.com.
A Purchased Gas Cost Adjustment application is filed each year to ensure the costs lntermountain
incurs on behalf of its customers are reflected in its sales prices. The request is a proposal, and is
subject to public review and approval by the ldaho Public Utilities Commission. A copy of the
application is available at the Commission's office and on its homepage at www.puc.idaho.oov as well
as on lntermountain's website at www.intqas.com . Written comments regarding the application may be
filed with the Commission. Customers may also subscribe to the Commission's RSS feed to receive
periodic updates via email.
WORKPAPER NOS. 1.8
CASE NO. INT.G.15.O2
INTERMOUNTAIN GAS COMPANY
(15 pages)
Workpaper No. 1
Case No. INT-G-15-02
lntermountain Gas Company
Page \ of 2
INTERMOUNTAIN GAS COMPANY
Line
No.
tNT.G.14.01
Annual Therms
rNT.G.14-01
Prices
tNT.G.14-01
Annual Cost
Summary of Northwest Pipeline TF-l Full Rate Demand Costs
Transportation
1
2
3
4
5
o
7
8
I
10
11
12
13
Line
No.
(a)
TF-'l Reservation Contract #1
TF-1 Reservation Contract #2
TF-1 Reservation Contract #3
TF-1 Reservation Contract fl4
TF-1 Reservation Conhact #5
TF-1 Reservation Contract #6
TF-1 Reservation Contract #7
TF-1 Reservation Contract #8
TF-1 Reservation Contract #9
TF-1 Reservation Contract #10
TF-1 Reservation Contract #11
TF-1 Reservation Contract #12
Total
Transportation
(b)
412,537,600
25,550,000
73,000,000
26,429,650
32,850,000
0
87,600,000
18,250,000
104,495,850
26,462,500
51,081,750
4,530,000
862,787,350
tNT.G.15-02
Annual Therms(1)
(c)
0.041849
0.054215
0.041000
0.041000
0.041000
0.000000
0.041000
0.041000
0.041000
0.041000
0.041000
0.041000
(d)
17,264,201
1,385,194
2,993,000
1,083,614
1,346,850
0
3,591,600
748,250
4,284,334
1,084,966
2,094,351
185,730
36,062,090
tNT.G.15.02
Prices
rNT.G.15.02
Annual Cost
(a)
TF-1 Reservation Contract #1
TF-1 Reservation Contract #2
TF-1 Reservation Contract #3
TF-'l Reservation Contract ll4
TF-1 Reservation Contract #5
TF-1 Reservation Contract #6
TF-1 Reservation Contract #7
TF-1 Reservation Contract #8
TF-1 Reservation Contract #9
TF-1 Reservation Contract #10
TF-1 Reservation Contract #1'l
TF-1 Reservation Contract #1 2
Total
(d)
$ 17,297,914
1,347 ,516
3,001,200
1,086,582
1,350,540
1,500,600
3,601,440
750,300
4,296,072
1,087,939
2,1 00,089
186,960
(b)
413,667,840
25,620,000
73,200,000
26,502,060
32,940,000
36,600,000
87,840,000
18,300,000
104,782,140
26,535,000
51,221,700
(c)
0.041816
0.052596
0.041000
0.041000
0.041000
0.041000
0.041000
0.041000
0.041000
0.041000
0.041000
0.041000
14
15
16
17
18
19
20
21
22
23
24
25
26
27
4,560,000
901,768,740 37,607,152
Total Annual Cost Difference (Row 26 minus Row 13)
(1) Daily Contract Demand multiplied by 366 days
(2) See Exhibit 4, Line 3, Column (h)
$ 1,545,062 (2)
Workpaper No. 1
Case No. INT-G-15-02
lntermountain Gas Company
Page 2 of 2
INTERMOUNTAIN GAS COMPANY
Line
No.
lNT.G.14-01
AnnualTherms
tNT.G-14.01
Prices
tNT-G-14-01
Annual Cost
Summary of Northwest Pipeline TF-1 Discounted Demand Costs
Transportation
1
2
3
4
5
6
7
8
Line
No.
(a)
TF-1 Reservation Contract #1
TF-1 Reservation Contract #2
TF-1 Reservation Contract #3
TF-1 Reservation Contract #4
TF-1 Reservation Contract #5
TF-1 Reservation Contract #6
TF-1 Reservation Contract #7
Total
Transportation
(b)
18,250,000
29,404,400
58,400,000
36,500,000
32,850,000
11,497,500
18,200,000
20s,101 ,900
INT.G-15-02
Annual Therms(1)
(c)
0.026650
0.021747
0.023409
0,026650
0.008499
0.036900
0.034850
(d)
486,366
639,444
1,367 ,104
972,725
279,203
424,261
634,270
4,803,373
INT-G-15.02
Prices
tNT-G-15.02
Annual Cost
9
10
11
12
13
14
15
16
17
(a)
TF-1 Reservation Contract #1
TF-1 Reservation Contract #2
TF-1 Reservation Contract #3
TF-1 Reservation Contract #4
TF-1 Reservation Contract #5
TF-1 Reservation Contract #6
TF-1 Reservation Contract #7
Total
(b)
18,300,000
29,484,960
58,560,000
36,600,000
32,940,000
1 1,529,000
0
(c)
0.026650
0.022698
0,024600
0.027776
0.008500
0.036900
0.000000
(d)
487,699
669,240
1,440,576
1 ,016,595
279,990
425,423
0
187,413,960
Total Annual Cost Difference (Row 16 minus Row 8)
4,319,523
(r) Daily Contract Demand multiplied by 366 days
(2) See Exhibit 4, Line 4, Column (h)
(4g3,g50) (2)
Workpaper No. 2
Case No. INT-G-15-02
lntermountain Gas Company
Page 1 of 2
INTERMOUNTAIN GAS COMPANY
tNT-G.14.01
Annual Therms
tNT.G.14.01
Prices
tNT.G.14-01
Annual Cost
Summary of Upstream Capacity Full Rate Demand Costs
Transportation
1 Upskeam Agreement #1
2 Upstream Agreement #2
3 Upsheam Agreement #3
4 Upstream Agreement #4
5 Upstream Agreement #5
6 Upskeam Agreement #6
7 Upstream Agreement #7
8 Upstream Agreement #8
9 Upstream Agreement #9
10 Total
11
(a) (b)
25,933,250
351,503,260
26,962,550
37,288,400
26,126,700
128,898,520
54,750,000
37,587,700
689,050,380
(c)
0.009036 $
0.009042
0.009036
0.009036
0.017735
0.017735
0.017735
(d)
234,330
3,178,200
243,631
336,934
463,347
2,285,964
970,969
12
_ (1)
0.017968 675,366 (2)
8,388,741
(500,000)
$ 7,888,741
Line
No.
Estimated Upskeam Capacity Release Credits
TotalAnnual Cost lncluding Capacity Release Credits
Transportation
tNT-G.15.02
Annua! Therms(3)
1NT.G.15.02
Prices
tNT.G.15.02
Annual Cost
(a)(b)
26,004,300
352,589,060
27,036,420
37,236,840
26,198,280
129,355,380
54,900,000
22,750,000
(c)
0.009016
0.009019
0.009016
0.009016
0.01 6504
0.016633
0.016504
0.016661
(d)
234,456
3,179,971
243,768
335,736
432,369
2,151,588
906,052
379,033 (1)
(2)
7,862,973
(500,000)
$ 7,362,973
13 Upstream Agreement #1
14 Upstream Agreement #2
15 Upstream Agreement #3
16 Upskeam Agreement #4
17 Upstream Agreement #5
18 Upsheam Agreement #6
19 Upstream Agreement #7
20 Upstream Agreement #8
21 Upstream Agreement #9
22 Total
23
24
676,070,280
Estimated Upskeam Capacity Release Credits
TotalAnnual Cost lncluding Capacity Release Credits
25 Total Annual Gost Difference (Row 24 minus Row 12)
(1) Renegotiated to full rate. See Workpaper 2 ,Page2, Lines 2 and 8, Column (d).
(2) Renegotiated to a discounted rate. See Workpaper 2, Page 2, Lines 5 and 11, Column (d).
(3) Daily Contract Demand multiplied by 366 days
(a) See Exhibit 4, Line 5, Column (h)
$ (525,768) (4)
Workpaper No. 2
Case No. INT-G-15-02
lntermountain Gas Company
Page 2 of 2
INTERMOUNTAIN GAS COMPANY
tNT-G.14-01
AnnualTherms
INT-G-14-01
Prices
INT.G-14.01
Annual Cost
Summary of Upstream Capacity Discounted Demand Costs
Transportation
1
2
3
4
5
6
(a)
Upstream Agreement #1
Upstream Agreement #2
Upstream Agreement #3
Upstream Agreement #4
Upstream Agreement #5
Total
(b)
62,050,000
22,500,000
37,018,300
452,311,650
573,879,950
INT.G-15.02
Annual Therms(3)
(c)
0.012414
0.009931
0.015074
0.016171
(d)
770,302
223,456
558,029
7,314,320
8,866,107
Line
No.Transportation
INT-G-15-02
Prices
INT-G-15-02
Annual Cost
(a)
7 Upstream Agreement #1
8 Upstream Agreement #2
9 Upskeam Agreement#3
10 Upstream Agreement #4
11 Upstream Agreement #5
12 Tota!
(b)
62,220,000
37,009,920
453,550,860
37,577,220
590,358,000
(c)
0.013584
0.014550
0,016749
0.016884
845,197
(1)
(d)
538,482
7,596,696
634.443 Qt
9,614,818
13 TotalAnnualCost Difference (Row 12 minus Row 6)
(1) Renegotiated to full rate. See Workpaper 2,Page 1, Lines 8 and 20, Column (d).
(2) Renegotiated to a discounted rate. See Workpaper 2, Page '1, Lines 9 and 21, Column (d).
(a) Daily Contract Demand multiplied by 366 days
(a) See Exhibit 4, Line 6, Column (h)
749,711 (4)
Workpaper No.3
Case No. INT-G-15-02
lntermountain Gas Company
Page 1 of 1
INTERMOUNTAIN GAS COMPANY
Summary of Other Storage Facility Costs
Line
No.
13
14
Line
No.
Storaqe Facilities
(a)
Demand Costs -
Clay Basin I Reservation
Clay Basin ll Reservation
Clay Basin lll Reservalion
Clay Basin I Capacity
Clay Basin ll Capacity
Clay Basin lll Capacity
Total Demand Costs
Storage Demand Charge Credit
Total Costs lncluding Storage Credit
Storaqe Facilities
tNT.G.14-0r
Monthly
Billing Determinant
(b)
266,250
221,880
213,010
31,950,000
26,625,000
25,560,000
84, 1 35,000
tNT-G-14-01
Prices
(c)
tNT-G-14-01 rNT.G.14.0rMonthlyCost Annual Cost
(d)(e)
1
2
3
4
5
o
7
8
(1) $
(1)
(1)
(2)
(2)
(2)
(3)
0.285338 $ 75,971
0.285338 63,311
0.285338 60,780
0.002378 75,977
0.002378 63,314
0.002378 60,782
$ 91 1,652
759,732
729,360
911,724
759,768
729,384
9 Rexburg LNG Facility -
10 TransportationReservation
11 VariableTransportation
12 Total Rexburg LNG Facility Costs
$ 400,1s5 $4,801,620
66,000
22,800
88,800
(1,810,000)
3,080,420
(a)
15 Demand Costs -
16 Clay Basin I Reservation
17 Clay Basin ll Reservation
18 Clay Basin lll Reservation
19 Clay Basin I Capacity
20 Clay Basin ll Capacity
21 Clay Basin lll Capacity
22 Total Demand Costs
lNT.G.1$02
Monthly
Billing Determinant
(b)
266,250 (1)
221,g80 (1)
213,010 (1)
3'1,950,000 (2)
26,625,000 (2)
25,560,000 (2)
84,135,000 (3)
|NT.G-15-02 |NT-G-15-02
(c)
0.285338
0.285338
0.285338
0.002378
0.002378
0.002378
Monthly Cost
(d)
75,971
63,31'l
60,780
75,577
63,314
60,782
rNT-G.15-02
Annual Cost
(e)
91 1,652
759,732
729,360
911,724
759,768
729,384
400,1 35 4,80'1,620
23
24
25
to
1t
28
2S
Rexburg LNG Facility -
Transportation Reservation
Variable Transportation
Total Rexburg LNG Facility Costs
Estimated Storage Demand Charge Credit
Total Costs lncluding Storage Credit
Total Annual Cost Difference lncluding Storage Gredit (Row 28 minus Row 14)
66,000
22,800
88,800
(1,810,000)
(') Charge Based on Maximum Daily Withdrawal
(2)Charge Based on Maximum Contractual Capacity
(3) Non Additive Billing Determinants; lncludes only Capacity Volumes
(a) See Exhibit 4, Line 20, Column (h)
3,080,420
INTERMOUNTAIN GAS COMPANY
Peak Day Analysis for Demand Allocators
Workpaper No.4
Case No. INT-G-15-02
lntermountain Gas Company
Page 1 of 1
TotalPeak Firm Sales
Description
(a)
DEI,AND ALLOCATORS PER CASE iIO. INT.G.1'LOI:
Peak Day Therms
Percent of Total
PROPOSED DEMAND ALLOCATORS PER CASE NO. INT-G-1$02:
Peak Day Usage Per Customer
January 2015 Actual Customers
INT-G-I$02 Peak Day Therms (Line 5 muliFlied by Line 6)
Percent of Total
{r) Contract Demand Therms
R$2 G$l(c) (d)
LV-1 PeakSales(e) (0
R$1
(b)
1
2
3
4
5
6
378,'105
1L!994%
5.87
67,821
398,109
1J.0195%
7.97
234,058
1,865,442
tuzz3%
1,030,778
324393%
34.66
31,916
1,106,209
32,!53!%
25,250
0.79460/.
38,850 (1)
lJ39E6
3,177,508
100.00000/"
333,795
3,408,610
100.0000%
7
8
Workpaper No.5
Case No. INT-G-15-02
lntermountain Gas Company
Page 1 of 5
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lntermountain Gas Company
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Case No. INT-G-15-02
lntermountain Gas Company
Page 3 of 5
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Case No. INT-G-15-02
lntermountain Gas Company
Page 4 of 5
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Case No. INT-G-15-02
lntermountain Gas Company
Page 5 of 5
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Workpaper No.6
Case No. INT-G-15-02
lntermountain Gas Company
Page 1 of 1
INTERIIOUNTAIN GAS COMPANY
Analysis of LV-l Tariff Block 1, Block 2, and Block 3 Adiustments
Description
Block 1
Therm Sales
Block 2
Therm Sales
Block 3
Therm Sales
Line
No.
1
2
3
4
(a)
LV-1 Therm Sales (1/1/14- 12131114)
Bloc*s 1 and 2 Therm Sales
PercentTherm Sales between Blocks 1 and 2
Proposed Adjustment to LV-1 Tariff (1)
LV-1 Therm Sales (1/1/14 - 12131114')
Annualized Adjustment (Line 4 multiplied by Line 5)
(b)
5,805,826
5,805,826
100.0000/o
0
0
0.0007o
(d)(c)(e)
5,805,826
5,805,826
100.000%
0.02434
5,805,826
$ 141,314
141,314
100.000%
141,314
5,805,826
$ 0.02434
(0.06718)
_$_p.042qq
0.00017
(0.06718)
(0.01675)j_Q.08379I
5
6
7 Annualized Adjustment (Line 6)
8 PercentAnnualized Sales included in Block 1 and Block 2
9 Adjustment to Block 1 and 2 (Line 7 multiplied by Line 8)
10 Block 1 and 2 Therms
11 Price AdjustmenUTherm Block 1 and 2 (Line 9 divided by Line 10)12 WACOG Commodity Charge Changs t2r
13 Tohl Price AdjustmenUTherm Block 1 and Block 2
14 Price AdjustmenUTherm Block 3 0)
15 WACOG Commodity Charge Change(2)16 Eliminate INT-G-14-01 Variable Temporary17 Total PdceAdjustmenuThem Block 3
(1) See Exhibit No. 4, Line 31, Column (l) minus the difference of Line 22, Column (f) minus Line 22, Column (c)
(2) See Exhibit No.4,Line22, Column (f) minus Line 22, Column (c)
(3) See Exhibit No. 6, Line 3, Column (e), plus Line No. 4, Column (e)
Line
No.
INTERMOUNTAIN GAS COMPANY
Analysis of Lost and Unaccounted For Gas ("L&U")
Description
Workpaper No.7
Case No. INT-G-15-02
lntermountain Gas Company
Page L of 2
AmountDetail
(a)
Lost and Unaccounted For Gas INT-G-I4-01 (Therms)
ActualOct 13 - Sep 14 L&U (Therms)
ActualOct 13 - Sep 14 Sales
Oct l3 - Sep 14 L&U Factor (line 2 divided by Iine 3)
Lost and Unaccounted For Gas INT-G-I5-02 (Therms)
Projected Oct 14 - Sep 15 L&U (Therms)
Estimated Oct 14 - Sep 15 Sales(1)
Oct 14 - Sep 15 L&U Factor (line 6 divided by Iine 7)
Lost and Unaccounted For Gas INT-G-I5-02 (Dollars)
Lost & Unaccounted For Gas (1910-2159; {z)
Estimated Oct 14 - Sep 15 Sales(1)
L&U rate per therm embedded in base rates
Oct 14 - Sep 15 Collection of Lost & Unaccounted for Gas
Projected L&U (Over)/Under Gollection (Line 10 minus Line l3)
(c)(b)
1
2
3
4
5
6
7
8
880,946
613,948,721
2,288,309
580,060,776
580,060,776$ 0.00182
0.143o/o
0.394Yo
$ (76,166)
1,055,711
_$ (1,131,87ry
10
11
12
13
14
(1) Estimated Oct 14 - Sep 15 Sales (Therms)
RS-1
RS-2
GS-1
lndustrial
TotalSales
(') See Workpaper No. 5, Page 2, Line 17, Column (c)
29,442,728
163,806,894
98,627,422
288,183,732
580,060,776
Workpaper No.7
Case No. INT-G-15-02
lntermountain Gas Company
Page 2 of 2
INTERMOUNTAIN GAS COMPANY
Lost and Unaccounted For Gas Statistics(1)
Check for Dead Orders
Year Check for Dead Orders Found Dead
Accounted
Percent Found Dead For Therms
2010
2011
2012
2013
2014
2015
12,441
10,093
5,089
5,041
6,102
4,561
569
795
513
796
923
745
5%
8%
10%
16%
15%
16%
213,590
258,839
187,091
Occurrences
Drive Rate Errors
Accounted For
ThermsYear
2010
2011
2012
2013
2014
2015 e)
13
14
3
3
15
6
2,331
26,559
6,464
Year Occurrences
Pressure Errors
Accounted For
Therms
2010
2011
2012
2013
2014
2015
19
I
15
17
7
2
(64,400)
10,245
25,015
Occurrences
Loss from Line Breaks
Accounted For
Therms
88,947
49,856
68,221
66,063
119,291
34,815
Gas
Year
2010
2011
2012
2013
2014
2015 Q)
175
154
177
163
187
128
(') Gas loss resulting from these occurrences becomes accounted for gas
(2) Through June 2015
Workpaper No.8
Case No. INT-G-15-02
lntermountain Gas Company
Page 1 of 1
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