20220810Application.pdf

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Lori A. Blattner
Director, Regulatory Affairs
lntermountain Gas Company
Enclosure
cc:Mark Chiles
Preston Carter
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August 10,2022
Ms. Jan Noriyuki
Commission Secretary
Idaho Public Utilities Commission
P.O. Box 83720
Boise, ID 83720-0074
RE: Case No. INT-G-22-04
Dear Ms. Noriyuki:
Attached for consideration by this Commission is an electronic submission of lntermountain Gas
Company's Purchased Gas Cost Adjustment Filing with prices proposed to be effective on October
1,2022.
If you should have any questions regarding the attached, please don't hesitate to contact me at (208)
377-60rs.
Sincerely,
dnAB\M
INTERMOTINTAIN GAS COMPAIYY
CASE NO.INT.C,-2244
APPLICATION,
EXHIBITS,
AI\D
WORKPAPERS
In theMatterof theApplication of W GAS COMPAI\IY
f,'or Authority to l)ecrease its Prices on October 112022
(October 112022 Purchased Gas Cost Adjustment F'iling)
Preston N. Carter, ISB No. 8462
Morgan D. Goodin,ISB No. I I184
Givens Pursley LLP
601 W. Bannock St.
Boise,Idaho 83702
Telephone: (208) 388-l 200
Attorneys for Intermountain Gas Company
In the Matter of the Application of
INTERMOUNTAIN GAS COMPANY
for Authority to Change its Prices
BEFORE THE IDAHO PUBLIC UTILITTES COMMTSSION
Case No.INT-G-22-04
APPLICATION
Intermountain Gas Company ("Intermountain" or "Company"), a subsidiary of MDU
Resources Group,lnc. with general offices located at 555 South Cole Road, Boise, Idaho, pursuant
to the Rules of Procedure of the Idaho Public Utilities Commission ("Commission"), requests
authority, pursuant to Idaho Code Sections 6l-307 and 6l-622, to place into effect October 1,2022
new rate schedules which will decrease its annualized revenues by approximately $7.7 million.
Because of changes in Intermountain's gas related costs, as described more fully in this Application,
Intermountain's eamings will not be impacted as a result of the proposed changes in prices and
revenues. Exhibit No. I is a summary of the overall price changes by class of customer and is
attached and incorporated by reference. Intennountain's current rate schedules showing proposed
changes are attached as Exhibit No. 2 and incorporated by reference. The resulting proposed rate
schedules are attached as Exhibit No. 3 and incorporated by reference.
Please address communications regarding this Application to:
Lori A. Blattner
Director - Regulatory Affairs
lntermountain Gas Company
Post Office Box 7608
Boise,Idaho 83707
Lori.Bl rntsas.com
INTERMouNranq Gas CoN{PAtIY's APPLICATIoN - 2
and
Preston N. Carter
Givens Pursley LLP
601 W. Bannock St.
Boise, Idaho 83702
prestoncarter@g ivensnurslev.com
[e-mail]
ln support of this Application, Intermountain alleges and states as follows:
I.
lntermountain 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.
lntermountain provides natural gas service to the following Idaho communities and counties
and adjoining areas:
Ada County - Boise, Eagle, Garden City, Kun4 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, N*pa Parma, and Wilder;
Caribou County - Bancrofl 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 - Bliss, Gooding, and Wendell;
Jefferson County - Lewisville, Menan, Rigby, and Ririe;
Jerome County - Jerome;
Lincoln County - Shoshone;
Madison County - Rexburg, and Sugar City;
Minidoka County - Heyburn, Paul, and Rupert;
Owyhee County - Bruneau, Marsing, 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.
INTSRMOT]NTAIN GAs COIUPANY,S APPLICATIoN . 3
Intermountain's properties in these locations consist of transmission pipelines, liquefied
natural gas storage facilities, compressor stations, distribution mains, services, meters and
regulators, and general plant and equipment.
II.
With this Application, Intermountain seeks to pass through to each of its customer classes
changes in gas related costs resulting from: l) costs billed to lntermountain from firm transportation
providers including Northwest Pipeline LLC ('t,lorthwest" or'Northwest Pipeline"), 2) a decrease
in Intermountain's Weighted Average Cost of Gas ('WACOG"), 3) an updated customer allocation
of gas related costs pursuant to the Company's Purchased Gas Cost Adjusbnent ('.PGA") provision,
4) the inclusion of temporary surcharges and credits for one year relating to natural gas purchases
and interstate transportation costs from Intermountain's deferred gas cost accounts, 5) benefits
resulting from lntermountain's management of its storage and firm capacrty rights on various
pipeline systems,6) benefits associated with the sale of liquefied natural gas from the Company's
Nampa, Idaho facility,T)the recovery of deferred in-person customer payment fees, and 8) a refund
of over-collected Residential Energy Efficiency funds. Intermountain also seeks to eliminate the
temporary surcharges and credits included in its current prices during the past 12 months, pursuant
to Case No. INT-G-21-04. If approved, these changes would result in a price decrease to all of
Intermountain's customers.
These price changes 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. NT-G-95-1, and additionally approved through subsequent proceedings.
INreRuouNreN GES COIIPA}.TY,S APPLICATION - 4
[I.
The Commission approved the current temporary and transportation prices in Order
No. 35182, Case No. INT-G-21-04. Prices related to the cost of gas were approved in Order
No. 35479, Case No. INT-G-22-02.
ry.
lntermountain'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 which have
occurred since Intermountain's PGA filing in Case No. INT-G-21-04. Exhibit No. 4, which
contains pertinent excerpts from applicable pipeline tariffs, is attached and incorporated by
reference. Suppliers upstream of Northwest Pipeline filed a net increase to rates of 52,073,439. The
net price increase resulting from these changes of $1,915,019 is included on Exhibit No. 5, Lines 3-
6. Exhibit No. 5 is attached and incorporated by reference.
v.
Intermountain continues to contract a variety of natural gas storage assets on Northwest
Pipeline's system as well as with Dominion Energy Questar Pipeline, LLC ("Dominion"). In
addition to providing operational reliability, these storage contracts can provide significant price
stability to customers.
Furthermore, lntermountain continues to effectively manage its natural gas storage assets
at Northwest's Jackson Prairie and Dominion's Clay Basin storage facilities. Supporting
documents to Line 20 of Exhibit No. 5 show Intermountain's management of these storage assets
resulted in $2.3 million in savings for customers.
INTERMOLTNTAIN GAS CoN4PANY'S APPLICATIoN - 5
As seen on Exhibit No. 5, Lines 7 through 20, there are no proposed changes to
Intermountain' s prices resulting from Intermountain's storage contracts.
VI.
The WACOG reflected in Intermountain's proposed prices is $0.39216 per therm, as shown
on Exhibit No. 5, Line22, Col. (f). This compares to $0.42405 per therm currently included in the
Company's tariffs.
In Case No. INT-G-22-02 the Company filed an interim PGA to increase the WACOG from
$0.26000 per therm to $0.42405 per therm effective August 1,2022. This change was approved by
the Commission in OrderNo. 35479. As the Company explained in that case, several factors
contributed to the significant increase in the WACOG since October 2021. These include a rebound
in demand, lower than average storage levels, high levels of liquefied natural gas exports, and other
global events. Although these factors are still at play, the Company's WACOG estimate has
decreased slightly since filing the interim PGA. The anticipation of cooler weather this fall and the
resulting lower electric generation demand seem to be helping to settle what is still a very volatile
natural gas market.
To help offset some ofthe volatility in the market, 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
traditionally 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 winteroflowing" supplies thus stabilizing a portion of the supply price and
INTERMOIINTAI.I GAS CON,PANY'S APPT-ICINON . 6
insulating it from the significant volatility seen in the futures market.
lntermountain 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 the2022 -2023 PGA period.Intermountain will employ, in
addition to those fixed price agreements already in place, cost effective price arrangements to
further secure the price of flowing gas embedded within this Application when, and if, those pricing
opporhrnities materialize in the marketplace.
Intermountain believes that timely natural gas price signals enhance its customers' 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 Company's Energy Effrciency programs, 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.
VIL
Pursuant to the Commission's Order in Case No. INT-G-21-04,Intermountain included
temporary credits in its October 1,2021prices for the principal reason of passing back to its
customers deferred gas cost benefits. Line 27 of Exhibit No. 5 reflects the elimination of these
temporary credits.
In summary, Exhibit No. 5 outlines the price changes in 1) Intermountain's base rate gas
costs as previously described, 2) its rate class allocation, and 3) net adjustments to temporary
surcharges or credits flowing through to Intermountain's customers.
INTERMoI,NTAIN GAS Cotr,PANY'S APPLICATIoN - 7
vIII.
Under the Company's PGA tarifl tntermountain's proposed prices will be adjusted for
updated customer class sales volumes and purchased gas cost allocations. Intermountain's proposed
prices include a gas transportation cost adjustment pursuant to these PGA provisions, as outlined on
Exhibit No. 6, Line 25. The price impact of this adjustment is included on Exhibit No. 5, Line 28.
The Gas Transportation Cost resulting from the adjustment plus the annual difference in demand
charges from Exhibit No. 5, Lines I - 20, Col. (h) is shown on Exhibit No. 6, Line29. Exhibit No. 6
is attached and incorporated by reference.
IX.
Intermountain proposes to pass through to its customers the benefits that will be generated
from the management of its transportation capacity, totaling $6.6 million as outlined on Exhibit No.
8. These benefits include credits generated through releases of a portion of Intermountain's firm
capacity rights on Northwest Pipeline as well as credits generated from releases of Intermountain's
upstream pipeline capacity. Intermountain proposes to pass back these credit amounts via the per
therm credits, as detailed on Exhibit No. 8 and included on Exhibit No. 7, Line 1. Exhibit Nos. 7
and 8 are attached and incorporated by reference.
x.
Intermountain proposes to allocate defened gas costs from its Account No. l9l balance to
its customers through temporary price adjustments to be effective during the l2-month period from
October 1,2022 to September 30,2023, as follows:
I ) Intermountain has deferred fixed gas costs in its Account No. I 9l . The credit amount
shown on Exhibit No. 9, Line 7, Col. (b) of $7.4 million is athibutable to a hue-up of the collection
of interstate pipeline capacity costs, the true-up of expense issues previously ruled on by this
INTERMoUNTanq GES CON,PANY,S APPLICATION - 8
Commission, and mitigating capacity release credits generated from the incremental release of
Intermountain's pipeline capacity. lntermountain proposes to true-up these balances via the per
therm debits and credits, as detailed on Exhibit No. 9 and included on Exhibit No. 7, Line 2. Exhibit
No. 9 is attached and incorporated by reference.
2) lntermountain has also deferred in its Account No. l9l a variable gas cost debit of $22
million, as shown on Exhibit No. 10, Line2, Col. (b). This defened debit is attributable to
lntermountain's variable gas costs since October 1,2021. Intermountain proposes to collect this
balance via a per therm debit, as shown on Exhibit No. 10, Line 4, Col. (b) and included on Exhibit
No. 7, Line 3.
3) Finally, lntermountain has deferred in its Account No. l9l deferred gas costs related to
Lost and Unaccounted for Gas as shown on Exhibit No. I 0, Lines 5 through 26, Col. (b). This
deferral results in a per therm decrease to lntermountain's customers, as illustrated on Exhibit No.
I0. This per therm decrease is included on ExhibitNo. 7, Line 3. Exhibit No. 10 is attached and
incorporated by reference.
xr.
Pursuant to Commission Order No. 32793, Case No. INT-G-13-02, Intermountain has
deferred in its Account No. l9l gas cost credits associated with sales of liquefied natural gas at its
Nampa, Idaho facility. Intermountain proposes to pass back this $0.2 million sales credit as outlined
onExhibitNo. ll,LineT andshownonExhibitNo.T,Line4.ExhibitNo. ll isattachedand
incorporated by reference.
XII.
As directed in Commission OrderNo.33887, CaseNo.INT-G-I7-05,Intermountain
established a regulatory asset to amortize over a five-year period $378,614 related to external
INTERMOUNTAIN GAS COMPANY'S APPLICATION - 9
General Rate Case costs associated with Case No. INT-G-16-02. The five-year amortization period
will end on September 30,2022. As seen on Exhibit No. 12, there is a small remaining balance
associated with the estimated amortization through the end of the period as well as the true-up of
September 30,2021remaining balances previously ruled upon by this Commission. The Company
proposes to roll this small remaining balance to the Lost and Unaccounted for Gas beginning
balance (Account l9l.2l2) for amortization in the next PGA. Exhibit No. 12 is attached and
incorporated by reference.
XIII.
In Commission OrderNo.34099, Case No. INT-G-I8-01, the Company was directed to
defer and later collect through the PGA the fees associated with in-person customer payments at
third party vendors. This authorization was extended in OrderNo.35047, Case No. INT-G-21-02.
Exhibit No. 13 summarizes the customer class surcharges associated with these previously deferred
costs which are included on Exhibit No. 7, Line 5. Exhibit No. l3 is attached and incorporated by
reference.
xrv.
In Commission Order No. 35479, Case No. INT-G-22-02, the Commission encouraged the
Company explore ways to reduce future increases, including potentially adjusting the EEC-RS
Residential Energy Effrciency Charge. In Case No. INT-G-22-05, which is being filed concurrently
with this case, the Company is l) requesting approval of a one-time transfer of $4.85 million in
over-collected Energy Efficiency Residential Program deferral balance to the PGA for refund to
residential customers, and2) approval of a decrease in the Residential Energy Efficiency Charge
effective October 1,2022. If the Commission approves the $4.85 million refund, ExhibitNo. 14
calculates the resulting per therm credit that would be retumed to residential customers through the
INTERMoTINTAI.I GAS COIVfANY,S APPLICATION - IO
PGA, if approved in this proceeding. The per therm credit is included on Exhibit No. 7, Line 6.
Exhibit No. 14 is attached and incorporated by reference.
xv.
Intermountain has allocated the proposed price changes to each of its customer classes based
upon the Company's PGA provision. However, a straight cents pertherm price change was not
utilized for the LV-l tariffas no fixed costs are currently recovered in the tail block of the LV-l
tariff. The proposed changes in the WACOG, and variable deferred debits and credits as outlined
on Exhibit No. 7, Lines 3 and 4, 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.
xvl.
As outlined on Exhibit No. 2, Page l, Lines 2l through 29,the T-3 and T-4 tarifts include
the following adjustments: a) the removal of existing temporary price changes, and b) the inclusion
of proposed temporary price changes from Exhibit No. 7. The net change from these
aforementioned adjustments results in a rate decrease for the Company's T-3 and T4 customers.
XVII.
The proposed price changes herein requested among the classes of service of Intermountain
reflect a just fair, and equitable pass-through of changes in gas related costs to Intermountain's
customers.
xvlII.
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
INTERMoUNTATN GAS CoIIPANY'S APPLICAIoN - I I
afiached and inoorporatcd by reference. Copies of&is Application, its Exhibits, and Worlgapers
have bem providod to those parties regularly intenvening in Intermountain's rate procecdings.
)mt
Iiltermountain r€qu€sts that this matlerbe handled unde'r modtfied prccdure pursuant to
Rules z0lAM ofthe Commission's Rules ofhocedr.rne. Intermorurtain stands ready for immdiate
oonsiderdion of this mder.
INTER},ToUI.IrA$I GAS CO}OAI.IY'S APPLICATION . 12
)o(
lntermountain respectfully petitions the tdaho Public Utilities Commission as follows:
a. That the proposed rate schedules submitted as ExhibitNo. 3 be approved without
suspension and made effective as of October 1,2022 in the manner shown on Exhibit
No.3;
b. That the filing requirement for the Deferred Gas Cost Balance, LNG Sales Cost Benefit
Analysis, and Weighted Average Cost of Gas reports be maintained at quarterly
frequency;
c. That this Application be heard and acted upon without hearing under modified procedure;
d. For such other relief as this Commission may determine proper
DATED: August 10,2022
INTERMOUNTAIN GAS COMPANY GIVENS PURSLEY LLP
and
By
Lori A. Blattner
Director - Regulatory Affairs
dhLBLM .P 6--z----By
Preston N. Carter
Attorney for Intermountain Gas Company
-----
INTERMoI.INTAtr.I GAS CoIVPANY,S APPLICATIoN - I 3
CERTIFICATE OF SERVICE
I certifr that on August 10,2022, a fiue and correct copy of the foregoing Case No. INT-G-
22-04 was served upon the following parties via the manner indicated below:
Ed Finklea
Allianoe of Westem Energy Consumers
545 Grandview Drive
Ashlan4 OR97520
efi [e-mail]
Michael Hale
J. R SimplotCompany
1099 W. Front St.
Boise, D*83702
[e-mail]
Elec'tronic Mail
Electronic Mail
flnABltM
Lori A. Blattrrer
Director - Regulatory Atrairs
INTERMoI]NTAIN GAS CO}VfANY'S APPLICATION . 13
E)ilIIBM NO. 1
CASE NO. INT-G-22.04
INTERMOT]NTAIN GAS COMPAI\TY
SI]MMARY OX' PRICts CHANGES
(2 pages)
Exhiblt No. 1
Case No. INT-G-22-04
lntermountain Gas Company
Page 1 of2
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Exhibit No. 1
Case No. INT-G22-(X
lntermounlain Gas Company
Paq,e2ot2
Llnc llo.D!|crldon
lt{TERilOut{rANG S COilP t{Y
AIIALYSF OF !ilT+224T PflCE CM,IIGE
Anount Tohl
(r)
Ihhndr:
INT-G21{4 Temporai* Reversed
Add INT{-22{4 Terporahs:
Fked Detuned Gas Cosb
Vai*le Dolbn€d G6 Cosh
Lost ard Unaccountod For Ga Costs
LNG Sdes Cndit
ln-Person Paynnnt Fees Defenal
Residentid Ercrgy Eftiency Credit
Totd Tamporahs Added
Tdrl Dt otrd.
Bere Rrte Pdce Chrnoe:
Fhed Coat Chaqes:
NWP TF-l Reservalion (Full Rate)
UWP TF-l Reservation (Dscounbd)
Upstrcam Capacity (Full Rde)
Upsteam Cap*ity (Discounted)
SG$2F and L$2F
OtherSbrage Faility
Totd Fixed Cost Choge
Changos in WACOG
Realocation of FixEd Cosb
Totll Bl3rRlocftleGhugr.
Td.l Annud Prlcc Chrng6
$ (11,054,612) 0
22,075,600 0l
(1,222,513) r')
(221,9$) o
70,370 (')
(1,850,000) o)
$ (158,120 (E
-o
1,254,463 (10)
918,976 (rr)
- (12)
00
1,915,019
(13,249,234) {r1)
_(2,4m,804_(")
1,796,852
$ 6,052,436
(r3,7s5,022)
$ r/,702,586)
g@"'
i 5,213
o)(c)
4,255,584 (r)
,|
2
3
4
5
6
7
8
9
't0
11
12
't3
14
't5
16
17
t8
19
m
21
u
23
24
$
25
26
Annud Prica Change per Exhibit ltlo. 1, Page I
Diftrence Due to Rounding
(tl Temporary prices fion INT-G2'i44lirms Exhibit No. 1, Page 1, Lines 2 - 4, 7 ard 9, Column (b)
e) See Exhibit No. 8, Line 3, Column (b), plus Exhibit No. 9, Line 7, Column (b)
F) See Exhibit No. 10, Line 2, Colunn (b)o See Exhibit No. 10, Line l0 plus Line 18, Column (b)o See ExhibitNo. ll, Line5, Colunn (b)(t) See Exhibit No. ,l3, Line 4 Colurm (b)
(7) See Exhibit No. 14 Lina 1, Column (b)
P) Soe exhlbit Ho. 5, Line 3, Column (h)
P) See e*ribit Ho. 5, Une 4, Column (h)
(rq See Exhibit No. 5, Une 5, Cdumn (h)
(tt) See ExhibitNo. S, Line6, Column (h)
('a See Exhibit No. 5, sum of Line 9 - .l9, Column (h)
(r0 See Exhibit No, 5, Lin6 20, Column (h)
0a See Bhibit No. 5, Line 22, Cdunn (h)
0q Sse Exhibit No. 5, Line 28, Columns (i) - (k), times Line 24, Columns (i) - (k)
0t) See Exhitrit No. 1, P4e'1, Line ll, Column (a)
E}MIBIT NO.2
cAsE NO. INT-G-22-04
INTERMOITNTAIN GAS COMPAI\IY
CT'RRENT TARIXT'S
Showing Propooed Prioe Changes
(f0 pages)
Exhibit No.2
Case No. INT-G22-04
lntermourtain Gas Company
Page 1 of10
INTERIUIOU NTAII{ GAS COMPAI{Y
Comparleon of Propooed October l, 2022 Prices
To Cumently Approved Prices
Line
l{o.Rate Class
Cunently
Apprcved
Pdces
Proposed
Adjustment
Proposed
October l,1122
Pdcet
(a)o)
$ 0.76073 $
(c)
(0.02152) $
0.76799
0.7u51
0.721U
0.65328
0.71864
0.65008
0.73980
0.76479
0.74131
0.7't864
0.65008
0.30000
0.54361
0.52572
0.M$n
0.03816
0.0'ts32
0.00s41
0.28189
0.02395
0.00847
0.00260
(0.01363)
(0.01363)
(0.01363)
(0.01363)
(0.01363)
(0.01363)
(0.00362)
(0.01363)
(0.01363)
(0.01363)
(0.01363)
(0,00188) F)
(0,00188) G)
(0.00144) ({)
(o.ooo4o F)
(o.ooo45; tst
(o,oog451 tsl
(0.00154 6)
(d)
0.73921
0.7s436
0.73088
0.7082',1
0.63965
0.70501
0,630rs
0.73618
0.75'l'16
0.72768
0.7050'l
0.63645
0.30000
0.54173
0.52384
0.44733
0.032,|
0.01487
0.00496
0,28032
0.02395
0.00847
0.00260
1RS
G9r
LV.t
2
3
4
5
b
7
8
9
10
11
12
13
14
15
16
17
't8
19
20
21
22
23
24
25
26
27
28
29
Block 1
Block 2
Block 3
Block 4
CNG Fuel
Block 1
Block 2
I$Rfl)
ls4(4
T.3
T.f
Block 1
Block 2
Block 3
Block 4
Demand Charye
Block 1
Block 2
Block 3
Block 1
Block 2
Block 3
Demand Charge
Block 1
Block 2
Block 3
(r) The l$R price is based on the RS price and receives the sarne PGA adjustmenb, except br tre Reskienlial
Energy Efrciency Crcdit on Exhibit No. 14, Line 3, Column (c)
(2) The lS-C pdce is based on the G$1 pdce and reeives the same PGA adiustnents
P) See Wofipaper No. 6, Line 13, Column (e)
(a) See Workpaper No. 6, Line '17, Column (e)
(s) Remove INT{-2144 temponary, ($0.00037), and add temponary fom Exhibit No. 7
Line 7, Column (e)
(e) Remove INT{-21-04 temponry, ($0.0181.l), and add temponary from Exhibrl No. 7
Line 7, Column (f)
Exhibit No.2
Case No. INT-G22{4
lrilermountain Gas Company
Page 2 of 10
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l.P.U.C. Gas Tariff
Rate Schedules
N*thRevis€d Eh Sheet No. 1 (Pase 1 of 1)
Name
of t filily lntermountain Gas Company
Exhibit No. 2
Case No. INT-G-22-04
lntermounlain Gas Company
Page 3 of 10
IDAHO PUBLIC UTIL]TIES COMMISSIONApproved EftctlveJulf*9sll e'ug-+3e33
Pe+€fH€{7e
Jan Noriyuki Secretary
Rate Schedule RS
RESIDENTIAL SERVICE
APPLICABILITY:
Applicable to any customer using natural gas for residential purposes.
RATE:
Mon$ly minimum charge is $e Customer Charge.
Customer Charge:
PerTherm Charge:
$5.50 per bill
$0#6e73. $0-23921
1) Temporary purchased gas cost adjusfnent
2) Irveighted avenge cost of gas
3) Gas transportation cost
'lncludes the following
Cost of Gas:($0.000s7)
$0.39216
$0.16364
Distribution Cost:
EE Charge:
$0.16305
$0.02093
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for the cost of purchased gas as provided for in Rate Schedule PGA.
This adjustnent is incorporabd into the calculation of the Cost of Gas stated on customer bills.
ENERGY EFFICIENCY CHARGE ADJUSTMENT:
This tariff is subject to an adjustnent for costs related to the Company's Energy Eficiency progrcm as
provided for in Rate Schedule EEGRS. The Energy Efficiency Charye is separately stated on customer bills.
SERVICE CONDITIONS:
All natural gas seMce hereunder is subjecl to the General Service Provisions of the Company's Tariff, of
which $is rate schedule is a parl.
rssued by: lntermountain Gas Gompany
Blattner TiUe: Director - Regulatory Affairs
($0€1+73)
$0J?105
$el€4{3,
l.P.U.C. Gas Tariff
Rate Scfiedules
Sixhrfeu* Revised Sixtv-Fiflh Sheet No. 3 (Paoe I of 2)
Narno lntermountain Gas Companydtnility
Exhibit No.2
Case No. INT-G-22-04
lntermountain Gas Company
Page 4 of 10
$0.75436
$0.7308q
200 herms perbill@
1,800 therms per bill@
8,000 therms per bill @
10,000 therms per bill @
200 therms per bill @
1,800 therms per bill @
8,000 therms per bill @
10,000 therms per bill @
IDAHO PUBLIC UTILITIES COtulUlSSlONApproved Effective*ilt49r20il2 *ug#'{3*
Po+eil{6,Fe
Jan Norlyuki Secretary
Rate Schedule GS-l
GENERAL SERVICE
APPLICABILITY:
Applicable to customers whose rcquirements for natural gas do not exceed 2,000 therms per day, at any point
on the Company's disbibution system. Requirements in exess of 2,0fi) therms per day may be allowed at
the Company's discretion.
RATE:
Monthly minimum charge is the Customer Charge.
Customer Charge:
PerTherm Charge:
'lncludes the bllowing:
Cost ofGas:
Distribution Cost:
$9.50 per bill
Block One:
Block Two:
Block Thpe:
Block Four:
Block One:
Block Two:
Block Three:
Block Four:
First
Next
Next
Over
First
Next
Next
Over
$ffi
$9r44++r
$0,72184*
$e€5ee8'
$0.7082'!
s0.63965
1) Temporary purchased gas cost adjustnent
2) V\bighted average cost of gas
3) Gas transportation cost
($€+e56e) $0.01445
$*4i!.le5
$0,{€{€e
$0.1846s
$0.161 1 7
$0.138s0
$0.06994
$0.39216
$0.15990
EE Charge:$0.00320
tssued by: lntermountain Gas Gompany
By: Lod A. Blattner __-- TiUe: Director- Regulatory Affairs
Eft"aire, A*rgc€F{+€ra3 Odobet 1' 2022
LP.U.C. Gas Tariff
Rate Schedules
Sirry*c+th Revised Sldv-Fifi h Sheet No. 3 (Paoe 2 of 2)
Name lntermountain Gas Companyof L,tility
Rate Schedule GS-l
GENERAL SERVICE
(Continued)
For separately metered deliveries of gas utilized solely as Compressed Natural Gas Fuel in vehicular intemal
combustion engines.
Customer Charge: $9.50 per bill
PerTherm Charge:
'lncludes the following:
Cost of Gas:
Distribution Cost:
First 10,000 therms per bill @
Over 10,000 therms per bill @
IDAHO PUBLIC UTILIT]ES COMMISSIONApproved Effectivelal!15,1{E4 LEg-47*0e*
P€r€N{64+e
Jan Noriyuki Secretary
$eiH€64i $0.70501
$es6ees. $0.6364s
$se0660) $0'01,{45
Exhibit No.2
Case No. INT-G-22-04
lntermountain Gas Company
Page 5 of 10
$0.39216
$0.15990
Block One:
Block Two:
1) Temporary purchased gas cost adjustTlent
2) Weighted average cost of gas
3) Gas transportation cost
Block One: First 10,000 thems per bill
Block Two: Over 10,0(X) therms per bill
@
@
$0'44.{eE
$e{€4€s
$0.1 3850
$0.06994
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for the cost of purchased gas as provided for in Rate Schedule PGA
This adjustnent is incorporated into the calculation of the Cost of Gas stated on custorner bills.
ENERGY EFFIGIENCY CHARGE ADJUSTMENT:
This tariff is subject to an adjusfnent for costs related to the Company's Energy Effciency progmm as
provided for in Rate Schedule EEC-GS. The Energy Effciency Charge is not applicable to gas utilized solely
as Compressed Natural Gas Fuel in vehicular inErnal combustion engines. The Energy Effciency Chaqe is
separately stated on customer bilb.
SERVICE CONDITIONS:
All natural gas seMce hereunder is subject to he General Service Provisions of the Company's Tariff,
of which this rate schedule is a part.
lssued by: lntermountain Gas Company
By: Lori A. Blattner , , - Tifle: Director - Regulatory Affairs
Eifective: A11cc€tg23 Odobet 1.2022
Exhibit No.2
Case No. INT-G-22-04
lntermountain Gas Company
Page 6 of 10
l.P.U.C. Gas Tarifi
Rate Schedulesi*"nti*n nevisea Twentv#irst SheetNo.4 (Paoe1of2)
Name
of t tilitv lntermountain Gas Gompany
IDAHO PUBLIC UTIL]TIES COMTIISSIONApproved EffectiveJult40r20iH} l*rg-*'4032
Po{L€$l{fl+e
Jan Noriyuki Secretary
Rate Schedule lS-R
RESIDENTIAL INTERRUPTIBLE SNOWMELT SERVICE
APPLIGABILITY:
Applicable to any residential customer otheruise eligible to Bceive service under Rate Schedule RS who
has added natural gas snowmelt equipment after 6/1/2010. The intended use of the snowmelt equipment is
to melt snovy and/or ice on sidewalks, driveways or any other simihr appurGnances. Any and all such
applications meeting he above criteria will be subject to service under Rate Schedule lS* and will be
separately and individually meEred. All seMce hereunder is interuptible at the sole discretion of the
Company.
FACILITY REIMBURSEMENT CHARGE:
All new intenuptible Snowmelt service customers are required to pay for the cost of the Snowmelt meter set
and other related f;acility and equipment cosb, prior to he 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
provirled, however, the Company can reasonably accommodate said relocation and Customer agrees to
pay all relabd costs.
RATE:
Monthly minimum charge is he CustomerCharge.
Customer Charge:
Per Therm Charge:
*lncludes the bllowing:
Cost of Gas:
$5.50 per bill
$eftege- $0.73618
1) Temporary purchased gas cost adjustnent
2) WeQhted average cost of gas
3) Gas transportation cost
{$O$fi7e} $0'01733
$e4iHe6 s0.39216
$el€a{43 $0.1636'l
Distribution Cost:$0.16305
PURCHASED GAS COST ADJUSTMENT:
This tariff is subjed to an adjustment br the cost of purchased gas as proMded for in Rate Schedule PGA.
This adjustnent is incorporated into the calculation of the Cost of Gas stated on customer bills.
lssued by: lntermountain Gas Company
Tifle: DireclorBy: Lori A Blattner
Effective:October 1. 2022 - Regulatory Affairs
Exhibit No.2
Case No. INT-G-22-04
lnlermountain Gas Company
Page 7 of 10
l.P.U.C. Gas Tariff
Rate Schedules
l,lii€te€6{h Revised Twentieth Sheet No. 5 (Paoe 'l of 2)
Name
of Lnilitv lntermountain Gas Company
IDAHO PUBLIC UTILITIES COIIMISSIONApproved EffectiveJuly49r*013 Lug-{r3022
PGr€Sl{54+9
Jan Noriyuki Secretary
$0,76179" $0.75116
$eJ#3+r $0.72768
$9,71861* $0.70501
$es5908-_$0.63645
Rate Schedule !S-C
SMALL COMMERICAL INTERRU PTIBLE SNOWM ELT SERVICE
APPLICABILITY:
Applicable to any customer otherwise eligible to reoeive gas service under Rate Schedule GS-1 who has
added natural gas snowmelt equipment after 61112010. The intended use of the snowmelt equipment is to
melt snow and/or ice on sidewalks, drivarays or any other similar appurtenances. Any and all such
applications meeting the above criteria will be subject to seMe under Rate Schedule l$C and will be
separately and individually metered. All service hereunder is interuptible at the sole discretion of the
Company.
FACILITY REIMBURSEMENT CHARGE:
All new intenuptible Snowmelt service customers are required to pay for the cost of the Snowmelt meter set
and other related facility and equipment cosB, prior to the installation of the mebr set. tury request to alter
the physical location of the meter set and related facilities from Gompany's initial design may be granted
provided, however, the Company can reasonably accommodate said relocation and Customer agrees to pay
all related cosb.
RATE:
Monthly minimum charge is the Customer Charge.
Customer Charge:
Per Therm Charge:
$9.50 per bill
*lncludes the following:
Cost of Gas:
Distribution Charge:
Block One:
Block Two:
Block Three:
Block Four:
Block One:
Block Two:
Block Three:
Block Four:
200 therms per
1,800 therms per
8,000 thems per
10,000 therms per
200 herms perbill @
1,800 therms per bill @
8,000 therms per bill@
10,000 therms per bill@
First
Next
Next
Over
First
Next
Next
Over
bil@
bil@
bifl@
biil @
1) Temporary purchased gas cost adjustnent
2) \lGighted average oost of gas
3) Gas transportation cost
($0€06€0)
$e.4e4e6
$oj+r€s
$0.18465
$0.161 17
$0.13850
$0.06994
$0.01,t45
$0.39216
$0.15990
tssued by: lntermountain Gas Company
By: Lori A Blattner Tite: Directcr - Regulatory Affairs
EiEaive: A€€u€t-1.2€r2e Oclobet 1. 2022
LP.U.C. Gas Tariff
Rate Schedules
serentr#ieeLltevised seventv-second Sheet No. 7 Paoe 1 ofZl
Name
of tnilitv lntermountain Gas Company
Exhibit No. 2
Case No. INT-G-22-04
lntermountain Gas Company
Page 8 of 10
Rate Schedule LV-l
LARGEVOLUME FIRM SALES SERVICE
AVAILAB!LITY:
Available at any mutually agreeable delivery point on the Companfs distribution system to any existing
customer receiving seMce under the Compan/s rate schedule LV-l 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 seMce contrac{ for firm sales service in excess of 200,000 $erms per year.
MONTHLY RATE:
Demand Charge: $0.30000 per MDFQ therm
250,000 therms per bill @
500,000 therms per bill @
750,000 therms per bill @
IDAHO PUBLIC UTILITIES COMMISSIONApproved EfhctiveJttly+Hll *ugrffi23
Pe+€il{5479
Jan Noriyuki Secretary
$0#/€e+' $0.54173
$ei6e5ie. S0.52384
ggA4efrt $0.,14733
Per Therm Charge:
*lncludes the iollowing
Cost of Gas:
Distribution Cost:
Block One:
BlockTwo:
Block Three:
Block One:
BlockTwo:
BlockThrce:
First
Next
Over
1) Temporary purchased gas cost adjustnent
Block One and Two
Block Three
2) l reighted average cost of gas
3) Gas transportation cost (Block One and Two only)
$e€0{e8}
$€€31€5
$e#4e5
$eos{54
$0.03000
$0.01211
$0.00307
$0.03247
$0.05210
$0.39216
$0.08710
First
Next
Over
250,000 therms per bill @
500,000 therms per bill @
750,000 therms per bill @
2.
3.
PURCHASED GAS COST ADJUSTMENT:
This tariff is subjeci to an adjustment for the cost of purchased gas as provided for in Rate Schedule PC;A.
This adjustnent is incorporated into the calculation of the Cost of Gas stiated on customer bills.
SERVICE CONDITIONS:
1. All natural gas service hereunder is subject to the General Service Provisions of the Company's
Taritr, of which this Rate Schedule is a paft.
The customer shall negotiate with the Company, a mutually agreeable Maximum Daily Firm Quantig
(MDFO), which will be stated in and in effect throughout the term of the service contract.
The monthly Demand Charge will be equal to the MDFQ times the Demand Charge rate. Demand
Charge relief will be afforded to those LV-1 customers when circumstances impacted by force
majeure events prevent the Company from delivering natural gas to the custome/s meter.
tssued by: lntermountain Gas Company
By: Lori A. Blather Tide: Direclor- Regulatory Affairs
Efiective: flrgu€tsffi3e Odobet 1,2022
Exhibit No. 2
Case No. INT-G-22-(N
lntermountain Gas Company
Page 9 of 10
l.P.U.C. Gas Tariff
Rate Schedules
Twentv Firet Revis€d Twentv-Second Sheet No. 8 (Paoe ,l of 1)
Name
of Lnilitv Intermountain Gas Company
IDAHO PUBLTC UTIL]TIES COMMISSIONApproved Efbc-tiveilov#6#+1 eee;{rfo++
Jan Noriyuki Secretary
Rate Schedule T-3
INTERRUPTIBLE DISTRIBUTION TRANSPORTATION SERVICE
AVAILABILITY:
Available at any point on the Company's distribution system to any customer upon execution of a one year
minimum written service contract.
MONTHLY RATE:
Per Therm Charge: Block One: First IOO,OOO therms transported @ $gOgef+. $0.03771
Block Two: Next 50,000 therms transported @ $m153e- $0'01'|87
Block Three: Over 15O,OOO therms transported @ $e€05/t+. $0.00496
*lncludes temporary purchased gas cost adjustment of ($e€S0ea($0.00082)
ANNUAL MINIMUM BILL:
The customer shall be subject to the payment of an annual minimum bill based on annual usage of 200,000
therms. The deficit usage below 200,000 therms shall be billed at the T-3 Block 1 rate.
PURGHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjusfnent for the cost of purchased gas as provided for in Rate Schedule PGA.
This adjustnent is incorporated into the calculation of the Cost of Gas stated on customer bills.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the Company's
Tariff, of which this Rate Schedule is a part.
This service does not include the cost of the customeds gas supply or the interstate pipeline capacity.
The customer is responsible for procuring its own supply of natural gas and transportation to
lntermountain's distribution system under this Rate Schedule.
The customer understands and agrees that the Company is not responsible to deliver gas supplies
to the customer which have not been nominated, scheduled, and delivered by the interstate pipeline
to the designated city gate.
The Company, in its sole discretion, shall determine whether or not it has adequate capacity to
accommodate transportation of the customeis gas supply on the Company's distribution system.
lf requested by the Company, the customer expressly agrees to immediately curtail or interrupt its
operations during periods of capaci$ constraints on the Company's distribution system.
tssued by: lntermountain Gas Company
By: Lori A. Blattner Tifle: Director-RegulatoryAffairs
Effective: 9eeember{#3+ Ocl'ober 1, 2022
1.
2.
3.
4.
5.
|.P.U.C. Gas Tariff
Rate Schedules
*.ren{i€th Revised T\,\rentv-First Sheet No. I (Paoe I of 2)
Name
of l.nililv lntermountaan Gas Company
Exhibit No.2
Case No. INT-G-22-04
lntermountain Gas Company
Page 10 of 10
IDAHO PUBLIC UTILITIES COMMISSIONApproved Effec'tiveil€tr+qee+t goo+,+*+
Jan Norlyukl Secretary
Rate Schedule T4
FIRM DISTRIBUTION ONLY TRANSPORTATION SERVICE
AVAILABILITY:
Available at any mutually agreeable delivery point on the Company's distribution system to any customer
upon execution of a one year minimum written service contract for firm distribution transportation service in
excess of 200,000 therms per year.
MONTHLY RATE:
Demand Charge:$0*8{€e per MDFQ therm* $0.28032
PerTherm Charge:Block One:
Block Two:
Block Three:
First
Next
Over
250,000 therms transported @ $0.02395
500,000 therms transported @ $0.00847
750,000 therms transported @ $0.00260
*lncludes Emporary purchased gas cost adjustment of $e€{€+4} ($0.01968)
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustnent for the cost of purchased gas as provided for in Rate Schedule PGA.
This adjustnent is incorporated into the calculation of the Cost of Gas stated on customer bills.
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. This service does not include the cost of the custome/s gas supply of the interstate pipeline capacity.
The customer is responsible for procuring its own supply of natural gas and transportation to
lntennountain's distribution system under thie Rate Schedule.
3. 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.
4. The customershall negotiate with the Company, a mutually agrceable Maximum Daily Firm Quantity
(MDFO), which will be stated in and in efbct throughout the term of the service contract.
5. The monthly Demand Charge will be equal to the MDFQ times the Demand Charge rate. Demand
Charge relief will be afforded to those T-4 customers when circumstances impacted by force majeure
events prevent the Company from delivering natural gas to the customer's meter.
tssued by: lntermountain Gas Company
By: Lori A Blattner TiUe: Director- Regulatory Affairs
Efiedive: Beeember44o+t October'l' 2022
D(HIBIT NO.3
CASE NO.INT-G-22.04
INTERMOT]NTAIN GAS COMPAI\TY
PROPOSED TARIX]FS
(8 pages)
I.P.U.C. Gas Tariff
Rate Schedules
Tenth Revised Sheet No. 1 (Page 1 of 1)
Name
of Utility lntermountain Gas Company
Exhibit No. 3
Case No. INT-G22-(N
lntermountain Gas Company
Page 1 of8
Rate Schedule RS
RESIDENTIAL SERVICE
APPLICABILITY:
Applicable to any customer using naturalgas for residential purposes.
RATE:
Monthly minimum charge is the Gustomer Charge.
Customer Charge:
PerTherm Charge:
*lncludes the following:
Cost ofGas:
$5.50 per bill
$0.73921'
1) Temporary purchased gas cost adjustment
2) Weighted average cost of gas
3) Gas transportation cost
($o.ooo57)
$0.39216
$0.163&t
Distribution Cost:
EE Charge:
$0.16305
$0.02093
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for the cost of purchased gas as provided for in Rate Schedule PGA.
This adjustment is incorporated into the calculation of the Cost of Gas stated on customer bills.
ENERGY EFFICIENCY CHARGE ADJUSTMENT:
This tariff is subject to an adjustment for costs related to the Company's Energy Efficiency program as
provided for in Rate Schedule EEC-RS. The Energy Efficiency Charge is separately stated on customer bills.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the Company's Tariff, of
which this rate schedule is a part.
rssued by: lntermountain Gas Company
By: Lori A. Blattner Title: Director - Regulatory Affairs
Efhctive: October 1, 2022
l.P.U.C. Gas Tariff
Rate Schedules
Sixtv-Fiffi Revised Sheet No.3 (Pase 1 ot 2l
Name
of Utility lntermountain Gas Company
Rate Schedule GS-l
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 allowed at
the Company's discretion.
RATE:
Monthly minimum charge is the Customer Charge.
Customer Charge:
Per Therm Charge:
$9.50 per bill
*lncludes the following:
Cost of Gas:
Distribution Cost:
Block One:
Block Two:
Block Three:
Block Four:
Block One:
Block Two:
Block Three:
Block Four:
200 therms per bill @
1,800 therms per bill@
8,000 therms per bill@
10,000 therms per bill @
200 therms per bill @
1,800 therms per bill@
8,000 therms per bill @
10,000 therms per bil! @
Exhibit No. 3
Case No. INT-G22-04
lntermountain Gas Company
Page 2 of 8
$0.75436.
$0.73088.
$0.70821.
$0.63965.
$0.01445
$0.39216
$0.15990
$0.18465
$0.161 17
$0.13850
$0.06994
1) Temporary purchased gas cost adjustment
2) Weighted average cost of gas
3) Gas transportation cost
First
Next
Next
Over
First
Next
Next
Over
EE Charge:$0.00320
lssued by: lntermountain Gas
By: LoriA. Blattner
EfEctive: October 1, 2022
Company
Title: Director - Regulatory Affairs
l.P.U.C. Gas Tariff
Rate Schedules
Silty-Fiflh Revised SheetNo.3 (Page2ol 2\
Name
of Utility lntermountain Gas Company
Rate Schedule GS-i
GENERAL SERVICE
(Continued)
For separately metered deliveries of gas utilized solely as Compressed Natural Gas Fuel in vehicular intemal
combustion engines.
Customer Charge: $9.50 per bill
Per Therm Charge:First 10,000 therms per bill @
Over 10,000 thenns per bill @
Exhibit No. 3
Case No. INT-G-22-&
lntermountain Gas Company
Page 3 of 8
$0.70501.
$0.63645.
$0.01,145
$0.39216
$0.15990
$0.1 3850
$0.06994
Block One:
Block Two:
*lncludes the following:
Cost of Gas:
Distribution Cost:
1) Temporary purchased gas cost adjustment
2) Weighted average cost of gas
3) Gas transportation cost
Block One: First 10,000 therms per bill
Block Two: Over 10,000 therms per bill
@
@
1
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for the cost of purchased gas as provided for in Rate Schedule PGA.
This adjustment is incorporated into the calculation of the Cost of Gas stated on customer bills.
ENERGY EFFICIENCY CHARGE ADJUSTMENT:
This tariff is subject to an adjustment for costs related to the Company's Energy Efficiency program as
provided for in Rate Schedule EEC-GS. The Energy Efficiency Charge is not applicable to gas utilized solely
as Compressed NaturalGas Fuel in vehicular internalcombustion engines. The Energy Efficiency Charge is
separately stated on customer bills.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the Company's Tariff,
of which this rate schedule is a part.
tssued by: lntermountain Gas Company
By: Lori A. Blattner Title: Director - Regulatory Affairs
Effective: October 1, 2022
l.P.U.C. Gas Tariff
Rate Schedules
Twentv-First Revised SheetNo. 4 (Paoe1ol2\
lntermountain Gas CompanyName
Exhibit No. 3
Case No. INT-G-22-04
lntermountain Gas Company
Page 4 of 8
Rate Schedule lS-R
RESIDENTIAL INTERRUPTIBLE SNOWMELT SERVICE
APPLICABILITY:
Applicable to any residential customer otherwise eligible to receive service under Rate Schedule RS who
has added naturalgas snowmelt equipment after 61112010. The intended use of the snqrmelt 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. AII service hereunder is interruptible at the sole discretion of the
Company.
FACILIW 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.
Customer Charge:
PerTherm Charge:
*lncludes the following:
Cost ofGas:
$5.50 per bill
$0.73618.
1) Temporary purchased gas cost adjustment
2) Weighted average cost of gas
3) Gas transportation cost
$0.01733
$0.39216
$0.16364
Distribution Cost:$0.1630s
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for the cost of purchased gas as provided for in Rate Schedule PGA.
This adjustment is incorporated into the calculation of the Cost of Gas stated on customer bills.
tssued by: lntermountain Gas Company
By: Lori A. Blattner Tifle: Director- Regulatory Affairs
Effective: October 1, 2022
LP.U.C. Gas Tariff
Rate Schedules
Twentieth Revised Sheet No. 5 (Page 1 of2)
Name
of Utilitv lntermountain Gas Company
*lncludes the following:
Cost of Gas:
Distribution Charge:
Block One:
Block Two:
Block Three:
Block Four:
Block One:
Block Two:
Block Three:
Block Four:
200 therms per bill @
1,800 therms per bill @
8,000 therms per bill @
10,000 therms per bill @
200 therms per bill @
1,800 therms per
8,000 therms per
10,000 therms per
Exhibit No. 3
Case No. INT-G-22-04
lntermountain Gas Company
Page 5 of 8
$0.75116.
$0.72768.
$0.70501.
$0.63045.
$0.01445
$0.39216
$0.15990
$0.18465
$0.16117
$0.13850
$0.06994
Rate Schedule lS-C
SMALL COMMERICAL INTERRUPTIBLE SNOWMELT SERVICE
APPLICABILIW:
Applicable to any customer othennise 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, drivevvays 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 hcility 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
allrelated costs.
RATE:
Monthly minimum charge is the Customer Charge.
Customer Charge:
Per Therm Charge:
$9.50 per bill
1) Temporary purchased gas cost adjustment
2) Weighted average cost of gas
3) Gas transportation cost
First
Next
Next
Over
First
Next
Next
Over
biil @
biil @bi[ @
tssued by: lntermountain Gas
By: LoriA. Blattner
Company
Title: Director - Regulatory Affairs
Effective: October 1 2022
l.P.U.C. Gas Tariff
Rate Schedules
Seventv-Second Revised Sheet No.7 (Paael ot2\
Name
of Utilitu lntermountain Gas Company
Rate Schedule LV-l
LARGE VOLUME FIRM SALES SERVICE
AVA!I-ABILIW:
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:
Demand Charge: $0.30000 per MDFQ therm
Per Therm Charge:250,000 therms per bill @
500,000 therms per bill @
750,000 therms per bill @
Exhibit No. 3
Case No. INT-G22-04
lnlermountain Gas Company
Page 6 of 8
$0.54173'
$0.52384.
$0.44733.
Block One:
Block Two:
Block Three:
Block One:
Block Two:
Block Three:
First
Next
Over
*lncludes the following:
Cost of Gas
Distribution Cost:
1) Temporary purchased gas cost adjustment
Block One and Two
Block Three
2) Weighted average cost of gas
3) Gas transportation cost (Block One and Two only)
$0.03247
$0.0s210
$0.39216
$0.08710
$0.03000
$0.01211
$0.00307
First
Next
Over
250,000 therms per bill @
500,000 therms per bill @
750,000 therms per bill@
1
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for the cost of purchased gas as provided for in Rate Schedule PGA.
This adjustment is incorporated into the calculation of the Cost of Gas stated on customer bills.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the Company's
Tariff, of which this Rate Schedule is a part.
The customer shall negotiate with the Company, a mutually agreeable Maximum Daily Firm Quantity
(MDFO), which will be stated in and in effect throughout the term of the service contract.
The monthly Demand Charge will be equalto the MDFQ times the Demand Charge rate. Demand
Charge relief will be afforded to those LV-1 customers when circumstances impacted by force
majeure events prevent the Company from delivering natural gas to the custome/s meter.
tssued by: lntermountain Gas Company
By: Lori A. Blattner Title: Director - Regulatory Affairs
Efbctive: October 1, 2022
2.
3.
l.P.U.C. Gas Tariff
Rate Schedules
Twentv-Second Revised Sheet No.8 (Paoe 1 of 1)
Name
of Utilitv lntermountain Gas Company
Exhibit No. 3
Case No. INT-G-22-04
Intermountain Gas Company
Page 7 of 8
Rate Schedule T€
INTERRUPTIBLE DISTRIBUTION TRANS PORTATION SERVICE
AVAILABILITY:
Available at any point on the Company's distribution system to any customer upon execution of a one year
minimum wriften service contract.
MONTHLY RATE:
Per Therm Charge: Block One: First 100,000 therms transported @ $0.03771.
Block Two: Next 50,000 therms transported @ $0.01487.
Block Three: Over 150,000 therms transported @ $0.00496.
*lncludes temporary purchased gas cost adjustment of ($0.00082)
ANNUAL MINIMUM BILL:
The customer shall be subject to the payment of an annual minimum bill based on annual usage of 200,000
therms. The deficit usage below 200,000 therms shall be billed at the T-3 Block 1 rate.
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for the cost of purchased gas as provided for in Rate Schedule PGA.
This adjustment is incorporated into the calculation of the Cost of Gas stated on customer bills.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the Company's
Tariff, of which this Rate Schedule is a part.
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 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.
The Company, in its sole discretion, shall determine whether or not it has adequate capacity to
accommodate transportation of the custome/s gas supply on the Company's distribution system.
!f 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.
tssued by: lntermountain Gas
By: LoriA. Blattner
Effective: October 1, 2022
Company
Title: Director - Regulatory Affairs
1
2.
3.
4.
5.
l.P.U.C. Gas Tariff
Rate Schedules
Twentv-First ReMsed Sheet No. 9 (Paoe 1 ot 2)
Name
of Utilitu lntermountain Gas Company
Exhibit No. 3
Case No. INT-G-22-04
lntermountain Gas Company
Page I of 8
Rate Schedule T4
FI RM DISTRIBUTION ON LY TRANSPORTATION SERVICE
AVA!TABILITY:
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:
Demand Charge:$0.28032 per MDFQ therm*
Per Therm Charge:Block One:
Block Two:
Block Three:
First
Next
Over
250,000 therms transported @ $0.02395
500,000 therms transported @ $0.00847
750,000 therms transported @ $0.00260
1
2
*lncludes temporary purchased gas cost adjustment of ($0.01968)
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for the cost of purchased gas as provided for in Rate Schedule PGA.
This adjustment is incorporated into the calculation of the Cost of Gas stated on customer bills.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the Company's
Tariff, of which this Rate Schedule is a part.
This service does not include the cost of the customer's gas supply of 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 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.
The customer shall negotiate with the Company, a mutually agreeable Maximum Daily Firm Quantity
(MDFQ), which will be stated in and in effect throughout the term of the service contract.
The monthly Demand Charge will be equalto the MDFQ times the Demand Charge rate. Demand
Charge relief will be afforded to those T-4 customers when circumstances impacted by force majeure
events prevent the Company from delivering naturalgas to the customer's meter.
tssued by: lntermountain Gas Company
By: Lori A. Blattner Title: Director- Regulatory Affairs
Effective: October 1, 2022
3
4
5
EXHIBIT NO.4
CASE NO.INf -G-22{4
INTERMOI]NTAIN GAS COMPAI\IY
PERTINENT EXCERPTS PERTAINING TO III{ITRSTAIE PIPELII\IES AI{D RETAIDI)
FACILITIES
(31pag6)
Exhibit No.4
Case No. INT-G-22-04
lntermountain Gas Company
Page I of31
NORTHWEST PIPELINE LLC
(6 pages)
Exhibit No.4
Case No. INT-G-22-04
lnlermountain Gas Company
Page 2 of 31
FEDERAL ENERGY REGULATORY COMMISSION
WASHINGTON, DC 20426
OFFICE OF ENERGY MARKET REGULATION
In Reply Refer To:
Letter Order Pursuant to $ 375.307
Northwest Pipeline LLC
Docket No. RP2l-22 l-000
December 15,2020
Northwest Pipeline LLC
P.O. Box 1396
Houston, Texas77251
Attention: Bela Patel, Manager
Rates & Regulatory
Reference: Leap Year Rate Adjustment
Dear Ms. Patel:
On November 17,2020, Northwest Pipeline LLC filed revised tariffrecordst to
reflect an update to its daily reservatior/demand rates that are computed based on 365
days. The referenced tariffrecords listed in the Appendix are accepted effective January
1,2021, as proposed.
Public notice of the filing was issued on November 18,2020. Interventions and
protests were due as provided in section 154.210 of the Commission's regulations (18
C.F.R $ 154.210 Q020)). Pursuant to Rule 214 (18 C.F.R. $ 385.214 (2020)), all timely
filed motions to intervene and any unopposed motion to intervene out-of-time filed
before the issuance date ofthis order are granted. Granting late intervention 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.
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.
Exhlblt No. 'lCasa i,lo. INT-G22{r
lrilermormalnG&Compatry
Pqe 3 of 3t
Docket No. RP21-22 l-000 -2-
such acceptance be deEmed as recognition of any claimed eontactual right or obligation
associatcd thercwith; and such acceptance is without prejudice to any findings or ordere
which have been ormay hereafter be made by the Commissionin any proceedingnow
pending or hereaftor instituted by or against your company.
This order constitrtes 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 (ao2CIr.
Issued by: MashaK.Pslazzi, Directoq Division ofPipeline Regulation
Exhibit No.4
Case No. INT-G2244
lntermountain Gas Company
Page 4 of31
Northwat Pipcline LLC
FERC Grs Teriff
l'ifth Rcviccd Volumc No I Elcvcnth Revised Sheet No.5
Superscding
Tenth Rcviscd Shcct No. 5
STATEMENT OE RATESEffective Rates Applicable to
Rate Schedules TF-1, TE-z, TI-L, TFL-1 and TII-1(Dollars per Dth)
Rate Schedule and
Tlpe of Rate
Rare Schedule TF-1 (4) (5)
Reservation
(Large Customer)
System-Wide
25 Year Evergreen Exp.
Volumetric (2)
(Large Customer)
System-Illide
25 Year Evergreen Exp.
(SmaU Customer) (5)
Scheduled Overrun (2)
Rate schedule ?F-2 (4) (5)
Reservation
volumetric
Scheduled Daily Overrun
Annual Overrun
Rate schedule TI-1. (2)
Volumetric (7)
Rate schedule TrL-1 (4) (5)
Reservationvolumetric (2)
Scheduled Overrun (2)
Rate Schedule TIL-1 (2)
Volumetric
BaseTariff Rate (1) , (3)
Mini.num Maxirnum
.00000
.00000
.39033
.32039
.00832
.00832
.00832
.00832
. 00 832
.00832
.69427
.39865
.39033
.00832
.3986s
.3986s
.00000
.00832
.00832
.00832
.00832 .39865
Exhibit No. 4
Case No. INT-G-22-04
lntermountain Gas Company
Page 5 of 31
Docrment Acceesion *t 202203)-7-3055 Filed Date: 03/L7/2022
FEDERAL ENERGY REGULATORY COMMISSION
WASHINGTON, DC 20426
OFFICE OF ENERGY MARKET REGULATION
In Reply Refer To:
Letter Order Pursuant to $ 375.307
Northwest Pipeline LLC
Docket No. RP22-597-000
March 17,2022
Northwest Pipeline LLC
P.O. Box 1396
Houston, TX 77251-1396
Attention: Bela Patel, Manager
Rates & Regulatory
Reference: FuelReimbursementFiling
On February 25,2022,Northwest Pipeline LLC filed a tariffrecordr to update its
fuel reimbursement factors in accordance with sections 14.12 and 14.20 of the General
Terms and Conditions of its tariff. Pursuant to authority delegated to the Director,
Division of Pipeline Regulation, under l8 C.F.R. n375.307 (2021), the tariffrecord is
accepted, effective April l, 2022, as requested.
The filing was publicly noticed, with interventions and protests due on or before
March 9,2022. Pursuant to Rule 214 of the Commission's regulations (18 C.F.R. $
385.214 (2021)\, notices of intervention, 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 a late intervention 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.
This action shall not be construed as a waiver of the requirements of section 7 of
the Natural Gas Act, as amended; nor shall it be constmed 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 the applicant's 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
I Northwest Pipeline LLC, Fifth Revised Volume No. l, Sheet No. 14. F'uel Use
Factors (30.0.0).
E(hlbltNo.4
Caee No. INT-&2-04
Inennountah Gas Cornpany
P{e6of 3l
Docusalrt Acccsglon *r 20220317-3055
Dooket No. RP22-597-000
Flled Datc: 03/L712022
been or may her€after be made by the Commission in any poceeding now pending or
heroafter instituted by or against the applioant.
This order constiafics final agency action. Requests for rchearing by fte
Commissioo may be fild within 30 days of tre dato of issuance of this order, pursuant to
18 C.F.R. $ 385.713 Q02t).
Issued by: Marsha K. Palazzi, Director, Division of Pipeline Regulation
2
Exhibit No.4
Case No. INT-G-22-04
lntermountain Gas Company
Page 7 of 31
Northwcst Pipcline LLC
FERC Gas Tarilf
Fifth Revised Volume No. I
Rate Schedules TF-1, TF-2, TI-L, and DEX-1
Rate Schedule TE-1 - Evergreen Expansion
Incremental Surcharge (1)
Rate schedule TEr,-l
Rate Schedule TIL-1
Rate Schedules SGS-2F and SGS-2I
Rate Schedules LS-2F, LS-3f and LS-2ILiguefactionVaporization
Rate Schedule LD-4I
f.iquefaction
Thirtieth Rcvised Sheet No. 14
Superseding
Twenty Ninth Reviscd Shcct No. 14
1.01?
0.50t
0 .32t
0.232
0.30*
o -23*
STATEMENT OF TUEL USE REOUIREMENTS FACTORS
FOR REIMBURSEMENT OF' FUEI USE
Applicable to Transportation service Rendered Under
Rate Schedufes Contained in this Tariff, Eifth Revised Volume No. L
The rates set forth on Sheet Nos. 5, 6, 7, I and 8-A are exclusive offuel use requirements. Shipper shall reinburse Transporter in-kind for its
fueL use requirements in accordance with Section 14 of the General Terms and
Conditions contained herein.
The fuel use rej.mbursement furnished by Shippers sha11 be as followsfor the applicable Rate ScheduLes included in this Tariff:
The fuel use factors set forth above shal1 be calculated and adjusted
as explalned in Section 14 of the General Terms and Conditions. Fuel
reimbursement quantities to be supplied by Shippers to Transporter shalL be
determined by applying the factors set forth above to the quantity of gas
nominated for receipt by Transporter from Shipper for transportation,
Jackson Prairie injection, Plymouth liquefactj-on, Plymouth vaporization, orfor deferred exchange, as applicable.
Footnote
(1) In addi-tion to the Rate Schedule TF-1 fuel use requirements factor, the
Evergreen Expansion Incremental Surcharge will apply to the quantity of gas
nominated for receipt at the Sumas, SIPI or Pacific PooI receipt points under
Evergreen Expansion service agreements.
Extribit No.4
Case No. INT-G22-04
lntermounlain Gas Company
Page 8 of31
NOVA GAS TRANSMISSION LTD.
(4 pages)
Exhibil No.4
Case No. INT-G-22-04
lntermountain Gas Company
Page 9 of 31
l*l ffiff-t* lfsm6r'€rs.
oRDER TG{XI5-2022
lN THE HATTER OF he Canadian Eneryy Regulator
Act (CER Act); and
lN THE iIATTER OF an application filed by NOVA Gas
Transmission Ltd. (NGTL) with the Canada Energy
Regulator (CER) pursuant to Section 226 and
paragraph 229(1Xb) of the CER Ad, filed under
File OF-Tolls€roupl-N081 -202241 01.
BEFORE tha Commission of the CER (Commlsrlon) on 3OMay 2022.
WHEREAS on 29 May 2014, he National Energy Board (NEB) issued the MH-001-2013
Decision, approving NGTL's methodology for calculating Abandonment Surcharges;
ANDIWIEREAS on 18 April2018, the NEB issued a Letter Decision, approving NGTL's
Abandonment Cost Estimate of $2,535,332,000 (2016 dollars);
AND W{EREAS on 25 March 2020, the Commission issued Order TG-001-2020, approving
NGTL's rate design (Rate Deslgn);
AND WHEREAS on 17 August 2020, the Commission issued Order TG40$,2020, approving
NGTL's 202G2024 Toll SetUement (Set0ement);
AND WHEREAS on 23 November 2021 , the Gommission issued Order TGI{01-2021,
approving NGTL's interim tolls and abandonment surcfiarges efbdive 1 January 2022;
AND WI{EREAS on 29 Nril2022, NGTL filed an application (Appllcatlon) requesting an
order ficr approval ol frml2022 rates, tolls and charges lFlnal 2022 Tolb) and final2O22
abandonment surcfiarges (Flnal 2O22 Abandonment surcharger);
AND UTIIEREAS the Commission is satisfied with the consultation conducted and is not
aware of any oubtanding conoems wih the Application fiom shippers and participants of
NGTL's Tolls, Tarifb, Facilities and Prooedures Committee or other intercsted parties;
AND WHEREAS the Commission finds the Fina! 2022Tolls are just, reasonable and not
unjusUy disoiminatory ard have been calculabd in accordance with the Settlement and Rate
Design, and the Final2022 Abandorment Surcharges have been calculated in accordance
to the NEB MH401-2013 and 18 April 2018 decisions respecting abandonment costs and
surdrarges;
.2
Canadii
Exhibit No.4
Case No. INT-G22-04
lntermountain Gas Company
Page 10 of31
-2-
lT lS ORDERED pursuant to Section 226 aN paragraph 229(1Xb) of the CER Act that:
1. The interim tolls approved through OrderTGl-001-2021 brthe period
1 January 2022to 31 May 2022 are approved as final;
2. Theapplied-forfinal2022tollsbrtheperiod 1 June2022to 31 December2022,as
contained in Attadtment G to the Application, arc approved as final;
3. The interim abandonment surcharges approved through Order TGI-001-2021 tor the
period 1 January 2022to 31 May 2022 are approved as final.
4. Theapplied-forfinal2O22 abandonmentsurchargesfortheperiod l Juna2022to
31 December 2O22, as contained in Attachment H to the Application, are approved
as final.
THE COMMISSION OF THE CANADA ENERGY REGUI.ATOR
Signed by
Ramona Sladic
Secretary of the Commission
TG{r05-2022
Exhibit No. 4
Case No. INT-G-22-04
lntermountain Gas Company
Page 11 of31
NOVA Gas Transmission Ltd.
Final June-December 2022 Rates
DELIVERY POINT RATES
Attachment 2
Delivery Point Rates
Page 1 of 10
Y6s
Yos
Yas 3
Y€8
Yes 3
Yo8
2000
3't't 11
3fi'to
31112
1958
3886
6404
ALLIANCE CLAIRMONT INTERCONNECT APN
ALLIANCE EDSON INTERCONNECT APN
ALLIANCE SHELL CREEK INTERCONNECT APGC
EMPRESS BORDER
GORDONDALE BORDER
MCNEILL BORDER
6.21
5.66
5.66
5.66
5.66
5.66
5.66
8.10
8.10
8.10
8.10
8.10
8.10
8.'10
8.'t0
10.50
10.50
8.10
8.10
8.10
8.'10
8.10
8.10
't0.50
10.50
8.10
8.10
8.10
8.10
8.10
8.10
8.10
8.10
8.10
8.'t0
8.10
8.10
8.10
8.10
8.10
8.'10
o.2u7
o.2047
o.204.7
o.2047
o.204.7
0.2u7
0.2929
0.2929
0.2929
0.2929
o.2925
0.2929
o.2929
0.2929
0.3719
0.371S
o.2929
0.2929
o.2929
o.2929
0.2929
o.2929
0.3719
0.37't9
o.2929
0.292s
0.2929
0.23.29
0.2929
0.2929
0.2929
0.2929
0.2929
o.2929
0,2929
0.2929
0.2929
o.2929
0.2929
0.2929
31000
31001
3880
31003
31002
31004
31005
31006
6'126
*20
3214
31007
31008
3868
3297
3059
6132
6133
31009
3552
6145
31012
3488
3237
3662
3216
3'135
3288
3423
6'158
310t3
6112
31014
3299
AT. PLASI1CS SALES APN
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
AITKEN cREEK sourH slLEs 2
A|TKEN cREEK tNTencoruruEcr 2
AKUINU RIVER WEST SALES
ALBERTA ENVIROFUELS SALES APN
ALBERTA HOSPITAL SALES APN
ALBERTA-ITIONTANA BORDER
ALDER FTATS SOUTH NO 2 SALES
ALLISON CREEK SALES
ALTARES SALES 2
lLtlnes soutx slLes'
ALTASTEEL SALES APN
AM@O SALES (BP SALES TAP)
ANDERSON LAKE SALES
APL JASPER SALES APN
ARDLEY SALES
ASPEN SALES
ATUSIS CREEK EAST SATES
AURORA NO 2 SALES
AURORA SALES
BANTRY SALES
BASHAW WEST SALES
BASSET I-AKE WEST SALES
BAYMAG SALES APS
BAY TREE SALES
BEAR CREEK COGEN SALES APGP
BEAR RIVER WEST SALES
Yo8
Group I
D.ltnry
Pollt
Nmb.r
Fru D.m.nd R.b
Ptlc. Polnt -T
lUGJImol
Grflp I DcllvGry Polnt Namc IIO R.t!
(gcJrdl
Group 2D.llnry
Polrt
Nmbor
-#IHI[;I"
Tf"Y,r
-UDFE
ATCO
Grup 2 Dellv.ry Polnt Nrm Plp.lln.s
Fnnchls
Faar!
Order: TC,005-2022 Effec{ive: June '1, 2022 (Amended: July 1, 20221
Exhibit No.4
Gase No. INT-G-22-04
lntermountain Gas Company
Page 12 ot 31
NOVA Gas Transmission Ltd.
Final June.December 2022 Rates
TABLE OF RATES, TOLLS AND CHARGES
Table of Rates, Tolls and Charges
Page 1 of 1
Sarule R.t s, Tolb rnd Ch.ryE
1. Rato Schodulo FT-R
l6ir to Attrdnst '1' br lpplable FT-R Dom.nd Rat6 por month bas6d ff e lhr*yaer i.rn (Pri@ Point 'R) &
iurchargG br oech Reoipl Pcint
V-ago Fi.m Sflicc R@ipt Pd6 (AFSRP) t257.73 / lohr/ msfi
2. Rate Schodule FT-RN l.t€r lo Attachm€nt '1 ' br apdioHo FT-RN Demand Ratc por month & Srehlrge fq clch Rsdpt Pcinl
3. Ratr Sch€dule FT-D I
R6td to Attaclmont '? br eppli€Us FT-D Demand Rat. p€r month based on a oil+ycar term (Pri6 Polnt'Z) &
Surcha!6 br oldr Gmp 1 or Grilp 2 Dclivsry Point
Aver.96 FT-D Dcmand Ralo ffr Grup 1 D€livory Poinb $5.87 / GJ / month
FT-O Demsd Rste fq Goup 2 Oolvory Pdnts $8.10 / GJ / |mtr
FT-D Oam.nd Rata for Grcup 3 tlolivsry Points $9.71 / GJ / mmth
{. RatcSch€duloSTFT STFT Bid ftic. = Minimum of 1 009{ ot th€ edicbl€ FT-D Dmlnd Rrte bas6d m r mlysar tm (Prhc Point 'Z) br
mdr Gmp I DGlivory Point
t. Retc Sch€dul6 FTOW FT-DW Bid Prie = Minimm ol 125% of th€ appliebl. FT-D D€mrnd Rrte br3od m . thByur tm (Plka Pdnt YJ
lbr.sdr Group 1 Ddiv.ry Pdnt
t. Ret. Schedul. FT-P I Ret€r to Attadrmant '3' for applcaHe FT-P D€mand R8t6 ptr monlh
I Rei.r to Attadrm€nt ''l' lbr aprlaue If-R Rrte ,or erch Rrceid Poht
l. Rat€ Sch€dule lT-D I Rcfcr to Attachmcnt 2' br applioblo lT-D Rato tor €ach D€liv€ry Point
,. RatcSchsdulcFCS fho FCS Chrrge is dd.min6d in e6rd.n@ with Attadtm$t'1'to th3 applicu€ Sch.(U. of S.ryia
10. Rato Sch6dulc PT SSeClle-Nc.
9021-OlOOGo
902r-0't00Gl
9022-0'too(x)
9022-0 t00't-0
9022-0 t002-0
PT Rat6
11,O74 I dey
$3,300 / day
$1,356 / d8y
$2,142 t day
$3,147 / day
PT Gss Rat
3.s /tormstday
11,9 / lohr/day
3.46/1otmr/day
11.0t / 1orm3/day
i4.,{6 / iorm3/day
11. Rata Schsdul. OS SshelsE-Ne.
2021800034
Cherc
i121.87 / tohr/mntr
2021402934 0682 / month
2@30D15?2.Appli€blo lT-R md ]T-D Rlte
2011476052 t
201117@*
$0.2€83 / GJ subjoct to
$717,000 Minimm Annud Chrgr
2017887638 I 2011476092
m14721799 lm1B75g25/
S0.005 / GJ sd
S1,0O0 /mmth
202173il73 $7.29 / GJ / month and
Apdicablo lT-O Rato il Ov.r-Run
12. RatrSchsdulcCO2 Ti€r 1
s601.10
z I
cqRato(/10h1 1175.72 $310.5r
13. MonthlvAbendonmontsucharqo 2 $7.21 /losm!/monu1 SO.19 /GJ /month
14. DdhAb.ndonmstsurctratoc !80.24 /1o!mt/day S0.0063 /GJ /d.y
15. Fod.ral Fusl Charge's0.0979 / m.
1. SlMe under Rats Schaduhs FT-D, FI-P ud lT-D fa deliv.ry .t tiom ldstifld ln Atiadrmat 2, End Rats Schotub OS No.2O11176nJ,,,2,
are subleci to tho ATCO Pip€limr Fr3nchis€ F*s puEuanl to paragraph 15.13 of lhe G€n6ru1 Tems end Condilion!.
2. Mmthly Absdonmst Surcharg€ apdiEuo b R8te Schoddos FT-R, FT-D, FT-P. FT-RN, FT-DW and STFT, and tho blliling
Ret€ Schedule os: 2021aooo3/, 2021735473.
3. Daily Abardonrent Surchsrgo apdietls to Rste Sth€duhs lT-R, lT-D, the blwing Rale Schedrl$ OS'.2OO3Oo4522,2o11&eO52, 2011476054,
2017887638, m11476O92,2O1A72179s,2016759254, end ifspplicsble Over-Run G8s.
4. Coll€cl€d m aI d€livsiss ol g6s within Aherta puBuilt to ily Rate Sdredul€ ud6$ NGTL has @ived a valid somption ccrtifi€t€
puBunt to lho Grenhous Ges Pollution Prung Act.
5. Se FCN12 Canada Revon$Agoncl Admini3t a0ve Position r.garding M8rkolabl€ N8UEI GB ffi&r Pdt 1 of thoGr*nhNs€ Ges Pollution P,icing Act.
Order: TG-005-2022 Eftsclive: June 1 ,2022
Exhibit No.4
Case No. INT-G-22-04
lntermountain Gas Company
Page 13 of31
FOOTHILLS PIPE LINES LTD.
(3 pages)
Exhibit No. 4
Case No. INT-G-22-04
lntermountain Gas Company
Page 14 of 31
() t. Energy
450-l StloetSW
cdgry, Albcta T2P 5Hl
Td: (,103) 92{12603
Fu:(4o3)92G.2347
Bnail: bamd3dlaia@caagy. com
a
a
October29,202l
Canada Enerry Regulator
Suite 2 10, 5 I 7 Tenth Avenue S'lV
Calgary, Alberta T2R0A8
Filed Electonically
Attention: Mr. JeepDenis Cherlebois, Secretary of the Commission
DearMr. Charlebois
Re: Foothills Pipe Lines Ltd. (Foothills)
Statement of Rgtes and Charges effective Jenurry 1,20T2
Foothills encloses for filingwith the Commissionpursuantto section 229(l)(a) ofthe Cqnadian
Energt Regulalor Actrates and charges for tansportation service on Foothills Zones 6, 7, 8 and
9 to be effective Januar5r l, 2022(Effe6ive2022 Rates).
The following attachments are included with this letter:
Attachment I consists of supporting Schedules A through G Lz
Attachments 2 and 3 are black-lined and clean copies, respectively, ofthe Table of
Effective Rates for 2022
The rates and charges are based on the methodolory approved in Order TG-8-2004, as amended
by OrderTG-03-2007.
The filing also includes the Foothills Abandonment Surcharges effective January l,2022,which
are included in the Table of Effective Rates for 2022. The supporting information on the
Abandonment Surcharge calculations are provided in the attached Schedule G.
Foothills met with customers and interested parties on October 2 5,2021 and presented the
preliminary 2022revqrrc requirement preliminary Eff*tive2022 Rates and preliminary
Abandonment Surcharges. Based onthis consultation, Foothills is not aware of any objections to
its proposal for establishing the Effective 2022 Rates.
Foothills understands that any party that is opposed to the rates and chages will advise the
Commission accordingly.
I Certain line items in Schedules A through G have been renamed to enhance consistency with Sre terminology
used in regulaory filings by other TC Energy CER-regulaed gas ptpclin€s2 Schedule C from previous years' filings has be€n terminated as the related Special Charge has been fully
amortized and is no longer applicable. As a result the previous Schedule C-l has been relabeled to Schedule C in
the current filing. In addition, Schedule C will only show depreciation by account by zone annually raher Btan
monthly.
Exhibit No.4
Case No. INT-G-22-04
lntermountain Gas Company
Page 15 of 31
Oc,.obrr. 29,2021
Mr. Charlebois
Page 2 of2
Foothills will notify its customers and interested parties ofthis filing and post a copyof it on
TC Enerry's Foothills System website at:
http ://www.tccustomerexpress. mm/934.htnl
Communication reprdingthis filing should be directedto:
AndrewPittet Ashley Mitchell
Regulatory ProjectManager Seniorlegal Counsel
Tolls and Tariffs, Canadian Natural Gas Pipelines Canadian Law, Natural Gas Pipelines
Foothills Pipe Lines Ltd.
450- I SteetSW
Calgary, Alberta T2P sHl
Telephone: [phone]
Facsimile : (403) 920 -23 47
Email: andrew3 [e-mail]
Yourstuly,
Foothills Pipe Lines Ltd"
Original signed by
Bernard Pelletier
Director, Regulatory Tolls and Tariffs
Canadian Natural Gas Pipelines
Attachments
cc: Foothills Firm Customers
Interruptible Customers and Interested Parties
Foothills Pipe Lines Ltd.
450-l StreetSW
Calgary, Alberta T2P 5Hl
Te lephone : (403) 920 -21 U
Facsimile : (403) 920 -23 47
Email: [e-mail]
Foothills Pipe Lines Ltd.
Exhibit No.4
Case No. INT-G-22-04
lntermountain Gas Company
Page 16 of 3'l
Page I
TABLE OF EFFECTIVE RATES
1. Rate Schedule FT, Firm Transportation Senice
Demand Rate
($/GJ/Km/Month)
Zone6 0.0048085566
Zore 7 0.0034837767
Zone 8* 0.0148256225
Zone9 0.0149212538
2. Rate Schedule OT, Overrun Trensportation Senice
Commodity Rate
($/GJ/Km)
Zore6 0.0001738985
ZoneT 0.0001259886
3. Rete Schedule IT, Interruptible Transportation Service
Commodity Rate
($/GJ/Km)
ZoneS 0.0005361595
Zone9 0.0005396179
4. Monthty Abandonment Surcharge**
All Zones 0.09 3 65 44028 ($/GJ/IvIonth)
5. Daily Abandonment Surcharge***
All Zones 0.0030790489 ($/GJ/Day)
* For Zone 8, Customers Haul Distance shall bc 170.7 lan.
**Monthly Abandonment Surcharge pplicable to Rate Schedule Firm Transportation Service, and Short Tcrm Firm
Transportation Service for all zones.
*+*Daily Abandonment Sucharge applicable to Rate Schedule Ovemrn Transportation Service for Zone 6 & 7
Intemrptible Transportation Service for Zone 8 & 9, and Small General Service for Z,one 9.
TARIFF -PHASE I Effective Date: Jawary 1,2022
Exhibit No.4
Case No. INT-G-22-04
lntermountain Gas Company
Page 17 of31
GAS TRANSMISSION NORTHWEST LLC
(6 pages)
Exhibit No.4
Case No. INT-G-22{4
Intermountain Gas Company
Page 18 of 31
Documen! Acceagi.on # : 20211118-3098 Filed Date: LL/78/2027
177 FERC fl 61,110
FEDERAL ENERGY REGTJLATORY COMMIS SION
WASHINGTON,DC 20426
November 18,2021
In Reply Refer To:
Gas Transmission Northwest LLC
Docket No. RPI 5-904-003
Gas Transmission Northwest LLC
Wright & Talisman P.C.
1200 G StreetNW
Suite 600
Washington, DC 20005
Attention: Joseph S. Koury, Attorney
Dear Mr. Koury:
I . On Septemb er 29, 202L, Gas Transmission Northwest LLC (GTN) filed a
stipulation and agreement (Settlement) pursuant to Rule 207 of the Commission's Rules
of Practice and Procedure.l The Settlement is submitted in lieu of a Natural Gas Act
(NGA) section 4 general rate case filing and fulfills GTN's obligation, established in
earlier proceedings, to submit rates to be effective no later than April 1, 2022.2 GTN
believes that the Settlement is supported or unopposed by all of its shippers and other
interested parties. As discussed below, we approve the Settlement as proposed to be
effective January l, 2022.
2. Previously, the Commission approved a sefflement filed by GTN on June 30, 2015
(2015 Settlement)3 and an amendment to that 2015 Settlement on November 30, 2018.4
I r 8 c.p.R. g 385.202(a)(s) (2020).
2 Gas Transmission Northwest LLC,l51 FERC fl 61,280 (2015); Gas Transmission
Nortlwest LLC,165 FERC fl 61,195 (2018) (approving 2018 settlement amending an
earlier settlement); Gas Transmission Northwest LLC,l75 FERC fl 61,250 (2021)
(extending deadline for rate filing under earlier settlements).
3 Gas Transmission Northwest LLC,15l FERC u 61,280 (2015).
a Gas Transmission Nortlwest LLC,165 FERC ti6l,195 (2013).
Exhibit No. 4
Case No. INT-G-22-04
lntermountain Gas Company
Page 19 of 31
Docunent Accession # : 20211118-3098
Docket No. RPl5-904-003
Filed Datse: aL/t8/202L
On June 4,2021, GTN filed a motion to extend GTN's obligation to file an NGA
section 4 rate case until April 1,2022. The Commission approved the extension of time
on June 28,2021.s
3. This Settlement resolves issues regarding GTN's rates and rate filing obligations.
The Settlement maintains existing tariff recourse rates and establishes depreciation rates
and a carbon tax regulatory asset. It also provides for the establishment of income tax
allowance and accumulated deferred income tax in the future. In addition, it establishes
that after December 31,2023, GTN will report to settling parties the expenses, capital
expenditures and amounts recovered relating to dithiazine contamination and
remediation.
4. GTN states that the Settlement establishes a rate case moratorium through
December 31,2023 and a comeback provision to file for rates to become effective no
later than April l, 2024, accounting for any Commission-imposed suspension period.
GTN further states that the standard of review for modifications by the Commission to
the terms of the Settlement "shall be the most stringent standard permissible under
applicable law.'{
5. Public notice of the filing was issued on October 1,2021. Interventions and
protests were due as provided in section 154.210 of the Commission's regulations.T
Pursuant to Rule 214,8 alltimely filed motions to intervene are granted. The Canadian
Association of Petroleum Producers intervened, supporting the Settlement. No protests
or adverse comments were filed.
6. The Settlement appears to provide that the standard of review applicable to
modifications to the Settlement proposed by third parties and the Commission acting sua
sponte "shall be the most stringent standard permissible under applicable law."e
Although we do not decide in this order what standard of review applies to the Settlement
or any component of it, we clariS the framework that would apply if the Commission
were required to determine the standard of review in a later challenge to the Settlement
by a third party or the Commission acting suq sponte.
s Gas Transmission Northwest LLC,l75 FERC !T 61,250 (2OZl).
6 Settlement at article V and article XIII.
7 r8 c.r.n. $ r54.2ro (zo2o).
8 r8 c.n.R. $ 3ss.2r4 (zo2o).
e Settlement at article V and article XIII.
Exhibit No.4
Case No. INT-G-22-04
lntermountain Gas Company
Page 20 of 31
Document Acces6ion #: 20211118-3098
Docket No. RP15-904-003
Filed Date: lL/L8/2027
-3-
7. The Mobile-Sierra "public interest" presumption applies to an agreement only
if the agreement has certain characteristics that justifu the presumption. In ruling on
whether the characteristics necessary to justiff a Mobile-Sierra 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 qualiff for a Mobile-Sierra
presumption . ln New England Power Generators Association v. FERC,\o howeveg the
Court of Appeals for 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.
8. We find that the uncontested Settlement appears to be fair and reasonable and in
the public interest. The Settlement is supported or not opposed by all parties to the
proceeding and establishes a rate moratorium. Therefore, we approve the Settlement as
proposed to be effective January 1,2022. The Commission's approval of the Settlement
does not constitute approval of or precedent regardinB, my principle or issue in this
proceeding.
By direction of the Commission. Commissioner Danly is concurring with a
separate statement attached.
Kimberly D. Bose,
Secretary.
ro New England Power Generators Ass'n v. FERC,707 F.3d364,370-371
(D.C. Cir.20t3\.
Exhibit No.4
Case No. INT-G22-04
lntermountain Gas Company
Page21 of31
Document Accession #: 20211118-3098 Filed Date: tL/18/202:.
I.,INITED STATES OF AMERICA
FEDERAL ENERGY REGULATORY COMMISSION
Gas Transmission Northwest LLC Docket No. RPl5-90+003
(Issued November 18, 2021)
DANLY, Comm ission er, c oncurr ing:
I agree with the Commission's decision to approve Gas Transmission Northwest
LLC's Amended and Restated Stipulation and Agreement of Settlement (Settlement).r
As I stated in my dissentrn Kinetica Deepwater Express, LLC,I suggest to anyone
participating in the natural gas industry that it might be prudent to be clearer in your
settlement agreements as to whether you are actually a party to that agreement.2 Though
I understand that defining "Settling Parties" as parties that "either support or do not
oppose"3 the Settlement is common in the indushy, situations will almost certainly arise
in which an entity's status as party or non-party to a settlement will be dispositive. This
will be even more important should the issue be presented to a body less indifferent to
fundamentals of conffact law than this Commission.
For these reasons, I respectfully concur.
James P. Danly
Commissioner
I Gas Transmission Nw. LLC,l77 FERC fl 6l,l l0 (2021).
2 Kinetica Deepwater Express, LLC,l75 FERC fl 61,048 (2021) (Danly, Comm'r,
concurring in part and dissenting in part at P l0 n.l2).
3 Setttement at Art. III(A) and App. A.
Exhibit No.4
Case No. INT-G22-04
lntermountain Gas Company
Page22ot31
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
DAILY
MILEAGE (a)
(Dth-MrLE)
Max. Min.
BASE 0.000362 0.000000
STF (c) (e) 0.000000
EXTENSION CHARGES
MEDFORD
E-r (0 0.002511 0.000000
E-2 (h) 0.002972 0.000000
(Diamond l)
E-2(h) 0.001166 0.000000
(Diamond 2)
COYOTE SPRINGS
E-3 (i) 0.001167 0.ooo0oo
CARTYLATERAL
E4(p)
OVERRUNCHARGEO)
SURCHARGES
ACA (k)
Issued: November 26, 2019
Effective: January l, 2020
PART4.I
4.1 - Statement of Rates
FTS-I, LFS-I, and FHS Rates
v.19.0.0 Superseding v.l 8.0.0
STATEMENT OF EFFECTIVE RATES AND CI{ARGES FOR
TRANSPORTATION OF NATTJRAL GAS
Rate Schedules FTS-I, LFS-I, and FHS
For Rate Schedules FTS-I and LFS-I:
RESERVATION
DAILY
NON-MILEAGE (b)
(Dth)
Ma:r. Min.
0.028612 0.000000
(e) 0.000000
DELIVERY (c)
(Dth-MrLE)
Max. Min.
0.000016 0.000016
0.000016 0.000016
ruEL (d)
(Dttr-MILE)
Max. Min.
0.00507o 0.0000/o
0.fi)50olo 0.0000%
0.044223 0.000000 0.000026 0.000026
0.000000 0.000000
0.000000 0.000000
0.001168 0.000000 0.000000 0.000000
0.151492 0.000000 0.000000 0.000000
(k) (k)
Docket No. RPI 9-370-001
Accepted: December 18, 2019
Exhibit No.4
Case No. INT-G-22-04
lntermountain Gas Company
Page 23 of 31
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ruROUOEE FLAtt
HCFIC 6tS e
CAUFORN]A
ft-F.-*-.!l'.,E
Exhibit No.4
Case No. INT-G22-04
lntermountain Gas Company
Page24 ot 31
MOUNTAINWEST PIPELINE, LLC
(5 pages)
Exhibit No.4
Case No. INT-G-22-04
lntermountain Gas Company
Page 25 of 31
/hountainVbst-
Re:
Kimberly D. Bose, Secretary
Federal Energy Regulatory Gommission
888 First Sfeet, N.E.
tlUashington, DC204.26
Nnll,2022
tountelnWect Plpellne, LLC
Docket No. RP22-_-000
FERC G6 Terlff Flllng
Dear Secretary Bose:
Pursuant to 18 CFR S 1 54.7 of the Federal Energy Regulatory Commission's (Commission)
Regulations, Mountaint/ttrest Pipeline, LLC (Mountain\I\lest), formerly Dominion Energy Questar
Pipeline, LLC (DEOP), submib for filing and acceptance the following proposed tarifi sections to
its FERC Gas Tariff, Second Revised Volume No. 1 and OriginalVolume No. 2 (Tadtr).
Mountrain\Abst r€quests an efbcWe date of April 1,2022, forthe proposed changes.
Propoced Sectlon(s):
Second Revised Volume No. 1, entire Tarifr, Version 20.0.0
First OriginalVolume No. 2, entire Tariff, Version 10.0.0
Material Submlfted
ln accordance with $ 154.7(a)(1) of the Commission's regulations, Mountaint/Vest submib the
folloring material:
An eTarifiXML package, filed as a zip (compressed) file, containing:
1. A transmittal letter in PDF format.2. The proposed Tarifr sectlon version(s) in RTF fomat with metadata attached.3. A clean copy of the Tariff section version(s) in PDF brmat.4. A marked copy of the Tarifi section version(s) in PDF format.
Statement of the Natun, Reasons and Basls for Flllng
On October 6, 2021, Dominion Energy, lnc. announcad he sale of its interstate FERC-
jurisdictiona! pipeline essets to Souhwest Gas Holdings, lnc., including DEQP. This sale was
completed and efiective on January 1 , 2022. On April 'l, 2022, DEQP became MountainlAbst. ln
this filing, MountainWest is submitting revised Tariff records ref,ecting this change of company
name, along wiffr oher pertinent revisions.
333 S. Stato St., Sdt Ld(e City. UT 8411'l I mu,plp..com
Exhibit No.4
Case No. INT-G-22-04
lntermountain Gas Company
Page 26 of 31
Kimberly D. Bose, Secretary
^f/fl1,2022Page2
MountainWest is submitting revised versions of both volumes of its Tariff. Each section of Second
Revised Volume No. 1 will be updated to Version No. 20.0.0, while each section of Original
Volume No. 2 will be updated to Version No. 10.0.0. In some cases, the only change to a given
section is the company name and version number in the header, which is not reflected in redline.
Other tarifr-wide "global' changes are outlined below.
Proposed Tarlff Revlsions
The following 'global' revisions are found throughout both volumes of the Tarift
All section headers reflect the new company name, MountainWest Pipeline, LLC, and the
update to Version Nos. 20.0.0 (Volume 1) or 10.0.0 (Volume 2).
'Dominion Energy Questrar Pipeline, LLC "changed to "MountainWest Pipeline, LLC'(in
some inshnces in Volume 2,'Questar Pipeline Company,' DEQP's previous name is
changed to'MountainWest").
'Questafl is changed to "Transportef in the body of the text.
'QuestLine@ changed to 'MyQuorum' in the body of the terit.
Various capitalizations of defined terms, conected typographical enos, and other similar
minor corrections have been made.
\AEb addresses arc changed to reflect MountainWesfs new website URL.
Volume I and2 Title Pages reflects MountainWest's new corporate identi$.
Statement of Negotiated Rates reflects the deletion of a wayward reference to Footnote No. 4.
Section 1 ref,ects a re-ordering of definitions due to the renaming of "Questaf and -QuestLine".
Part 2, Section 'l, Part 3 Section 1, and Part 4, Section 1 reflect the deletion of the numbered list
formatting of an already alphabetical list of definitions.
Form of Firm Peaking Service Agreement reflects a re-structuring of column headings in line 4
and eliminates checkboxes in lines G9.
Sections 2.5,2.9, and MyQuorum Access Agreement fl 9 reflect updated website URLs. The new
URL, www.mwpipe.com, will automatically redirect users to MountainWest's cunentwebsite,
www.questarpipeline.com, until such time as MountainWest's new site is tully deployed and
questarpipeline.com is decommissioned.
Filings Pendlng Before the Gommlsslon
MountainWest states that in compliance with 18 CFR S 154.204(0 and the Commission's Order
No. 587-2 issued July 15,2021 (July Order)i, on November 10,202'1, DEQP submitted its
compliance filing in this proceeding (NAESB Filing)2. Therein, DEQP submitted a revised Tariff
Section No. 26 Version No. 7.0.0 incorporating the revised North American Energy Standards
Board (NAESB) Standards Version No. 3.2 (Standards) into its Tariff, to be effective on June 1,
2022, pu.s;uant to the July Order. As of the date of this filing, the NAESB Filing is still pending
before the Commission. SecUon 26 Version 20.0.0 submitted in this name+hange filing retains
Version 3.'l of the Standards. Upon approval of the NAESB Filing, Version 7.0.0 will be marked
"Overtaken by Events' and MountainWest will file a revised Section 26 with appropriate changes
incorporating the Version 3.2 Standards and all information relevant to this name-change filing.
t 176 FERC f 61 ,0',15 (202'.t)
2 Dominion Energy Questar Pipeline, LLC, Docket No. RP22-211-000 (2021!.
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Exhibit No.4
Case No. INT-G-22-04
lntermountain Gas Company
Page 27 oI 31
Kimberly D. Bose, Secretary
April l,2022
Page 3
MountainWest states that it has no other filings other than that described above pending before
the Commission that may significantly impact this filing.
Motion to Place Tariff Sections into Effect and Request for Waiver
Pursuant to $ 154.7(a)(9) of the Commission's Regulations, MountainWest moves to place the
proposed Tariff section into effect on April1,2022. MountainWest also requests a waiver of the
30day notice requirement in 18 CFR S 154.207 of the Commission's regulations to allow an
effective date of April 1 , 2022.
Communications
Pursuant to S 385.203 of the Commission's regulations, copies of all communications conceming
this filing should be addressed to:
Shelley W. Kendrick
Director Marketing & Business Development
MountainWest Pipeline, LLC
333 South State Street
P.O. Box 45360
Salt Lake City, UT 84145
[phone]
shelley. [e-mail]
Ryan J. Collins
Wright & Talisman, P.C.
1200 G. Street N.W., Suite 600
Washington, D.C. 20005
[phone]
[e-mail]
Posting and Certification of Service
ln accordance with the provisions of $ 154.2(d) of the Commission's regulations, copies of this
filing are available for public inspection, during regular business hours, in a convenient form and
place at MountainWest's main office at 333 South State Street, Salt Lake City, Utah 841 'l 1. ln
addition, in accordance with S 154.208 of the Commission's regulations, MountainWesl is serving
copies of the instant filing to its customers and the Colorado Publlc Utilities Commission, the
Public Service Commission of Utah, and the \Afioming Public Service Commission.
Certification
The signature on this filing constitutes a certification that (1) the signer has read the filing, (2) the
statements contained in the electronic media are true and conect to the best of her information
and belief, and (3) the signer possesses full power and authorig to sign this filing.
E)d{Ut No.4
Caso No. INT-e22-04
lntermounfraln Gas Company
Page 28 of 31
l(Inbdly D. Eo.t, 8ccru0rry
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Ihmlnion E r.rgy 8.n icc., hc, 393 Sou0r 6lbD S:tnd, 8.t t & Cty, UT E{l I I , (t01) !2+
2047 (ptron ), (t01) gll-6E2s (FN0, [e-mail].
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Exhibit No. 4
Case No. INT-G-22-il
lntermountain Gas Company
Page 29 of 31
MountainWest Pipeline, LLC
FERC Gas Tariff
Second Revised Volume No. 1
Statement of Rates
Sectlon Version: 20.0.0
STATEMENT OF RATES
Rate Scheduley'
Type of Charge(a)
PEAKING STORAGE
Firm Peaking Storage S€rvice - PKS
Monthly Reservation Cta rge
Maximum 41,.,.,.,,,,.,
Mlnlmum...,....,
Usage Chargelnjecton
Wthdrawal......
OMONAL VOLUMETRIC REI,EASES /Peaking Storage S€rvlce - PKS
Maximum 4/,.,....,,,,..,,..,,
Minlmum..,......
Firm Storage Service - FSS
Maximum 4/,..........,,...,,.
Minlmum........,
Storage Usage Charges Appllcable to Volumetric Releas€s 6/
Peaklng Storage Servlce - PKS:,..,....,.,,,,,.
InJection
WltMrawal.,....
CLAY BASIN STORAGE
Flrm Storage Servlce - FSS
Monthly Reservation C-tlarge
Deliverabllity
Maximum 4l .,,.,.,,.., 2.85338Mlnimum......... .....,,0,00000
CapacityMaximum..,..... .....,. 0,02378Mlnimum.....,.., ,..,..,. 0,00000
Usage ChargeInjectionl/ 0.01049Wlthdrawal,,,.., ...,....... 0.01781
Authorized Overrun Charge .,,,,,.,..,.Maxhumu,.,.. '..'.."' o'303r5Mlnlmuml/.'."' .....'...' 0'01781
Interruptible Storage Service - ISS
Usage Charge
Inventory 5/Maximum.,..,.,, ,,,.... 0,05927Mlnimum..,.,,,,. ,,.....0,00000
InJectionl/
withdrawal
0.01049
0'01781
Base
Tarlff
Rate ($)
(b)
2.87375
0.00000
0.03872
0.03872
3.40890
0.00000
0.57068
0.00000
'drieii
0.03872
Clay Basin Storage Service - FSS:Injectonl/...,.. 0.01049Withdrawal...... 0,01781
PARK AND LOAN SERVICE - PAL1
Dally ChargeMaximum,...,... ...,,,,..., 0.30315Minimum,........ ,.,.,,,,... 0,00000
Dellvery Chargel/.,...,... ,, 0,02830
EIELBEIUzuBSEMEUI - Z.Oelo (0.2oh utility and 1.8olo compr€ssor fuel) for Rate Schedule PALI
Filed On: Apri'l L,2022 Effective On: April 1,2022
E:filblt No.4
Case No. lt'IT-G,244
lnbtnumhln Gae Corp€ry
Page 3O of3l
f,.EDERAL ENERGY REGTILATORY COMIIISSION
AITIIIUAL CIIARGES I]NIT CHARGE
(1 page)
Exhibit No.4
Case No. INT-G22-04
lntermountain Gas Company
Page 31 of 31
FEDERAL ENERGY REGULATORY COMMISSION
WASIIINGTON, D.C. 20426
NT 2022 GAS A}.INUAL CHARGES
coRRECTToN FOR AI.TNUAL tjl,'Rcrr UNrr CHARGE
The annual charges unit charge (ACA) to be applied to in fiscal year 2023 for recovery of
FY 2022 Current year and 2021 True-Up is $0.ffi15 per Dekatherm @,th). The new ACA
surcharge will become efrective October L,2022.
The following calculations were used to determine the W 2022 unit charge:
2022 CT]RRENT:
Estimated hogram Cost $9I,433,000 divided by 62,561,913,420 Dth = 0.0014614802
2021TRUE-UP:
Debit/Credit Cost $2,517,644 divided by 61,518,030,836 Dth = 0.0000409253
TOTALUNIT CHARGE = 0.0015024055
lf you have any questions, please cootact Raven A. Rodriguez at (202)502{276 or e-mail
at [e-mail].
PUBLIC
EXHIBIT NOS.5.14
CASE NO. INT-G.22-04
INTERMOTINTAIN GAS COMPAIVY
(10 pages)
Exhibit No. 5
Case No. INT-G2244
lntermountain Gas Company
Page 1 of1
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Case No. INT-G-22-04
lntermountain Gas Company
Page 1 of1
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Case No. INT-G-22-&
lntermountain Gas Company
Page 1 ofl
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Case No. INT-G22-04
lntermountain Gas Company
Page 1 of1
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Case No. INT-G22-04
lnlermountain Gas Company
Page 'l of 'l
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!ilTERTOUI{TAIN GAS CO]UIPA}IY
Propoeed Temporary Surcharyes (Credits) - Vadable Costs
De*riptlon
Exhibit No. 10
Case No. INT-G-22-04
lntermountain Gas Company
Page 1 of1
Amount
5
6
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11
12
13
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25
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(a)
Account 1910 Variable Amounh Which Aoph to RS. G$.1. and LV-l:
Account 19'10 Variable Co6b
Normalized Sales Volumes (111121 -1%1l?J)
Proposed Temporary Surcharge (Credit) - Varlable Corb
Lod and Unaccounted For Gas Amoun$ Which Aoolv to RS rnd G$1:
Lost and Unaccounted For Gas Amouns from INT-G-2'|{4 (Accont 1910.2120)
Lost and Unaccounted For Gas Amoilization (Account 1910.2130)
(Over)AJnder Collection of Lost and Unaccounted For Gas from INT-G-21-04
Lost and Unaccounted For Gas INT-G-22{4
Total Lost and Unaccounted For Gas Amounb Wtich Apply to RS and G$1
Normalized Sales Volumes W1H - 12131121)
Proposed Temporary Surcharge (Gndit) - Lost and Unaccountod For Gas Gotb
Lost and Unaccounted For Gar Amountr Which Apoh to LV-l. T-3. and T-1:
Lost and Unaccounted For Gas Amounb fiom INT-G-21{4 (Account 1910.2120)
Lost and Unaccounted For Gas Amortization (Account 1910,2140)
(Over)/under Collection of Lost and Unaccounted For Gas from INT€-2144
Lost and Unaccounted For Gas INT-G-22{4
Tolal Loot and Unrccounted For Gas Amounb vlJhich Apply to LV-1, T-3, and T4
Normalized Sales Volumes W1U - 12131121)
Propored Temponry Surcharge (Gredlt) - Lost and Unaccounted For Gas Gotts
Conveil T.{ Lost and Unaccounted For Temoorary from a Volumefiic Rab to a Demrnd Rate:
Proposed Temporary Surcharge (Credit) - Lost and Unaccounted For Gas Costs (Line 20)
Normalized T4 Sales Volumes l1l1l21 - 12131121l,
Total Temporary Collected
Billing Determinanb Demand Volumes
Propored Temporary Surcharge (Credit) - Lost and Unaccounted For T.f Demand Rate (Line 24 Dlvlded by Line 25)
(') See Workpaper No. 5, Page 1, Line 16, Column (f)
(2) See Workpaper No. 5, Page 2, Line 2, Column (c)
F) SeeWorkpaperNo.5, Page2, Line8, Column (d)
(a) See workpaper No. 5, Page 2, Line 30, Column (d), plus Line 36, Column (e)
o See Workpaper No. 5, Page 2, Line 3, Column (c)
(6) See Workpaper No. 5, Page 2, Line 14, Column (d)
o See Workpaper No. 5, Page 2, Line 31, Column (d), plus Line 40, Column (e)
(b)
$ 22,075,600 (1)
415,466,730
$0.0531 3
$(407,602) e)
434,5$ p)
26,991
(938,251) (1)
$(911,260)
403,067,298
$(0.00226)
$(5)
(6)
(13e,000)
140,583
1,583
(312,$6)r)
$(31 I,253)
378,011,472
$ (0.00082)
$(0.00082)
308,850,867
$(253,258)
16,024,920
$(0.01580)
Exhibit No. 11
Case No. INT-G-22-04
lntemountain Gas Company
Page 1 of 1
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Exhibit No. 12
Case No. INT-G22-04
lntermountain Gas Company
Page 1 ofl
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Extriblt No. 13
Case No. INT-G22{4
lntermountaln Gas Corparry
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Edrlblt No. 14
Case No. INT-G22-04
I nGrmountaln Gas CompanyP{elof1
Llnc
tlo.
I}ITERXOUilTfl }I GAS COT PAITY
RocldenUal Enagy Ef,ldcncy Gredlt
Tdd RS
(r)
1 ResidentidEneryyEftienryCtodit $ (4,850,000) $ (4,850,000)
2 ltlormdizedSdosVotum* W1m-nMml 270,876,009 (t)
3 PropoeodP.rThmnPilrAdfittndtt $ (0.017$)
(rl Doea rd indude durrs tur he !$R rdo dass bocilse t\e Eneryy Effiicy Chqe b not applkslo b R# Sfie&b l&R"
(c)o)
ITEWS RELEASE
CUSTOMERNOTICE
CASE NO.INT.G-22-04
INIERMOUNTAIN GAS COI},IPAI\TY
(3 pages)
and
NEWSRELEASE
A INTERMOUNTAIN
GAs COMPANY
A Subidiary of MtN Romlurrrr frwp, htc.
Intermountain Gas Company files decrease in prices as part of PGA and EEC lilings
BOISE, ID - August 10, 2022 - Intermountain Gas Company filed its annual purchased gas cost adjustment
(PGA) application with the Idaho Public Utilities Commission to decrease its prices by an average of 2.2%o or
approximately $7.7 million. The PGA application is filed each year to ensure the costs Intermountain incurs on
behalf of its customers are reflected in its sales prices. Additionally, the company filed an application to reduce
its Residential Energy Efficiency Charge, which would decrease prices to residential customers by an average
of 0.60/o or approximately $1.4 million. If approved, both decreases would be effective Oct. I ,2022.
The primary reason for the proposed PGA decrease is a small decrease in estimated gas commodity costs for the
upcoming year when compared to Intermountain's recently approved interim PGA as well as a refund of over-
collected residential energy efficiency funds. If approved, a typical residential customer would see a monthly
decrease of $1.36, or 2.5Yo based on average weather and usage. Commercial customers, on average, would see
a decrease of $4.32, or l.8o/o, per month.
The decrease in the residential EEC is due primarily to energy efficiency program changes and greater than
forecast sales which resulted in an over-collection of funds. Intermountain is proposing a one-time refund of the
current balance along with a reduction in the charge going forward. If approved, a typical residential customer
would see an additional decrease of $0.33 per month, or 0.60/o. When combined with the PGA decrease, an
average residential customer can expect a total decrease of $ I .69, or 3 .2Yo, per month based on average weather
and usage. Intermountain's eamings will not change as a result of either of the proposed changes in prices and
revenues.
"The natural gas market remains volatile with hot weather in the US, the economic rebound, and other global
events keeping prices at higher levels than we have seen in many years," said Scott Madison, executive vice
president of business development and gas supply.
Intermountain Gas urges all customers to use energy wisely. For more information about the company's energy
efficiency program and available rebates for installing high efficiency equipment, visit
www.intgas.com/saveenergy. Conservation tips, information on govemment payment energy assistance and
programs to help consumers level out their energy bills over the year can be found on the company's website
www.intgas.corn.
Both requests are proposals and are subject to public review and approval by the PUC. A copy of the
applications are available for review at the commission, its homepage www.puc.idaho.gov, as well as the
company's website www.intgas.com. Written comments regarding the applications may be filed with the
commission. Customers may also subscribe to the commission's RSS feed to review periodic updates via email
Intermountain Gas Company is a natural gas distribution company serving approximately 404,000 residential,
commercial ond industrial customers in 76 communities in southern ldaho. Intermountain is a subsidiary of
MDU Resources Group, Inc., o Fortune 500 company and member of the S&P MidCap 400 and the S&P High-
Yield Dividend Aristocrats indices, and is Building a Strong America@ by providing essential products and
services through its regulated energt delivery and construction moterials ond services businesses. For more
information about MDU Resources, see the company's website ot Vv,)t-LAfu,ggry. For more information about
Intermountain, visit www. intsas. com.
Media Contact: Mark Hanson at 701-530-1093 or [e-mail].
-^OtAW*'Customer Notice
lntermountain Gas Cornpany files decrease in prices as part of FGA and EEC filingst-C.-rtf,
BoEe rO lA,rgr.rst 1O,2O2.- lntermountain Gas Company filed hs annual prrchased gns cost adjuslrnent (PGA) application widr the
ldaho Public tltilities Commission to decrease its prices by an average of 2.8 or approximately $7.7 million. The PGA application is filed
each year to ensure the costs lntermqrntain incurs on behalf of its customers as rsfl€cred in its sales prices. Additionally, fie company
filed an application to redr.rce hs Residential Eneqgy Efficiency Charge, whklr rrvould decrease prices to residential cus*omers by an
average of 0.6% or approxinutely $1 .4 million. ff approved, bodr decreases wor.rld be efrectiw Oct. 1 , n22.
Ihe prinury reason lor the propos€d PGA decrease is a srnall decrease in estimated ges cornmodity costs fc,r the upcoming year urtren
compared to lnternountain's recendy approved interim PGA as well as a refund of over-collected rcsifuntial energy efficiency funds.
lf approved, a typical residential custoner would see a montrly decrease of $1 .36. q 2.5% bmed qr awrage rveadrer and usage.
Cqnmercial custotrprs. on aveege, would see a decrease of $4 .32, or 1 .8%, per nronth.
The decrease in the osidential EEC is due primarily to energy efficiency pro!,ram clunges and greater than forecast sales which
resuhed h an over-collection of funds. lntermounain is proposing a one-tirne refund of the cr.rrent balance along widr a reduaion in the
chage goirg foward. lf approrod, a tyFrical residential customer would see an additional decrease of $0.33 per month, or 0.6%. When
combined wi*r the PGA deosase. an awrirge residential customer c:rn el<pect a total decrease of $1.69, q 3.%, per mondr based
(conlinued m reveoe siJe)
on average weattnr and ucage. lntermountain's eamings will not chang€ as a resuh of either of the propoeed changes in prices and
re\renues
'The natural gas market remains volatile wifr hot npafrer in the US, fie economic rcbornd, and odrer global ewnts keeprng
price at higher levels than rve have seen in many years," said Scon Madison, exeorti\re vice president of business developrnent
and gas supply.
lntermountain Gas urges all custorners to use eneqgy wisely. For more information about the company's energy efficiency Program
and ayailable rebates for installing high efficiency equipnent visit ururw.intgas.com/saveenergy. Conservation tips, information on
govemrnent payrnent energy assistance and programs to help consumers level otrt fieir energy bills over the year can be found on the
company's urebeite wnvw.htgas.com.
Eodr requests are proposals and are subject to prublic oview and appoval by *re Pt C. A copy oI drc applhations arc available for review
at the commission, is homepage urwvr,.p"rc.idaho.gov, as ulell as the cornpany's website wmr.intgas.com. Written commenr reganCing
the applicatinns may be filed widr fie commission. Custonrers may also srbscribe to fre commissinn's RSS feed to rwiew periodic
updates via email.
-,^O+.-
lntermorrrtain Gm Company l Customer Service @54&3679 l M-E 7:30am - 6:3opm lnnww.intgas com AW*
ii(-trth
WORKPAPER NOS. 1-7
CASE NO. INT-C,.22.04
INTERMOUNTAIN GAS COMPAIIY
(14 pages)
Workpaper No. 1
Case No. INT-G22-04
lntermountain Gas Company
Page 1 of 2
INTERMOUNTAIN GAS COMPANY
Summary of Northrvest Pipeline TF-l Full Rate Demand Costs
LIne
Tran$oilation
tNT.&2t-r)4
AnnualTherms
tNT.G2t.04
Pricesfll
Ii{T.G21.04
Annual Gost0lNo.
(a)
TF-1 Reservdion Conbact #1
TF-1 Reserration Contmt f2
TF-1 Reservation Contat #3
TF-1 Reservation Conbact il4
TF-1 Reservdion Contact #5
TF-l Reserration Conbac-t #6
TF-'l Reserration Conbmt #7
TF-1 Reservation Conhact #8
TF-1 Reservation Conbact #9
TF-1 Reservation Conbact #10
TF-l Reservation Conbact#l 1
Total
Transportation
(b)
412,537,600
25,550,000
73,000,000
26,429,650
32,850,000
36,500,000
87,600,000
18,250,000
104,495,850
26,462,500
51,081,750
0.040001
0.044966
0.039033
0.039033
0.039033
0.039033
0.039033
0.039033
0,039033
0.039033
0.039033
16,501,952
1,148,891
2,U9,412
1,031,629
1,282,233
1,424,702
3,419,296
712,3s3
4,078,7U
't,032,9't4
1,993,876
(c)(d)
1
2
3
4
5
6
7
8
o
10
11
12
$$
lNT.G22.04
AnnualTherms
!NT.G22.04
Pricesfll
$ 35,476,042
tNT.G22.04
Annual Cost0
894,757,350
Llne
No.
(a)
TF-1 Reservation Confact #1
TF-1 Reservation Conhac't #2
TF-1 Reservation Contact #3
TF-1 Reservation Confac't #4
TF-1 Reservdion Conbact #5
TF-1 Reservation Contac't #6
TF-1 Reservalion Conbact #7
TF-1 Reservation Conbact #8
TF-l Reservalion Contac't #9
TF-I Reservation Confact #10
TF-I Reservation Contact #1 1
Total
(b)
412,537,600
25,550,000
73,000,000
26,429,650
32,850,000
36,500,000
87,600,000
18,250,000
104,495,850
26,462,500
51,081,750
(d)
$16,450,268
1,042,155
2,U9,412
1,031,629
1,282,233
1,424,702
3,419,296
712,353
4,078,7U
1,032,914
1,993,876
$ 35,317,622
$(158,420) (3)
(c)
13
14
15
16
17
18
19
20
21
22
23
24
25
$0.039876
0.040789
0.039033
0.039033
0.039033
0.039033
0.039033
0.039033
0.039033
0.039033
0.039033
894,757,350
TotalAnnual Cost Datference (Llne 24 minus Llne 12)
(') Column (d)divided by Column (b), rounded to 6 decimal places
(') Sum of the calctlated monthly ctsts
(') See Exhibit No. 5, Line 3, Column (h)
INTERMOUNTAIN GAS COMPANY
Summary of Northwest Pipeline TF-l Discounted Demand Gosts
Workpaper No. 1
Case No. INT-G-22-04
lntermountain Gas Company
Page2ol2
!NT.G.21.04
Annua! Costol
Line
No.Transportation
tNT.G.21.04
AnnualTherms
tNT.G.21.{r4
Pricesfl)
(c)(a)(b)
18,250,000
58,400,000
36,500,000
32,850,000
11,497,500
4,530,000
63,688,850
59,513,250
91,250,000
0.025372
0.025371
0.02v20
0.008500
0.035130
0.031227
0.009758
0.013662
0.009758
(d)
$463,030
1,481,690
854,818
279,225
403,901
141,457
621,492
813,O11
890,438
$ 5,%9,095
1NT.G.22.04
Annual CostP)
1
2
3
4
5
6
7
I
I
10
TF-1 Reservation Contract #1
TF-1 Reservation Contract #2
TF-1 Reservation Conhact #3
TF-1 Reservation Contract #4
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
Total
Transportation
!NT.G.22.04
Annual Therms
$
376,479,600
Line
No.
!NT.G.22.04
Pricesfl)
TF-1 Reservation
TF-1 Reservation
TF-1 Reservation
TF-1 Reservation
TF-1 Reservation
TF-1 Reservation
TF-1 Reservation
TF-1 Reservation
TF-1 Reservation
Tota!
Contract#1
Contract #2
Contract #3
Contract #4
Contract #5
Contract #6
Contract #7
Contract #8
Contract #9
(b)
18,250,000
58,400,000
36,500,000
32,850,000
11,497,500
4,530,000
63,688,850
59,513,250
91,250,000
0.025372
0.025371
0.02v20
0.008500
0.035130
0.$1n7
0.009758
0.013662
0.009758
(d)
$463,030
1,481,690
854,818
279,225
403,904
141,457
621,492
813,O11
890,438
$ 5,949,095
$
(c)(a)
11
12
13
14
15
16
17
18
19
20
$
376,479,600
21 TotalAnnual Gost Difference (Line 20 minus Line 10)
(1) Column (d)divided by Column (b), rounded to 6 decimalplaces
(2) Sum of the calculated monthly costs
(3) See Exhibit No. 5, Line 4, Column (h)
(3)
Workpaper No. 2
Case No. INT-G-22-04
lntermountain Gas Company
Page 1 of 2
INTERMOUNTAIN GAS COMPANY
Summary of Upstream Capacity Full Rate Demand Costs
No.Transpoilrtion
tNT€.2i.t4 lNT4.2t{4
fuinuat Thermc Prices(1)
(b)(c)(a)
1
2
3
4
5
6
7
8
I
10
11
12
Line
Upstream Agreement #1
Upteam Agreement#2
Upstream Agreement #3
Uptream Agreement ll4
Upstream Agreement #5
Upsfeam Agreement #6
Upsbeam Agreement #7
Upstream Agreement #8
Upsteam Agreement#9
Upsbeam Agreement#10
Upsteam Agreement#1l
Total
13 Estimated Upstream Capacity Release Credits
14 ToblAnnualCost lncluding Capacity Release Credlb
Transportation
25,933,250
351,503,260
26,962,5s0
37,244,600
26,126,700
'128,898,520
54,750,000
62,050,000
133,590,000
36,974,500
37,657,050
$ 0,006466
0.006470
0.006466
0.004m6
0.013466
0.013466
0.013466
0.013466
0.013466
0.01 3466
0.020188
tNTG.2l{4
Annual Cort0
(d)
$167,676
2,274,163
174,336
240,816
351,824
1,735,75'.1
737,2U
835,565
1,798,923
497,896
760,212
9,574,426
(500,000)
$ 9,074,426
tNT4.2244
Annual Cosda
Line
l{o.
921,690,430
lNIG.22{4
Annual Thermr
tNT€.22{4
Prices(l)
(a)
Upstream Agreement #1
Upsbeam Agreement f2
Upstream Agreement #3
Upsteam Agreement ll4
Upstream Agreement #5
Upsbeam Agreement #6
Upsfeam Agreement #7
Upstream Agreement#8
Upsteam Agreement #9
Upstream Agreement #10
Upsteam Agreement#1'l
Total
Estimated Upstream Capacity Release Credib
ToblAnnual Coat lncluding Capacig Release Grcdib
ToblAnnual Cott Difturence (Line 28 minus Line 14)
(r) Column (d) divided by Column (b), rounded to 6 decimal places
(2) Sum of the calculated monhly costs
(3) See Exhibit No. 5, Line 5, Column (h)
(b)
25,933,250
351,503,260
26,962,550
37,2M,600
26,126,700
't28,898,520
54,750,000
62,050,000
133,590,000
36,974,500
37,657,050
$ 0.009103
0.009109
0.009103
0.009103
0.013496
0,013496
0.013496
0.013496
0.013496
0.013496
0.022200
(d)
$236,076
3,201,859
245,M8
339,048
352,607
1,739,619
738,903
837,425
1,802,933
499,003
835,968
10,828,889
(500,000)
$ 10,328,889
(c)
15
't6
17
18
19
20
2t
22
23
24
25
26
27
28
29
921,690,430
$1.254./m3 (3)
Wortpaper No.2
Case No. INT-G-22-04
lntermountain Gas Company
Page2ol2
INTERMOUNTAIN GAS COMPANY
Summary of Upstream Capacity Discounted Demand Costs
Line
No.Transportation
!NT.G.21.04
AnnualTherms
!NT.G.21.04
Pricesfl)
!NT.G.21{t4
Annual Cost€)
(c)(a)(b)(d)
452,311,650 $ 0.018245 $ 8,252,508
452,311,650 $ 9,252,508
1
2
Line
No.
Upstream Agreement #1
Total
Transportation
tNT.G.22.04
AnnualTherms
tNT.G.22.04
Pricesfll
!NT.G.22.04
Annual CostP)
Upstream Agreement #1
Total
Total Annual Cost Difference (Line 4 minus Line 2)
Column (d) divided by Column (b), rounded to 6 decimal places
Sum of the calculated monthly costs
See Exhibit No. 5, Line 6, Column (h)
(b)(c)(d)
452,31'1,650 $ 0.020056 $ 9,071,4W
452,311,650 $ 9,071,4U
$g1g,976 (3)
(a)
3
4
5
(1)
@
(3)
Workpaper No. 3
Case No. INT-G-22-04
lntermountain Gas Company
Page 1 of 1
INTERMOUNTAIN GAS COMPANY
Summary of Other Storage Facilig Costs
Line
No.Stonge Facilities
ll{T.G.2l{1
ilonthly
Billing Determinant
(b)
266,2s0
221,880
213,010
31,950,000
26,625,000
25,560,000
INT.G.22.O4
Monthly
Billing Deteminant
(b)
lNT.G21.t,1
Prices
]NT.G.21.{t1
Monthly Cost
1ilT.G.21.01
Annual Cort
(a)
Clav Basin Costs:
Clay Basin I Reseruation
Clay Basin ll Reservation
Clay Basin lll Reservation
Clay Basin I Capacity
Clay Basin ll Capacity
Clay Basin lll Capacity
Total Clay Basin Costs
Rerburo LilG Facilitv:
Transportation Reservation
Variable Transprtation
Total Rexburg LNG Facility Cosb
Stonge Demand Charye Credit
Total Costs lncluding Slorage Credit
Stonge Facilities
$ 911,6s2
759,732
729,360
911,724
759,768
729,3U
$ 4,801,620
(c)(d)(e)
1
2
3
4
5
6
7
8
fl)$
(1)
(l)
t2)
t4
ttl
0.285338
0.285338
0.28s338
0.002378
0.002378
0.002378
75,971
63,311
60,780
75,977
63,314
60,782
$
$400,'135
I
10
11
12
13
14
tNT.G.22,04
Prices
tNT.G.22.01
Monthly Cost
$66,000
18,000
$84,000
$ (2,300,000)
$ 2,585,620
tilT.G.22{t1
Annual Cost
Line
No.
(a)
Chv Basin Costt:
Clay Basin I Reservation
Chy Basin ll Reservation
Clay Basin lll Reservation
Clay Basin I Capacity
Clay Basin ll Capacity
Clay Basin lll Capacity
Total Clay Basin Cosb
266,250 (1)
221,880 (l
213,010 (1)
3t,950,000 (2)
26,625,000 (2)
25,560,000 (2)
(c)(d)(e)
15
16
17
18
't9
20
21
22
23
24
25
26
27
28
29
$$0.285338
0.285338
0.285338
0.002378
0.002378
0.002378
75,971 $
63,311
60,780
75,977
63,314
60,782
911,652
759,732
729,360
911,724
759,768
729,3U
Rexburq LNG Facilitv:
Transportation Reservation
Variable Transportation
Total Rexburg LNG Facility Cosb
Estimated Stomge Demand Charge Credit
Total Costs lncluding S:torage Credit
Total Annual Cost Difference (Line 28 minus Line 14)
{r) Charge Based on Maximum Daily Withdrawal
(2) Charge Based on Maximum Contractual Capacity(t) See Exhibit No.5, Line 20, Column (h)
$400,13s $ 4,801,620
$66,000
18,000
$84,000
$ (2,300,000)
$
$
2,585,620
(3)
Wbrkpaper No. 4
Case No. INT-G-22-04
lntermountain Gas Company
Page 'l of 1
INTERIIOUNTAIN GAS CO]IIPANY
Allocation Factors
Llna
ilo.Descrldon
(a)
ll{T€.2.04 Co3t of Gts Allocltors:
Peak Demand Psr Cusbmer
January 2022 Ac{ud Customes
INI-G2244 Peak Demand Therms (Ljne 2 tmes Line 3)
PercentofTotd
ll{T.G.22fl LIG SCcc Crcdlt lhrnnd Alocrton:
Peak Demand Fer Customer
January 2022 Actual Custome]s
INT-G2244 Peak Demand Thems (Line 7 times Line 8)
Peroent ofTotal
Ordlr NG 33r, Alocrton of Brso Rato Rovsrurs:
Appoved Bae Rab Rercnues
PeroentofTotd
Allocdlon of Bae Rrte Rwcnuor to RS rnd GS.l Rile Clmsas:
frEr l'lo. 337$/ Approved Base Rde Revenues
PercentofTohl
Ferk
RS Ggl LV.l I.3 T.1 Toel
-lbi-----G,--i- T -- -)-1
2
3
4
5
7.89
*4,711
2,8n,570g.EM
7.89
364,7il
2,8n,{70
ilfiill$
$ 5/,675,297
or.tiuo[
37.96
35,069
1,331,219
3Us4[
37.96
&5,069
1,331,219
n;Llg&
$ 22,067,934 $
!4.0910t
69,680 (i)
L0&0s I'l/A
4,278,4E9
t@,00f,
5,613,879
1@,00b
$ 89,376,264
lCIoqh
iUA
6
7I
I
t0
1'l
12
,l3
14
15
16
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L211%
't,335,410 (r)
B;I$MMA
339,403
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$ 532,754
0rsls
$ 8,760,876
9,N2ft
$ 57,675,297
12,3s!j6
$ 22,067,931
zlitlt:h
$ 79,743,23'l
10,oqr
()confrt Demand
WbdpaperNo 5
Casa No. INT+22-04
lntcflnounErl GB Compty
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Case tlo. INT-G,Z+{
lnErr[ountaln GB Company
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Analysb of LY.l Tariff Block I, Block 2, and Block 3 Adiultment!
Workpaper No. 6
Case No. INT-G-22-04
lntermountain Gas Company
Page 1 ofl
Total
Lino
No.Description
Block I
Them Sales
Block 2
Therm Saler
Block 3
Therm Sales
(a)
LV-1 Therm Sales (1/1/21 -12lilml
Blocks 'l and 2 Therm Sdes
Percent Them Sales between Blocks 1 and 2
(b)
12,399,432
12,399,432
't00.000%
(c)(d)(e)
12,399,432
12,399,432
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0.03001 fl)
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5
6
7
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15
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Propsed Adjmtmentto LVI Tarifi
LV-'l Them Sales Wlm -lAflml
Annualized Adjustment (Line 4 times Line 5)
Annualized Adju$ment (Line 6)
Percent Annudized Sales induded in Block 'l and Block 2
Adjustnent to Block 1 and 2 (Line 7 times Line 8)
Blockl and2Therms
Price AdjustnenUTherm Block 1 and 2 (Line 9 divided by Line 10)
WACOG Commodity Charge Change
Total Price AdjuilmrnUThem Block I and Block2
Price AdjusfnenUTherm Block 3
WACOG Commodity Charge Change
Eliminate INT-G21{4 VariaHe Temporary
Total Pdce AdiudmenUTherm Block 3
(r) See Exhibit No, 5, Line 3'1, Column (k) minus the difierence of Line 22, Column (f) minus Column (c)
(2) See Exhibit No. 5, Line 22, Column (f) minus Column (c)
(') See Exhibit No. 7, sum of Lines 3 - 4, Column (d)
(o) See case No. INT-@2144
$
$
$
$
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100,000%
372,107
't2,399,432
$0.03001
(0.03't89) (2)
$ (0.00188)
$0.05210 G)
(0.0318s) P)
(1)
Wortpaper No. 7
Case No. INT-G22-(X
lntermountain Gas Company
Page 1 of1
INTERTIOUNTAI}I GAS COTIPAT{Y
Lolt trtd Un$counbd hr Gas
(Volum€s in Therms)
Llno
No.De6crlpuon Oct2018-Sopt20l9 OdAl9-Sopt2020 Oct2020.Sot202l
(r)(b)
301,931,101
373,0s2,004
I 1,825,283
(c)
*1,n4,151
363,513,90s
1,455,E18
568,080
(d)
103,730,817
36E,193,748
4,623,36E
t0,tg)
s
$
6
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10
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12
13
14
'15
16
17
18
19
20
21
2
n
Colo Crrstomer Pur$asod Gas
TraBporHion Cusbmor Gas
LJ,lG Shrage Wi0drawals
Urdor Deliveries of Gas tom Pipoline (M)
Tohl Dallver'l€s to Syctsm
CorcCusbmerBihd G6
Ur$ited Adjrrstnent
TrarprHion Cubmor Biled Gas
Company Use G6
LJ.lG Sbrage lnjeclions
Une BlBal(s - Found Gas
othsr Found Gas
over Deliveries of G6 from Pipolino (Pd)
Tohl Ddivedes h Cr6bmeIs
Lo.U(Found) Gil (Llno 5 mlnut itl)
Averags Purchase WACoG
Cost of tosU(Found) G6 (Lin€ I 5 tm€E Line 1 6)
Lost Grr lfihontt (Llnc 17 dMd.d by Uoo O
LosU(Found) Gas (Uns 10
Losu(Found) Gas Therms Dehned
Lost(Found) Gas Adlustneflt (Une 19 minus Line 20)
Actual Lost Gas Rab (Une t5 dMded by Une 0
aY.r?Avongo LoctGl3 fut
26,E0E,691
38E,323,201
3,n2,N
3B,0sam4
3S,104
19384,891
329,664
759,761,957
4m,fi7,998
(3,731,984
363,513,905
318,1 39
1,086,497
fi4,7n
fi,9n
26,558,083
409,747,004
634,r62
36E,193,748
fi2,9n
3,068,540
'132,070
432,630
n8,n2,7%781,3fi,252 781,95E,447
(1,394,100 fl,596,45)(5,{00,364)
$0.21535 $0.a2fi $0.2282
($0,22r) $
(0.00039) $
(33e,034 $
(0.00040 $
(,n1,9111
(0.00158)
(5,400,364)(1,394,105)
568,915
(1,596,295)
745,782
(r,963,020)
{.'r79570
---lffiilnr
e,v10m
{.2101%
(5,100,364)
{.6S3t%
-0.3617%-0.'fi93% o
(') Soe Case No. INT-G2G05ra See Case No. lrr-e2t{)4{x CunantPM}YeaAverage