20170814Application.pdf

EXECUTIVE OFFICES
I NtEnruouNTAlru Ges CoruPnNY
555 soUTH coLE ROAD o P.o. BoX 7608 . BOISE,IDAHO 83707 ' [phone] o FAX:[phone]
. i ,. ,
August 14,2011
Ms. Diane Hanian
Commission Secretary
Idaho Public Utilities Commission
472 W. Washington St.
P.O. Box 83720
Boise, lD 83720-0074
RE: Case No. INT-G-17-05
Dear Ms. Hanian:
Attached for consideration by this Commission are the original and seven (7) copies of Intermountain Gas
Company's Application for Authority to Change Its Prices on October 1,2017.
If you should have any questions regarding this Application please contact me at 208-3 77 -6168
Sincerely,
P.
Director-Re gulatory Affairs
Intermountain Gas Company
Enclosure
cc: Mark Chiles
Scott Madison
Ronald L. Williams
i' - !?'r ir-'r-.' - it/ -i I
INTERMOTINTAIN GAS COMPANIY
: l. Dr,l ?. i:'.1i -, i i, a. L-,u
i. i. i , rCASE NO. INT.G-17.05
APPLICATION,
E)GIIBITS,
AND
WORKPAPERS
In the Matter of the Application of INTERMOUNTAIN GAS COMPAII-Y
For Authority to Change lts Prices on October 1,2017
(October t,2017 Purchased Gas Cost Adjustment Filing)
Ronald L. Williams, ISB 3034
Williams Bradbury PC
802 W. Bannock, Suite 900
Boise,Idaho 83702
Telephone: [phone]
Attorney for Intermountain Gas Company
In the Matter of the Application of
INTERMOUNTAIN GAS COMPANY
BEFORE T}IE IDAHO PUBLIC UTILITIES COMMISSION
Case No. INT-G-17-05
APPLICATION
for Authori8 to Chanse Its Prices
Intermountain Gas Company ("Intermountain" or "Company'), a subsidiary of MDU
Resources Group, Inc. with general offices located at 555 South Cole Road, Boise, Idaho, pursuant
to the Rules of Procedure of the Idaho Public Utilities Commission ("Commission"), hereby requests
authority, pursuant to Idaho Code Sections 61-307 ard 6l-622, to place into effect October 1,2017
new rate schedules *trich will decrease its annualized revenues by $19.2 million. Because of changes
in Intermountain's gas related costs, as described more fully in this Application, lntermountain's
earnings will not be impacted as a result of the proposed changes in prices and revenues.
Intermountain's current rate schedules showing proposed changes are attached hereto as Exhibit No.
1 and are incorporated herein by reference. lntermountain's proposed rate schedules are attached
hereto as Exhibit No. 2 and are incorporated herein by reference.
Communications in reference to this Application should be addressed to:
Michael P. McGrath
Director - Regulatory Affairs
Intermountain Gas Company
Post Office Box 7608
Boise,ID 83707
and
Ronald L. Williams
Williams Bradbury PC
802 W. Bannock, Suite 900
Boise,Idaho 83702
In support of this Application, lntermountain does allege and state as follows:
APPLICATION - 2
I.
Intermountain is a gas utility, subject to the jurisdiction of the Commission, engaged in the
sale of and distribution of natural gas within the State of Idaho under authority of Commission
Certificate No. 219 issued December 2,1955, as amended and supplemented by Order No. 6564,
dated October 3,1962.
Intermountain provides natural gas service to the following Idaho communities and counties
and adjoining areas:
Ada County - Boise, Eagle, Garden City, Kuna, Meridian, and Star;
Bannock County - Arimo, Chubbuck, lnkom, Lava Hot Springs, McCammon, and Pocatello;
Bear Lake County - Georgetown, and Montpelier;
Bingham County - Aberdeen, Basalt, Blackfoot, Firth, Fort Hall, Moreland./Riverside, and Shelley;
Blaine County - Bellevue, Hailey, Ketchum, and Sun Valley;
Bonneville County - Ammon,Idaho Falls, Iona, and Ucon;
Canyon County - Caldwell, Greenleaf Middleton, Nampa, Parm4 and Wilder;
Caribou County - Bancroft, Grace, and Soda Springs;
Cassia County - Burley, Declo, Malta, and Raft River;
Elmore County - Glenns Ferry, Hammett, and Mountain Home;
Fremont County - Parker, and St. Anthony;
Gem County - Emmett;
Gooding County - Gooding, and Wendell;
Jefferson County - Lewisville, Menan, Rigby, and Ririe;
Jerome County - Jerome;
Lincoln County - Shoshone;
Madison County - Rexburg, and Sugar City;
Minidoka County - Heybum, Paul, and Rupert;
Owyhee County - Bruneau, and Homedale;
Payette County - Fruitland, New Plymouth, and Payette;
Power County - American Falls;
Twin Falls County - Buhl, Filer, Hansen, Kimberly, Murtaugh, and Twin Falls;
Washington County - Weiser.
Intermountain's properties in these locations consist of transmission pipelines, liquefied
natural gas storage facilities, a compressor station, distribution mains, services, meters and regulators,
and general plant and equipment.
U.
Intermountain seeks with this Application 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 ("Northwest" or "Northwest Pipeline"),2) adecrease in
Intermountain's Weighted Average Cost of Gas, or "WACOG", 3) an updated customer allocation of
gas related costs pursuant to the Company's Purchased Gas Cost Adjustrnent ("PGA") provision,4)
APPLICATION - 3
the inclusion of temporary surcharges and credits for one year relating to natural gas purchases and
interstate transportation costs from lntermountain's defened gas cost accounts, 5) benefits resulting
from lntermountain's management of its storage and firm capacity rights on various pipeline systems,
and 6) costs accrued related to Intermountain's General Rate Case. Intermountain also seeks with
this Application to eliminate the temporary surcharges and credits included in its current prices during
the past 12 months, pursuant to Case No. NT-G-16-03. The aforementioned changes would result
in a price decrease to Intermountain's RS and GS-1 customers and a price increase to lntermountain's
LV-1, T-3 and T-4 customers.
These price changes are applicable to service rendered under rate schedules affected by and
subject to lntermountain's PGA, initially approved by this Commission in OrderNo.26109, Case No.
INT-G-95- l, and additionally approved through subsequent proceedings.
Exhibit No. 3 contains pertinent excerpts from applicable pipeline tariffs. Exhibit No. 4
summarizes the price changes in: 1) Intermountain's base rate gas costs, 2) its rate class allocation,
and 3) adjusting temporary surcharges or credits flowing through to Intermountain's customers.
Exhibit Nos. 3 ard 4 are attached hereto and incorporated herein by reference.
III.
The current temporary and cost of gas related prices of lntermountain are those approved by
this Commission in OrderNo.33604, Case No. INT-G-16-03. The current base rate charges are those
approved as part of Order No . 337 57 , Case No. INT-G- 16-02.
IV.
Intermountain's proposed prices incorporate all changes in costs relating to the Company's
firm interstate transportation capacity including, but not limited to, any price changes or projected
cost adjustments implemented by the Company's pipeline suppliers as well as any volumetric
adjustments in contracted transportation agreements which have occurred since Intermountain's
PGA filing in Case No. INT-G-16-03.
The permanent transportation and storage costs included with this Application reflect a net
decrease of approximately $1.3 million as compared to those same costs included in Case No. INT-
G-l6-03. Northwest Pipeline transportation and storage costs reflect the removal of the 2016leap
year rates included in Case No. INT-G-16-03 as well as a reduction in transportation and storage
rates pursuant to FERC Docket No. RPIT-567-000 resulting in a reduction in annual transportation
and storage costs to the Company's customers. The Company's upstream transportation charges had
APPLICATION - 4
a 54,062 net increase resulting from rate changes from the Company's upstream transportation
providers.
Intermountain continues to effectively manage its natural gas storage assets at Northwest's
Jackson Prairie and Questar Pipeline's Clay Basin storage facilities. Supporting documents
relating to Line 20 of Exhibit No. 4 include $1.8 million in savings from Intermountain's
management of these storage assets.
Exhibit No. 4, Lines 1 through 20, details the proposed changes to Intermountain's prices
resulting from Intermountain's cost of storage, and interstate and upstream capacity from its
various suppliers.
v.
The WACOG reflected in Intermountain's proposed prices is $0.26020 per therm, as shown
on Exhibit No. 4, Line 22, Col. (f. This compares to $0.29695 per therm currently included in the
Company's tariffs.
Advanced drilling technologies continue to increase drilling effrciencies resulting in even
higher production in shale gas wells. Deliverable shale gas reserves in North America are abundant
and supplies, in the face of growing demand for natural gas, have continued to outpace the demand
for this natural resource. This supply/demand imbalance has contributed greatly to the decrease in the
Company's WACOG. From a historical perspective, robust natural gas supplies combined with
significant storage balances have kept natural gas prices lower iN compared to even a year ago.
Additionally, the proposed WACOG includes benefits to lntermountain's customers
generated by the Company's management of its significant natural gas storage assets. Because gas
added to storage is procured during the summer season when prices are typically lower than during
the winter, the cost of Intermountain's storage gas is normally less than what could be obtained on
the open market in winter months. Additionally, in an effort to further stabilize the prices paid by our
customers during the upcoming winter period, lntermountain has entered into various fixed price
agreements to lock-in the price for portions of its underground storage and other winter "flowing"
supplies.
Intermountain believes that the WACOG proposed in this Application, subject to the effect of
actual supply and demand and based on current market conditions, provides today's most reasonable
forecast of gas costs for the 2017 -201 8 PGA period. lntermountain will employ, in addition to those
fixed price agteements already in place, cost effective price arrangements to further secure the price
APPLICATION - 5
of flowing gas embedded within this Application when, and if, those pricing opportunities materialize
in the marketplace.
Intermountain believes that timely natural gas price signals enhance its customer's ability to
make informed and appropriate energy use decisions. The Company is committed to alert customers
to any significant impending price changes before their winter natural gas usage occurs. By
employing the use of customer mailings, the Company's website, and various media resources,
Intermountain will continue to educate its customers regarding the wise and efficient use of natural
gas, billing options available to help manage their energy budget, and any pending natural gas price
changes.
vr.
Pursuant to the Commission's Order in Case No. INT-G-16-03,Intermountain included
temporary credits in its October 1,2016 prices forthe principal reason ofpassing back to its customers
deferred gas cost benefits. Lne27 of Exhibit No. 4 reflects the elimination of these temporary credits.
vII.
Intermountain's PGA tariffincludes provisions whereby lntermountain's proposed prices will
be adjusted for updated customer class sales volumes and purchased gas cost allocations.
Intermoturtain's proposed prices include a fixed cost collection adjustrnent pursuant to these PGA
provisions, as outlined on Exhibit No. 5, Line25. The price impact of this adjustrnent is included on
Exhibit No. 4,Line 28. The Fixed Cost Collection Rate resulting from the adjustment plus the annual
difference in demand charges from Exhibit No. 4, Lines I - 20, Col. (h) is shown on Exhibit No. 5,
Lne 29. Exhibit No. 5 is attached hereto and incorporated herein by reference.
vrII.
Intermountain proposes to pass through to its customers the benefits that will be generated
from the management of its transportation capacity totaling $3.7 million as outlined on Exhibit No.
7. These benefits include credits from a segmented release of a portion of lntermountain's firm
capacity.ights on Northwest Pipeline and other non-segmented capacity releases. hrtermountain
proposes to pass back these credit amounts via the per therm credits, as detailed on Exhibit No. 7 and
included on Exhibit No. 6, Line 1. Exhibit Nos. 6 and 7 are attached hereto and incorporated herein
by reference.
APPLICATION - 6
IX.
Intermountain proposes to allocate defened gas costs from its AccountNo. 191 balance to its
customers through temporary price adjustments to be effective during the l2-month period ending
September 30, 2018, as follows:
1) tntermountain has deferred fixed gas costs in its Account No. l9l. The credit amount
shown on Exhibit No. 8, Line 7, Col. (b) of $16.2 million is attributable to a true-up of the collection
of interstate pipeline capacity costs, the true-up of expense issues previously ruled on by this
Commission, and mitigating capacity release credits generated from the incremental release of
Intermountain's pipeline capacrty. Intermountain proposes to true-up these balances via the per therm
debits and credits, as detailed on Exhibit No. 8 and included on Exhibit No. 6, Line 2. Exhibit No. 8
is attached hereto and incorporated herein by reference.
2) lntermountain has also deferred in its Account No. 191 a variable gas cost debit of $2.4
million, as shown on Exhibit No. 9, Line 2, Col. (b). This defened debit is attributable to
Intermountain's variable gas costs since October 1,2016. lntermountain proposes to collect this
balance via a per therm charge, as shown on Exhibit No. 9, Line 4, Col. (b) and included on Exhibit
No. 6, Line 3.
3) Finally, lntermountain has defened in its Account No. 191 defened gas costs related to
Lost and Unaccounted for Gas as shown on ExhibitNo. 9, Lines 5 through 26,Col. (b). This deferral
results in net per therm decreases to lntermountain's sales customers, as illustrated on Exhibit No. 9,
Ltne 12, Col. (b). The Lost and Unaccounted for Gas deferral results in a per therm decrease for
Intermountain's transportation customers as shown on Exhibit No. 9, Lne 20 and Line 26, Col. (b).
Exhibit No. 9 is attached hereto and incorporated herein by reference. These per therm decreases are
included on Exhibit No. 6, Line 3.
x.
Pursuant to Commission Order No. 32793, Case No. NT-G-13-02, lntermountain has
deferred in its Account No. I 9 1 variable gas cost credits associated with sales of liquefied natural gas
at its Nampa, Idaho facility. Intermountain proposes to pass back this $495,418 sales credit as outlined
on Exhibit No. I 0, Line 7 . Exhibit No. l0 is attached hereto and incorporated herein by reference.
xr.
Intermountain has allocated the proposed price changes to each of its customer classes based
upon lntermountain's PGA provision. However, a straight cents per therm price change was not
APPLICATION - 7
utilized for the LV-1 tariff as no fixed costs are currently recovered in the tail block of the LV-1 tariff.
The proposed changes in the WACOG, and variable defened debits and credits as outlined on Exhibit
No.'s 9 and 10, are applied to all three blocks of the LV-l tariff. However, all adjustrnents relating to
fixed costs are applied only to the first two blocks of the LV-l tariff.
xII.
As outlined on Exhibit No. 1, Page 1, Lines 21 through 28, the T-3 and T-4 tariffs
include the following adjustnents: a) removal of existing temporary price changes; b) the Lost and
Unaccounted for Gas decrease as outlined on Exhibit No. 9; c) the LNG Sales Credits are applied to
the T-4 tariff as illustated on Exhibit No. 10, Line 7, Col. (f) and, d) a temporary adjustment to
recover lntermountain's general rate case related expenses. The net change from these
aforementioned adjustrnents result in a rate increase for the Company's T-3 and T-4 customers.
xIIl.
Pursuant to Commission Order No. 33757, Case No. NT-G-16-02, Intermountain was
directed to include for recovery within this PGA $25,178 of intervenor funding to be allocated
proportionally according to base rate revenues within each customer class. Exhibit 1l outlines the
recovery of this funding as well as its customer class allocation. Exhibit 1l is attached hereto and
incorporated herein by reference.
xlv.
Pursuant to Commission Order No .33432, Case No. INT-G-I5-03, Intermountain established
a regulatory asset to defer extemal rate case costs associated with Case No. INT-G-16-02. The
Company requests with this Application that these deferred costs, or $699,114, be amortized and
collected over a four-year period as outlined on Exhibit No. 12. Exhibit 12 is attached hereto and
incorporated herein by reference.
xv.
Exhibit No. 13 is an analysis of the overall price changes by class of customer. Exhibit No.
13 is attached hereto and incorporated herein by reference.
xvl.
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 lntermountain's
customers.
APPLICATION - 8
XVII.
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 lntermountain's service area. The Press Release and Customer Notice are
attached hereto and incorporated herein by reference. Copies of this Application, its Exhibits, and
Workpapers have been provided to those parties regularly intervening in Intermountain's rate
proceedings.
APPLICATION - 9
xvIII.
Intermountain requests that this matter be handled under modified procedure pursuant to
Rules 201-204 of the Commission's Rules of Procedure. Intermountain stands ready for immediate
consideration of this matter.
WHEREFORE, Intermountain respectfully petitions the ldaho Public Utilities Commission as
follows:
a. That the proposed rate schedules herewith submitted as Exhibit No. 2 be approved without
suspension and made effective as of October 1,2017 in the manner shown on Exhibit No. 2.
b. That this Application be heard and acted upon without hearing under modified procedure,
and
c. For such other relief as this Commission may determine proper herein.
DATED at Boise, ldaho, this l4th day of August,2017.
INTERMOUNTATN GAS COMPANY Williams Bradbury PC
l?r,,t Ltrl//--By
M
D Affairs
By
Ronald L. Williams
Attorney for lntermountain Gas Company
APPLICATION - IO
CERTIFICATE OF MAILTNG
I HEREBY CERTIFY that on this l4th day of August, 2017, I served a copy of the
foregoing Case No. INT-G-17-05 upon:
Ed Finklea
Northwest Industrial Gas Users
545 Grandview Drive
Ashland, OR 97520
Chad Stokes
Cable Huston et al.
1001 SW Fifth Avenue, Suite 2000
Portland, Oregon 97204-1136
Don Sturtevant
J. R. Simplot Company
PO Box 27
Boise, lD 83707
by depositing true copies thereof in the United States Mail, postage prepaid, in envelopes addressed
to said persons at the above addresses.
Regulatory Affairs
APPLICATION - II
EXHIBIT NO. I
CASE NO. INT.G-17.05
INTERMOUNTAIN GAS COMPANY
CIIRRENT TARIFFS Showing
Proposed Price Changes
(11 pages)
Exhibit No. 1
Case No. INT-G-'l7-05
lntermountain Gas Company
Page I of 11
INTERMOUNTAIN GAS COMPANY
Comparison of Proposed October 1,2017 Prices
To May 1,2017 Prices
Line
No.Rate Class
Prices per
tNT.G.16.02
Order No. 33757
Proposed
Adjustment
Proposed
October 1,2017
Prices
(a)(b)
$ 0.63676 $ (0.05900) $ 0.57776
(d)(c)
1RS
GS.12
3
4
5
b
7
8
9
10
Block 1
Block 2
Block 3
Block 4
CNG Fuel
Block 1
Block 2
0.65288
0.62847
0.60491
0.53596
0.60491
0.53596
0.63676
0.65288
0.62847
0.60491
0.53596
0.30000
0.37551
0.35623
0.29314
0.03929
0.01542
0.00507
0.27885
0.02638
0.00932
0.00286
(0.06226)
(0.06226)
(0.06226)
(0.06226)
(0.06226)
(0.06226)
(0.05e00)
(0.06226)
(0.06226)
(0.06226)
(0.06226)
0.00270 (3)
0.00270 p)
(0.02328) (4)
0.00036 (5)
0.00036 6)
0.00036 (s)
0.00267 (s)
0.59062
0.56621
0.54265
0.47370
0.54265
0.47370
0.57776
0.59062
0.56621
0.54265
0.47370
0.30000
0.37821
0.35893
0.26986
0.03965
0.01578
0.00543
0.28152
0.02638
0.00932
0.00286
ls-R (1)
ls-c (2)
11
12
13
14
15
Block 1
Block 2
Block 3
Block 4
Demand Charge
Block I
Block 2
Block 3
Block 1
Block 2
Block 3
Demand Charge
Block 1
Block 2
Block 3
16
17
18
19
20
LV-1
T.3
T4
21
22
23
24
25
26
27
28
(') The lS-R price is based on the RS price and receives the same PGA adjustrnents
@ The lS-C price is based on the GS-l price and receives the same PGA adjusfnents
(3) See Workpaper No. 6, Line 13, Column (e)
(a) See Wokpaper No. 6, Line 17, Column (e)
(0 Remore INT-G-16{3 temporary and add the temporary from Exhibit No. 6, Line 7
Exhibit No. 1
Case No. INT-G-17-05
lntermountain Gas Company
Page 2 of 11
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I.P.U.C. Gas Tariff
lndex
firctRovissd Second Sheet No. C
NarnE
af tJtlltly Intermountain Gas Company
Exhibit No. 1
Case No. INT-G-17-05
lntermountain Gas Company
Page3of11
IDAHO PUBLIC UT'LITIES COIiMISSIONApproved Elfuctlve
Jsan D. Jewsll Sectutary
INDEX
RATE SCHTDULES
SCHEDULE
Ml.
TrrLE SHEET
RS"r*
{8.C
G$,'t
IS.R
rs-c
LV.1
T-3
T-4
&6*
H-1
PGA
ER
FT
+{sating-..
fl esidential lntenuptible $nomnelt Service 4
$mallCommerciallnteruptibleSnowmeltService......... .............,..5
Eirm
Large Volume Sales Seruice ........,.....7
lntenuptibleDistribulionTranspoflationService ....-........................8
Firm Distribution OnlyTransportatbn Servioe.......... ..,.^...........,....,9
.........JS
Reeidential Space Heating Equipment Rebate........., .........,....-.."...14
rssued by: lntermountaln Gas CompanyBy: Michael P. McGrath Title: Director.- Regulatory Affairs
Effective:
Exhibit No. 1
Case No. INT-G-17-05
lntermountain Gas Company
Page 4 ot 11
Rate Schedule RS
RESIDENTIAL SERVICE
APPLICABILITY:
Applicable to any customer using natural gas for residential purposes.
RATE:
Monthly minimum charge is the Customer Charge.
IDAHO PUBLIC UTILITIES COMMISSIONApproved EffectiveMay{&,-304# Me4-4i-A04?
For-@rN'3E767
Diane M. Hanian Secretary
$o€4e6+) ($0.053e5)
-$e€069e $0.26020{o*fi+t $0.1e964
Customer Charge:
Per Therm Charge:
*lncludes the following:
Cost ofGas:
$5.50 per bill
$&63676- $0.57770
1) Temporary purchased gas cost adjustmenl
2) Weighted average cost of gas
3) Gas transportation cost
Distribution Cost:$0.17187
PURCHASED GAS COST,ADJUSTMENT:
This tariff is subject lo an adjustment for cost of purchased gas as provided for in the Company's Purchased
Gas Cost Adjustment Schedule.
SERVICE CONDI'TIONS:
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.
rssrred by: lntermountain Gas Conrpany
By: Michael P. McGratlr l-itle: Director - Regulatory Affairs
LP.U.C. Gas l'ariff
Rate Schedules
[4rst Revised Secottd Slreet No. 1 (Page 1 of 1)
Nanre
of Utillty lntermountain Gas Company
Effective:
Exhibit No. 1
Case No. INT-G-17-05
lntermountain Gas Company
Page5of11
IDAHO PUBLIC UTILITIES COMMISSIONApproved EffectiveMay-+9;-20+7. May-{73047
Per-&!S-SOiF57
Dlane M. Hanlan Secretary
Rate Schedule GS-l
GENERAL SERVICE
APPLIGABILITY:
Applicable to customers whose requirements for natural gas do not exceed 2,000 therms per day, at any point
on the Company's distribution system. Requirements in excess of 2,000 therms per day may be served under
this rate schedule upon execution of a one-year written service contract.
RATE:
Monthly minimum charge is the Customer Charge.
Customer Charge:
Per Therm Charge:
$9.50 per bill
Block One:
Block Two:
Block Three:
Block Four:
200 therms per
1,800 therms per
8,000 therms per
10,000 therms per
$&662€8"
$g€e847*
$0,6049+*
$es3696',
$0.6426s
$0.47370
First
Next
Next
Over
First
Next
Next
Over
$0.59062
$0.56621
biil @
bill @
bil @
bi[ @
blll@
bifl @
bifi @
*lncludes the following:
Cost of Gas:
Distribution Cost:
Temporary purchased gas cost adjustrnent
Weighted average cost of gas
Gas transportation cost
6e05444) ($0.06277)
$0*9696 $0.26020
$03+545 $0.20127
$0.19192
s0.16751
$0.14395
$0.07500
1)
2)
3)
Block One:
Block Two:
Block Three:
Block Four:
200 therms per bill @
1,800 therms per
8,000 therms per
10,000 therms per
lssued by: lntermountain Gas Gompany
By: MichaelP. McGrath Title: Director * Regulatory Affairs
Effective:Oclober'1.2017
l,P.U,C, Gas Tariff
Rate Schedules
Fifty-F.ifth Revised Sixth Sheet No.3 (Page 1 of 2)
Name lntermountain Gas Companyof Utillty
Exhibit No. 1
Case No. INT-G-17-05
Intermountain Gas Company
Page6of11
IDAHO PUBLIC UTILITIES GOMMISSIONApproved EffectiveMaf4s40{+ llay--{re0+7
ForO,N'03767
Dlane M. Hanlan Secretary
Rate Schedule GS-l
GENERAL SERVICE
(Continued)
For separately metered deliveries of gas utilized solely as Compressed Natural Gas Fuel in vehicular internal
combustion engines.
Customer Charge: $9.50 per bill
Per Therm Charge:
'lncludes the following:
Cost of Gas:
Distribution Cost:
First 10,000 therms per bill @
Over 10,000 therms per bill @
Block One:
Block Two:
$0s04s1.
$0'63596-
$0.54265
$0.47370
1) Temporary purchased gas cost adjustment
2) Weighted average cost of gas
3) Gas transportation cost
Block One: First 10,000 therms per bill @
Block Two: Over 10,000 therms per bill @
($oo5444)
$&29696
$ga,lans
$0.14395
$0.07500
($0.06277)
$0.26020
$0.20127
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company's Purchased
Gas Cost Adjustment Schedule.
SERVICE CONDITIONS:
1. All natural gas service hereunder is subject to the General Service Provisions of the Company's Tariff,
of which this rate schedule is a part.
BILLING ADJUSTMENTS:
Any GS-1 customer who leaves the GS-1 service will pay to lntermountain Gas Company, upon exiting
the GS-1 service, all gas and transportation related costs incurred to serve the customer during the GS-
1 service period not paid by the customer during the time the customer was uslng GS-1 service. Any
GS-1 customer who leaves the GS-1 service wlll have refunded to them, upon exiting the GS-1 service,
any excess gas commodity or transportation paynents made by the customer during the time they were
a GS-1 customer.
tssued by: lntermountain Gas Company
By: Michael P. McGrath Title: Director * Regulatory Affairs
Effeclive:-fitray{#e1+ October 1, 2017
l.P.U.C. Gas Tariff
Rate Schedules
Fifly-Fifth Revised Sixth Sheet No. 3 (Page 2 of 2)
Name lntermountain Gas Gompanyof Utllity
1.
Exhibit No. 1
Case No. INT-G-17-05
lntermountain Gas Company
PageT ol 11
IDAHO PUBLIC UT]LITIES COMMISSIONApproved EffectiveMaf4q8047 trtraf-4r.aO+7
Pcr-ON,€37&
Dlane M. Hanian Secretary
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 natural gas snowmelt equipment after 6112O10. The intended use of the snowmelt equipment is
to melt snow and/or ice on sidewalks, driveways or any other similar appurtenances. Any and all such
applications meeting the above criteria will be subject to service under Rate Schedule lS-R and will be
separately and individually metered. All service hereunder is interruptible at the sole discretion of the
Company,
FACIUry 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 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 Gompany can reasonably accommodate said relocation and Customer agrees to
pay all related costs.
RATE:
Monthly minimum charge is the Customer Charge.
Customer Charge:
Per Therm Charge:
*lncludes the following:
Cost of Gas:
$5.50 per bill
$&69676. $0.57776
1) Temporary purchased gas cost adlustment
2) Weighted average cost of gas
3) Gas transportation cost
($o€4€6D
$0*8696
$03446{.
($0.05395)
$0.26020
$0.19964
Distribution Cost: $0.17187
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company's Purchased
Gas Cost Adjustment Schedule,
tssued by: lntermountain Gas Company
By: Michael P. McGrath Title: Director - Regulatory Affairs
Effective:
l.P,U.C. Gas Tariff
Rate Schedules
Turolf;lr Revise6 Thirteenth Sheet No. 4 (Paqe 1 of 2)
Name
of Utility lntermountain Gas Company
Exhibit No. 1
Case No. INT-G-17-05
lntermountain Gas Company
Page 8 of 1'l
Rate Schedule lS-C
SMALL COMMERICAL INTERRUPTIBLE SNOWMELT SERVIGE
APPLICABILITY:
Applicable to any customer othemrise eligible to receive gas service under Rate Schedule GS-1 who has
added natural gas snowmelt equipment after 6/1/2010, The intended use of the snourmelt 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 seMce under Rate Schedule lS-C and will be
separately and individually metered. All service hereunder is interruptible at the sole discretion of the
Company.
FACILITY REIMBURSEMENT CHARGE:
All new interruptible Snowmelt service customers are required to pay for the cost of the Snowmelt meter set
and other related facility and equipment costs, prior to the installation of the meter set. Any request to alter
the physical location of the meter set and related facilities from Company's initial design may be granted
provided, however, the Company can reasonably accommodate said relocation and Customer agrees to pay
all related costs.
RATE:
Monthly minimum charge is the Customer Charge.
Customer Charge:
Per Therm Charge:
$9.50 per bill
LP.U.C. Gas Tariff
Rate Schedules
Twelfth Revised Thirteenth SheetNo. 5 (Paqe"l of 2)
Name
of Utility lntermountain Gas Gompany
IDAHO PUBLIC UTILITIES COMMISSIONApproved EffectiveMay-tS-2OtT May*+,-AO+f
For 9:N: 33757
Dlane M, Hanian Secretary
$e€6288" $0.59062
$962847' $0.56621
$+6049+. $0.54265
$s,64596* $0,47370
6e06444
$0*s605
($0.06277)
$0-.21€46
$0.19192
$0,1675'1
$0.14395
$0.07500
Block One:
Block Two:
Block Three:
Block Four:
200 therms
1,800 therms
8,000 therms
10,000 therms
First
Next
Next
Over
perbill@
perbill@
per bill @per bill @
*lncludes the following:
Cost of Gas:
Distribution Charge:
1) Temporary purchased gas cost adJustment
2) Weighted average cost of gas
3) Gas transportation cost
Block One: First 200 therms per bill @
Block Two: Next 1,800 therms per bill @
Block Three: Next 8,000 therms per bill @
Block Four: Over 10,000 therms per bill @
$0.26020
$0.20127
lssued by: lntermountain Gas Company
P McGrath Title; Director - Regulatory Affairs
I
I
I
Exhibit No. 1
Case No. INT-G-I7-05
lntermountain Gas Company
Page9of11
Rate Schedule LV-I
LARGE VOLUME FIRM SALES SERVICE
AVAILAB!LITY:
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
IDAHO PUBLIC UTILITIES COMMISSIONApproved EffectlveMaf+9,"40{Z May-lr-f0{+
PerO'+l'3&75tr
Dlane M. Hanlan Secretary
$0.37821Per Therm Charge:Block One:
Block Two:
Block Three:
250,000 therms per
500,000 therms per
750,000 therms per
$03766+.
$0366?3"
$0,38&14',
First
Next
Over
$0.35893
$0.26986
bil @
biil @
biil @
*lncludes the folloWng;
Cost of Gas: 1) Temporary purchased gas cost adjustment
Block One and Two
Block Three
2) Weighted average cost of gas
3) Gas lransportation cost (Block One and Two only)
Distribution Cost: Block One: First 250,000 therms per bill @
Block Two: Next 500,000 therms per bill @
Block Three: Over 750,000 therms per bill @
$ooaaa31
($o"oo7+a)
$s.28696
$0$7066
$0.03234
$0.01306
$0.00331
($0.01978)
$0.00635
$0.26020
$0.10545
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company's Purchased
Gas Cost Adjustment Schedulo.
SERVICE GONDITIONS:
1. All natural gas service hereunder is subject to the General Service Provisions of the Company's
Tariff, of which this Rate Schedule is a part.
2.The customer shall negotiate with the Company, a mutually agreeable Maximum Daily Firm Quantity
(MDFO) amount, which will be stated in and will be in effect throughout the term of the servlce
contract.
ln the event the Customer requires daily usage in excess of the MDFQ, and subject to the
availability of firm interstate transportation to serve lntermountain's system, all such excess
usage will be billed under rate schedule LV-1, Additionally, all excess MDFQ above the customer's
contracted MDFQ for the month will be billed at the monthly Demand Charge rate.
tssued by: lntermountain Gas Company
By: Michael P. McGrath Title: Director - Regulatory Affairs
Eifective: May-4-20:17' October 1' 2017
l.P.U.C, Gas Tariff
Rate Schedules
Sixty-Third Revised Ecurt-h.Shoet No. 7 (Paqe 1 of 2)
Nanre
of Utility lntermountain Gas Company
l.P.U-C. GasTariff
Rate Schedules
Foedaeath Revised Fifteenth Sheet No. 8 (Paoe 1 of 2)
Name
of Utilitv lntermountain Gas Company
Fkst
Next
Over
Exhibit No. 1
Case No. INT-G-17-05
lntermountain Gas Company
Page 10 of 'l 1
IDAHO PUBLIC UTILITIES COITiMISSIONApproved Effsctivemey++-ae*+ ilay**lr{0+f
Per&l&€EiF67
Diane M. Hanlan 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 wrilten service contact.
MONTHLY RATE:
Per Tharm Charge: Block One:
Block Two:
Block Three:
1OO,00O therms lransported @ $0. 4929" $0'03905
50,000 therms transported @ $&.9{64a' $0.01578
150,000 thorms transported @ $&006g7' $0'00113
I
"lncludes temporary purchased gas cost adjustment of $$€0@ ($0.00061)
ANNUAL MINIMUM BILL:
The customer shall be subject to the payment of an annual minimum bill of $30,000 during each annual
contracl period, unless a higher minimum is required under the service contrac{ to cover special conditions.
PURCHASED GAS COST ADJUSTIIIENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Compan/s Purchased
Gas Cost Adjustment Schedule.
SERVICE CONDITIONS:
The Company, in its sole discretion, shall determine whether or not it has adequate capacity lo
accommodate transportation of the customefs gas supply on the Company's distribution system.
All natural gas service hereunder is subjec* lo the General Service Provisions of the Company's
Tariff, of which this Rate Schedule is a part,
lnterruptible Distribution Transportation Service may be made firm by a written agreement between
the parties if the customer has a dedicated line.
lf requested by the Company, the customer expressly agrees to immediately curtail or interrupt its
operations during periods of capacity constraints on the Company's distribution system.
This service does not include the cost of the custome/s gas supply or the interstate pipeline capacity.
The customer is responsible for procuring its own supply of natural gas and transportation to
lntermountain's distribution system under this rate.
6. The cuslomer understands and agrees that the Gompany is not responsible to deliver gas supplies
to the customer which have not been nominated and accepted for delivery by the intorstate pipeline.
7. An existing T4 customer electing this schedule may conculrently utilize Rate Schedule T-3 on the
same or contiguous ProPertY.
tssued oy: lntermountain Gas Company
P McGrath Title; Direclor - Regulatory Affairs
2.
3.
4.
5.
Exhibit No. 1
Case No. INT-G-17-05
lntermountain Gas Company
Page 1'l of 1'l
IDAHO PUBLIC UTILITIES COMMISSIONApproved EffectiveMay4ffiO+r Maf 4rr0l"-
PerO,!{.CE767
Diane M. Hanlan Secretary
Rate Schedule T-4
FIRM DISTRIBUTION ONLY TRANSPORTATION SERVICE
AVAILABILlTY:
Available at any mutually agreeable delivery point on the Company's distribution system to any customer
upon execution of a one year minirnum written service contract for firm distribution transportation service in
excess of 200,000 therms p€r year.
MONTHLY RATE:
Demand Charge:$0.?7886 per MDFQ therm* $1]1]81g
Per Therm Charge:Block One:
Block Two:
Block Three:
First
Next
Over
250,000 therms transported @ $0.02638
500,000 therms transported @ $0,00932
750,000 therms transported @ $0.00286
*lncludes temporary purchased gas cost adjustment of fiSO2+16) ($0.01848)
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in lhe Company's Purchased
Gas Cost Adjustment Schedule.
SERVICE GONDITIONS:
1. This service excludes the service and cost of lirm interstate pipeline charges.
2. The customer is responsible for procuring its own supply of natural gas and interstate transportation
under this Rate Schedule. The customer understands and agrees that the Company is not
responsible to deliver gas supplies to the customer which have not been nominated, scheduled, and
delivered by the interstate pipeline to the designated city gate.
3. All natural gas service hereunder is subject to the General Service Provisions of the Company's
Tariff, of which this Rate Schedule is a part.
4. The customer shall 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.
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.
6. An existing LV-1 or T-3 customer electing this schedule may concurrently utilize Rate Schedule T-4
on the custome/s same or contiguous property.
LP.U.C. Gas Tariff
Rate Schedules
Slri*eonth Revised Fou&enth Sheet No. I (Paoe 1 of 2)
Name
of Utllity lntermountain Gas Company
lssued by: lntermountain Gas Company
By: Michael P. McGrath Title: Director - Regulatory Affairs
Eifective: May tO17 October 1, 2017
t
i
I
I
I
I
I
!
EXHIBIT NO.2
CASE NO. INT.G.17-05
INTERMOT]NTAIN GAS COMPANY
PROPOSED TARIFFS
(9 pages)
l.P.U.C. Gas Tariff
lndex
Second Revised Sheet No. C
Name
of Utility Intermountain Gas Gompany
SCHEDULE
NO.
RS
GS-1
IS-R
ts-c
LV-1
T-3
T-4
H-1
PGA
ER
FT
INDEX
RATE SCHEDULES
Residential Service
General Service........
Residential lnterruptible Snowmelt Service..................
Small Commercial lnterruptible Snowmelt Service...
Large Volume Firm Sales Service ............................
lnterruptible Distribution Transportation Service......
Firm Distribution Only Transportation Service .........
Ketchum/Sun Valley Area Hook-up Fee ..................
Purchased Gas Cost Adjustment
Residential Space Heating Equipment Rebate..........
Franchise Fee/ Tax Adjustment..........
Exhibit No. 2
Case No. INT-G-I7-05
lntermountain Gas Company
Page 1 of9
SHEET
...,,,,..1
.........3
.,.....,' 4
.........5
.........7
.........8
.........9
.........12
13
14
15
rssued by: lntermountain Gas CompanyBy: Michael P. McGrath Title: Director- RegulatoryAffairs
Effective: October 1, 2017
TITLE
l.P.U.C. Gas Tariff
Rate Schedules
Second Revised Sheet No. 1 (Page 1 of 1)
Name
of Utility lntermountain Gas Company
Exhibit No. 2
Case No. INT-G-17-05
lntermountain Gas Company
Page 2 of 9
Rate Schedule RS
RESIDENTIAL SERVICE
APPLICABILITY:
Applicable to any customer using natural gas for residential purposes.
RATE:
Monthly minimum charge is the Customer Charge.
Customer Charge:
Per Therm Charge:
$5.50 per bill
$0.57776.
*l ncludes the following:
Cost of Gas:1) Temporary purchased gas cost adjustment
2) Weighted average cost of gas
3) Gas transportation cost
($o.os3es)
$0.26020
$0.1 9964
Distribution Cost:$0.17187
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company's Purchased
Gas Cost Adjustment Schedule.
SERVICE GONDITIONS:
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 CompanyBy: Michael P. McGrath Title: Director - Regulatory Affairs
Effective: October 1, 2017
l.P.U.C. Gas Tariff
Rate Schedules
Fifty-Sixth Revised Sheet No.3 (Page 1 of 2)
Name
of Utility lntermountain Gas Company
Exhibit No. 2
Case No. INT-G-17-05
lntermountain Gas Company
Page 3 of 9
Rate Schedule GS-1
GENERAL SERVICE
APPLICABILITY:
Applicable to customers whose requirements for natural gas do not exceed 2,000 therms per day, at any point
on the Company's distribution system. Requirements in excess of 2,000 therms per day may be served under
this rate schedule upon execution of a one-year written service contract.
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:
1) Temporary purchased gas cost adjustment
2) Weighted average cost of gas
3) Gas transportation cost
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 bill @
First
Next
Next
Over
First
Next
Next
Over
$0.59062.
$0.56621.
$0.54265.
$0.47370"
($0.06277)
$0.26020
$0.20'127
$0.1 91 92
$0.1 6751
$0.1 4395
$0.07500
tssued oy: lntermountain Gas Company
By: Michael P. McGrath Title: Director - Regulatory Affairs
Effective: October 1, 2017
l.P.U.C. Gas Tariff
Rate Schedules
Fifty-Sixth Revised Sheet No.3 (Page 2of 2)
Name
of Utility lntermountain Gas Company
Exhibit No. 2
Case No. INT-G-17-05
lntermountain Gas Company
Page 4 of 9
Rate Schedule GS-l
GENERAL SERVICE
(Continued)
For separately metered deliveries of gas utilized solely as Compressed Natural Gas Fuel in vehicular internal
combustion engines.
Customer Charge: $9.50 per bill
Per Therm Charge:Block One:
Block Two:
First 10,000 therms per bill @
Over 10,000 therms per bill @
$0.54265.
$0.47370.
($0.06277)
$0.26020
$0.20127
$0.14395
$0.07500
*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@
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company's Purchased
Gas Cost Adjustment Schedule.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the Company's Tariff,
of which this rate schedule is a part.
Any GS-1 customerwho leaves the GS-1 service will pay to lntermountain Gas Company, upon exiting
the GS-1 seryice, allgas and transportation related costs incurred to serve the customer during the GS-
1 service period not paid by the customer during the time the customer was using GS-1 service. Any
GS-1 customerwho leaves the GS-1 service will have refunded to them, upon exiting the GS-1 service,
any excess gas commodity or transportation payments made by the customer during the time they were
a GS-1 customer.
tssued uy: lntermountain Gas Company
By: Michael P. McGrath Title: Director - Regulatory Affairs
Effective: October 1, 2017
BILLING ADJUSTMENTS:
1.
l.P.U.C. Gas Tariff
Rate Schedules
Thirteenth Revised Sheet No. 4 (Pase 1 ot2l
Name
of Utilitv lntermountain Gas Company
Exhibit No. 2
Case No. INT-G-17-05
lntermountain Gas Company
Page 5 of 9
Rate Schedule lS-R
RESIDENTIAL INTERRUPTIBLE SNOWMELT SERVICE
APPLICAB!LITY:
Applicable to any residential customer otherwise eligible to receive service under Rate Schedule RS who
has added natural gas snowmelt equipment after 61112010. The intended use of the snowmelt equipment is
to melt snow and/or ice on sidewalks, driveways or any other similar appurtenances. Any and all such
applications meeting the above criteria will be subject to service under Rate Schedule lS-R and will be
separately and individually metered. All service hereunder is interruptible at the sole discretion of the
Company.
FACILITY REIM BURSEM ENT GHARGE:
All new interruptible Snowmelt service customers are required to pay for the cost of the Snowmelt meter set
and other related facility and equipment costs, prior to the installation of the meter 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:
*l ncludes the following
Cost of Gas:
$5.50 per bill
$0.57776*
1) Temporary purchased gas cost adjustment
2) Weighted average cost of gas
3) Gas transportation cost
($0.053e5)
$0.26020
$0.19964
Distribution Cost:$0.17187
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company's Purchased
Gas Cost Adjustment Schedule.
tssued uy: lntermountain Gas Company
By: Michael P. McGrath Title: Director - Regulatory Affairs
Effective: October 1, 2017
l.P.U.C. Gas Tariff
Rate Schedules
Thirteenth Revised Sheet No. 5 (Paqe 1 of2)
Name
of Utilitv lntermountain Gas Company
Exhibit No. 2
Case No. INT-G-17-05
lntermountain Gas Company
Page 6 of 9
Rate Schedule IS-C
SMALL COMMERICAL INTERRUPTIBLE SNOWMELT SERVICE
APPLICABILITY:
Applicable to any customer otherwise eligible to receive gas service under Rate Schedule GS-1 who has
added natural gas snowmelt equipment after 61112010. The intended use of the snowmelt equipment is to
melt snow and/or ice on sidewalks, driveways or any other similar appurtenances. Any and all such
applications meeting the above criteria will be subject to service under Rate Schedule lS-C and will be
separately and individually metered. All service hereunder is interruptible at the sole discretion of the
Company.
FAGILIW 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
allrelated costs.
RATE:
Monthly minimum charge is the Customer Charge.
Customer Charge:
Per Therm Charge:
$9.50 per bill
Block One:
Block Two:
Block Three:
Block Four:
First
Next
Next
Over
200 therms per bill@
1,800 therms per bill @
8,000 therms per bill@
10,000 therms per bill @
$0.59062.
$0.56621.
$0.54265.
$0.47370.
*lncludes the following:
Cost of Gas:1) Temporary purchased gas cost adjustment
2) Weighted average cost of gas
3) Gas transportation cost
($0.06277)
$0.26020
$0.20127
Distribution Charge Block One:
Block Two:
Block Three:
Block Four:
First
Next
Next
Over
200 therms per bill@
1,800 therms per bill @
8,000 therms per bill@
10,000 therms per bill @
$0.19192
$0.16751
$0.14395
$0.07500
tssued oy: lntermountain Gas Company
By: Michael P. McGrath Title: Director - Regulatory Affairs
Effective: October 1, 2017
LP.U.C. Gas Tariff
Rate Schedules
Sixty-Fourth Revised Sheet No. 7 (Page 1 ol2)
Name
of Utility lntermountain Gas Company
Rate Schedule LV-l
LARGE VOLUME FIRM SALES SERVIGE
AVAILABILITY:
Available at any mutually agreeable delivery point on the Company's distribution system to any existing
customer receiving service under the Company's rate schedule LV-1 or any customer not previously served
under this schedule whose usage does not exceed 500,000 therms annually, upon execution of a one-year
minimum wriften service contract for firm sales service in excess of 200,000 therms 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 @
Exhibit No. 2
Case No. INT-G-17-05
lntermountain Gas Company
Page 7 of 9
$0.37821.
$0.35893.
$0.26986"
Per Therm Charge:
*lncludes the following
Cost of Gas:
Distribution Cost:
Block One:
Block Two:
Block Three:
Block One:
Block Two:
Block Three:
First
Next
Over
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)
($0.01e78)
$0.00635
$0.26020
$0.10545
$0.03234
$0.01306
$0.00331
First
Next
Over
250,000 therms per bill@
500,000 therms per bill@
750,000 therms per bill@
1
2
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company's Purchased
Gas Cost Adjustment Schedule.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the Company's
Tariff, of which this Rate Schedule is a part.
The customer shall negotiate with the Company, a mutually agreeable Maximum Daily Firm Quantity
(MDFO) amount, which will be stated in and will be in effect throughout the term of the service
contract.
ln the event the Customer requires daily usage in excess of the MDFQ, and subject to the
availability of firm interstate transportation to serve lntermountain's system, all such excess
usage will be billed under rate schedule LV-1. Additionally, all excess MDFQ above the customer's
contracted MDFQ for the month will be billed at the monthly Demand Charge rate.
tssued oy: lntermountain Gas Company
By: Michael P. McGrath Title: Director - Regulatory Affairs
Effective: October 1, 2017
l.P.U.C. Gas Tariff
Rate Schedules
Fifteenth Revised Sheet No.8 (Pase 1 of 2\
Name
of Utilitv lntermountain Gas Company
Exhibit No. 2
Case No. INT-G-17-05
lntermountain Gas Company
Page 8 of 9
Rate Schedule T-3
I NTERRUPTI BLE DISTRI BUTION 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 100,000 therms transported @ $0.03965.
Block Two: Next 50,000 therms transported @ $0.01578-
Block Three: Over 150,000 therms transported @ $0.00543.
*lncludes temporary purchased gas cost adjustment of ($0.00061)
ANNUAL MINIMUM BILL:
The customer shall be subject to the payment of an annual minimum bill of $30,000 during each annual
contract period, unless a higher minimum is required under the service contract to cover special conditions.
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company's Purchased
Gas Cost Adjustment Schedule.
SERVICE CONDITIONS:
The Company, in its sole discretion, shall determine whether or not it has adequate capacity to
accommodate transportation of the customer's gas supply on the Company's distribution system.
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.
lnterruptible Distribution Transportation Service may be made firm by a written agreement between
the parties if the customer has a dedicated line.
lf requested by the Company, the customer expressly agrees to immediately curtail or interrupt its
operations during periods of capacity constraints on the Company's distribution system.
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.
The customer understands and agrees that the Company is not responsible to deliver gas supplies
to the customer which have not been nominated and accepted for delivery by the interstate pipeline.
An existing T4 customer electing this schedule may concurrently utilize Rate Schedule T-3 on the
same or contiguous property.
lssued oy: lntermountain Gas Gompany
By: Michael P. McGrath Title: Director - Regulatory Affairs
Effective: October 1, 2017
1
2.
3.
4.
5.
6.
7.
l.P.U.C. Gas Tariff
Rate Schedules
Fourteenth Revised Sheet No. 9 (Pase 1 of 2\
Name
of Utility lntermountain Gas Gompany
Exhibit No. 2
Case No. INT-G-17-05
lntermountain Gas Company
Page 9 of 9
Rate Schedule T-4
FIRM DISTRIBUTION ONLY TRANSPORTATION SERVICE
AVAILABILITY:
Available at any mutually agreeable delivery point on the Company's distribution system to any customer
upon execution of a one year minimum written service contract for firm distribution transportation service in
excess of 200,000 therms per year.
MONTHLY RATE
Demand Charge:$0.28152 per MDFQ therm*
Per Therm Charge:
*lncludes temporary purchased gas cost adjustment of $(0.018a8)
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company's Purchased
Gas Cost Adjustment Schedule.
SERVICE CONDITIONS:
1. This service excludes the service and cost of firm interstate pipeline charges.
2 The customer is responsible for procuring its own supply of natural gas and interstate transportation
under this Rate Schedule. The customer understands and agrees that the Company is not
responsible to deliver gas supplies to the customer which have not been nominated, scheduled, and
delivered by the interstate pipeline to the designated city gate.
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
(MDFQ), 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 T-4 customers when circumstances impacted by force majeure
events prevent the Company from delivering natural gas to the customer's meter.
An existing LV-1 or T-3 customer electing this schedule may concurrently utilize Rate Schedule T-4
on the customer's same or contiguous property.
lssued by: lntermountain Gas Company
By: Michael P. McGrath Title: Director - Regulatory Affairs
Effective: October 1, 2017
Block One:
Block Two:
Block Three:
First
Next
Over
250,000 therms transported @ $0.02638
500,000 therms transported @ $0.00932
750,000 therms transported @ $0.00286
3
4
5
6.
EXHIBIT NO.3
CASE NO. INT.G-17-05
INTERMOUNTAIN GAS COMPAI{Y
PERTINENT EXCERPTS PERTAII\IING TO INTERSTATE PIPELII\ES AND RELATED
FACILITIES
(41pages)
Exhibit No. 3
Case No. INT-G-17-05
lntermountain Gas Company
Page 'l of 41
NORTHWEST PIPELINE LLC
10 I t t2017 -12 l3l I 201 7 RATE S
(9 pages)
201,61,220-3003 FERC PDF (unofficial) 72/20/20L6
FEDERAL ENERGY REGULATORY COMMISSION
WASHINGTON, D.C. 20426
OFFICE OF ENERGY MARKET REGULATION
In Reply Refer To:
Letter Order Pursuant to $ 375.307
Northwest Pipeline LLC
Docket No. RPl 7-2 I 3-000
December 20,2016
Northwest Pipeline LLC
P.O. Box 58900
Salt Lake City, UT 84158-0900
Attention: LarenGertsch,Director
Rates and Tariffs
Reference: TariffRevisions
Dear Mr. Gertsh:
On November 29,20l6,Northwest Pipeline LLC filed revised tariff recordsl to its
FERC Gas Tariff to change its daily reservation and demand rates, which are currently
based on a 366-day year to reflect the leap year, to those based on a 365-day year. The
referenced tariffrecords are accepted, effective January 1,2017, as proposed.
Public notice of the filing was issued on November 30, 20l6.Interventions and
protests were due as provided in section 154.210 of the Commission's regulations (18
C.F.R. $ 154.210 (2016)). Pursuant to Rule 214 (18 C.F.R. $ 385.214 (2016)), all timely
filed motions to intervene and any unopposed motion to intervene out-of-time filed
before the issuance date of this 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 or service contained in your tariff, nor
shall such acceptance be deemed as recognition of any claimed contractual right or
Exhibit No. 3
Case No. INT-G-17-05
lntermountain Gas Company
Page 2 ot 41
I See Appendix.
201-51220-3003 FERC pDF (Unofficial) 72/20/201,6
Docket No. RPI 7-2 1 3-000
obligation associated therewith; and such acceptance is without prejudice to any findings
or orders which have been or may hereafter be made by the Commission in any
proceeding now pending or hereafter instituted by or against your company.
This order constitutes final agency action. Requests for rehearing by the
Commission may be filed within 30 days of the date this order issues, pursuant to 18
c.F.R. $ 38s.713 (2016).
Sincerely,
Jerry Pederson, Director
Division of Pipeline Regulation
Exhibit No. 3
Case No. INT-G-17-05
lntermountain Gas Company
Paoe 3 of 41' -2-
20L6L220-3003 FERC PDF (Unofficial) 1,2/20/201,6
Docket No. RPI 7-2 I 3-000
Northwest Pipeline LLC
FERC NGA Gas Tariff
Fifth Revised Volume No. 1
Tariff Records Accepted January I , 2017
Sheet 0
Sheet No. 5-C" Statement of Rates: TF'-1" TF-2. TI-1. TFL-I and 'IIL-I. 5.0.0
Sheet No. 7. Statement of Rates: SGS-2F and SGS-2I. 7.0.0
Sheet No. 8-A. Statement of Rates: LS-2F and LS-2I. 7.0.0
Sheet No. 9. Statement of Rates: LS-2F and LS-2I. 5.0.0
Exhibit No. 3
Case No. INT-G-17-05
lntermountain Gas Company
Page 4 ol 41 ^-J-
Appendix
1
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. I
Exhibit No.3
Case No. INT-G-17-05
lntermountain Gas Company
Page 5 of 41
Seventh Revised Sheet No. 5
Superseding
Sixth Revised Sheet No. 5
STATEMENT OF RATES
Effective Rates Applicable to
Rate Schedules TF-1 | TF-2, TI-1, TFL-1 and TIL-1
(Do1lars per Dth)
Rate Schedu]e and
Type of Rate
Rate Schedu.l-e TE-1 (4 ) (5 )Reservation
(Large Customer)
System-Wide
15 Year Evergreen Exp
25 Year Evergreen Exp
Volumetric (2)
(Large Customer)
System-Wj-de
15 Year Evergreen Exp.
25 Year Evergreen Exp.
(SmalI Customer) (6)
Schedul-ed Overrun (2)
Rate Schedufe TE-2 (4) (5)
Reservation
Volumetric
Scheduled Daily Overrun
Annua1 Overrun
Rate Schedule TI-1 (2)
Volumetric (7)
Rate Schedufe TFL-1 (4) (5)
Reservation
Volumetric (2)
Scheduled Overrun (2)
Rate Schedule TIL-1 (2)
Vol-umetric
Base
Tariff Rate(1), (3)
Minimum Maximum
00000
00000
00000
.41000
.36263
.34234
.0081-3
.00813
.00813
.03000
.00813
.00813
.00813 .'72155
00813 .44000
.00000
.00813
.00813
.00813
.41000
.03000
.44000
.44000
.00813 .44000
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. 1
Exhibit No. 3
Case No. INT-G-17-05
lntermountain Gas Company
Page 6 of41
Seventh Revised Sheet No. 7
Superseding
Sixth Revised Sheet No. 7
STATEMENT OF RATES (Continued)
Effective Rates Applicable to Rate Schedules SGS-2F and SGS-2I
(Dollars per Dth)
Rate Schedufe and
Type of Rate
Rate Schedule SGS-2F (2) (3) (4) (5)
Demand Charge
Pre-Expanslon Shipper
Expansion Shipper
Capacity Demand Charge
Pre-Expansion Shipper
Expansion Shipper
Volumetric Bid Rates
Withdrawal Charge
Pre-Expansion Shipper
Expansion Shipper
Storage Charge
Pre-Expansion Shipper
Expansion Shipper
Base
Tariff Rate (1)
Minimum Maximum
0.00000
0. 00000
0. 00000
0.00000
0.00000
0.00000
0. 00000
0.00000
0 .01_562
0. 04056
0.00057
0.00348
0.01s62
0.04056
0. 00057
0.00348
Rate Schedul-e SGS-21
Volumetrlc 0.00000 0.00224
Footnotes
(1) Shj-ppers receiving service under these rate schedules are required to
furnish fuel reimbursement in-kind at the rates specified on Sheet
No. 1,4 .
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. 1
Exhibit No. 3
Case No. INT-G-17-05
lntermountain Gas Company
PageT ot 41
Seventh Revised Sheet No.8-A
Superseding
Sixth Revised Sheet No.8-A
STATEMENT OF RATES (Continued)
Effective Rates Applicable to Rate Schedules LS-2F and LS-2I
(Dol1ars per Dth)
Rate Schedule and
Type of Rate
Base
Tariff Rate (1)
Mi-ni-mum Maximum
Rate Schedule LS-2F (3)
Demand Charge (2)0.00000
0.00000
0.02587
0. 00331Capacity Demand Charge (2)
Volumetric Bi-d Rates
Vaporlzation Demand-Related Charge (2)
Storage Capaclty Charge (2)
0.00000
0.00000
0.02s87
0.00331
Liquefaction
Vaporj- zation
0. 908ss
0.03386
0.90855
0.03386
Rate Schedule LS-2I
Volumetri-c 0.00000 0.00662
Llquefaction
Vaporization
0.90855
0.03386
0. 90855
0.03385
Eootnotes
(1) Shippers recelving service under these rate schedul-es are required to
furnish fuel reimbursement in-kind at the rates specified on Sheet No.
1A
(2t Rates are daily rates computed on the basis of 365 days per year,
except that rates for leap years are computed on the basis of 366 days.
(3)Rates are also applicable to capacity release service except for short-
term capacity release transactions for a term of one year or l-ess that
take effect on or before one year from the date on which Transporter is
notified of the reJ-ease, which are not subject to the stated Maximum
Base Tariff Rate. (Section 22 of the General Terms and Conditions
descri-bes how bids for capacity release will be evaluated. ) TheVaporization Demand-Rel-ated Charge and Storage Capacity Charge are
appli-cab1e to Replacement Shippers bidding for capacity released on a
one-part volumetric bid basis.
20L70321--3056 FERC pDF (Unofficial) 03/21,/201,7
FEDERAL ENERGY REGIILATORY COMMISSION
WASHINGTON, D.C. 20426
OFFICE OF ENERGY MARKET REGULATION
In Reply Refer To:
Letter Order Pursuant to $ 375.307
Northwest Pipeline LLC
Docket No. RP1 7-445-000
Issued: March 2l,20ll
Northwest Pipeline LLC
P.O. Box 58900
Salt Lake city, UT 84158-0900
Attention:Laren Gertsch, Director
Rates and Tariffs
Reference: 2017 Summer Fuel Filing
Dear Ms. Gertsch:
On February 28,2Ol7,Northwest Pipeline LLC (Northwest) filed a tariff recordr
to comply with Sections I 4. 12 and 14.20 of the General Terms and Conditions in its
tariff. These Sections require a) the fuel reimbursement factors for the transportation rate
schedules to be determined semi-annually to become effective on April I and October I
each year and b) the fuel reimbursement factors for storage rate schedules to be
determined annually to become effective April I of each year. Northwest proposes that
the referenced tariff record become effective on April 1,2017. We accept the referenced
tariff record, effective April 1,2017, as proposed.
Northwest proposes the following adjustments to its fuel reimbursement factors:
a) an increase from I .19 percent to I .28 percent in the factor for Northwest's
transportation services under Rate Schedules TF-1, TF-2, TI-1, and DEX-1; b) a decrease
from 0.23 percent to 0.15 percent in the factor for Northwest's underground storage
services under Rate Schedules SGS-2F and SGS-2I; c) a decrease from 0.71 percent to
0.53 percent for Northwest's liquefaction factor for liquefied natural gas (LNG) storage
services under Rate Schedules LS-1, LS-2F, LS-3F, LS-2I, and LD-4I; and d) an increase
l Northwest Pipeline LLC;FERC NGA Gas Tariff; Fifth Revised Volume No. 1,
Sheet No. 14. Fuel Use Factors. 19.0.0.
Exhibit No. 3
Case No. INT-G-17-05
lntermountain Gas Company
Page 8 of 41
201,7032r-30s6 FERC pDF (Unofflcial) 03/21,/2017
Docket No. RP 1 7-445-000
from 0.34 percent to 0.53 percent for Northwest's vaporization factor for LNG storage
services under Rate Schedules LS- l, LS-2F, LS-3F and LS-2I. As part of its annual
Summer Fuel Filing, Northwest must true-up the Liquefaction Facility Charge for Rate
Schedules LS-3F and LD-4I. Northwest proposes no change for 2017 to the estimated
LS-3F and LD-4I liquefaction charges.
Public notice of the filing was issued on March 2,2017. Interventions and protests
were due as provided in section 154.210 of the Commission's regulations (18 C.F.R.
$ 154.210 (2016)). Pursuant to Rule 214 (18 C.F.R. $ 385.214 (2016)), all timely filed
motions to intervene and any unopposed motion to intervene out-of-time filed before the
issuance date of this 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
such acceptance be deemed as recognition of any claimed contractual right or obligation
associated therewith; and such acceptance is without prejudice to any findings or orders
which have been or may hereafter be made by the Commission in any proceeding now
pending or hereafter instituted by or against your company.
This order constitutes final agency action. Requests for rehearing by the
Commission may be filed within 30 days of the date this order issues, pursuant to
18 C.F.R. $ 38s.713 (2016).
Sincerely,
Monique Watson, Acting Director
Division of Pipeline Regulation
Exhibit No. 3
Case No. INT-G-17-05
lntermountain Gas Company
Paoe 9 of 41-.|
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. I
Exhibit No.3
Case No. INT-G-17-05
lntermountain Gas Company
Page 10 of41
Nineteenth Revised Sheet No. 14
Superseding
Eighteenth Revised Sheet No. 14
STATEMENT OE FUEL USE REQUIREMENTS FACTORS
FOR REIMBURSEMENT OE FUEL USE
Applicable to Transportation Service Rendered Under
Rate Schedules Contained in this Tariff, Fifth Revj-sed Volume No. 1
The rates set forth on Sheet Nos. 5, 6,'7, 8 and 8-A are exclusive of
fuel use requJ-rements. Shipper shall reimburse Transporter in-kind for its
fuel use requirements j-n accordance with Section 14 of the General Terms and
Conditions contained herein.
The fuel- use reimbursement furnished by Shippers shall- be as follows
for the applicable Rate Schedules included in this Tariff:
Rate Schedules TF-1, TF-2, TI-1-, and DEX-1
Rate Schedule TF-1 - Evergreen Expansion
Incremental Surcharge (1)
Rate Schedul-e TEL-l-
Rate Schedule TIL-1
Rate Schedufes SGS-2F and SGS-21
Rate Schedules LS-2F, LS-3E and LS-2I
Liquefactlon
Vapori-zation
Rate Schedule LD-4I
Lj-quefaction
1.28e"
0.509
0.158
0.538
0.53U
0.539
The fuel use factors set forth above sha1l be calcul-ated and adjusted
as explained in Section 14 of the General- Terms and Conditlons. EueI
rei-mbursement 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 Prairle injection, Plymouth liquefaction, Plymouth vaporization, or
for deferred exchange, as appJ-icable.
Footnote
(1) In addition to the Rate Schedule TF-1 fuel use requirements factor, the
Evergreen Expansion Incremental Surcharge wil-1 apply to the quantity of gas
nominated for recej-pt at the Sumas, SIPI or Pacific Pool- receipt points under
Evergreen Expansion service agreements.
Exhibit No. 3
Case No. INT-G-17-05
lntermountain Gas Company
Page 11 of 41
NORTHWEST PIPELINE LLC
I I t 12018-9 I 30 t2018 RATE S
(8 pages)
20170412-3021- FERC PDF (Unofficial-) 04/72/201,'1
FEDERAL ENERGY REGULATORY COMMISSION
WASHINGTON, D.C. 20426
OFFICE OF ENERGY MARKET REGULATION
In Reply Refer To:
Letter Order Pursuant to $ 375.307
Northwest Pipeline LLC
Docket No. RP 1 7-567-000
Issued:April 12,2017
Northwest Pipeline LLC
P.O. Box 58900
Salt Lake City, Utah 84158-0900
Attention:Laren Gertsch, Director
Rates & Tariffs
Reference: Extension of Time Tariff Provision
Dear Mr. Gertsch:
On March 29,2017, Northwest Pipeline LLC (Northwest) filed revised tariff
recordsl to its FERC Gas Tariff. Northwest states that the revised tariff records extend
the time for Northwest to file an NGA section 4 general rate case and make other changes
to preserve and implement rate reductions agreed to by Northwest and its shippers. The
referenced tariff records are accepted, effective May 1, 2017 , as proposed.
Public notice of the filing was issued on March 30,2017. Interventions and
protests were due as provided in section 154.210 of the Commission's regulations (18
C.F.R. $ 154.210 (2016)). Pursuant to Rule 214 (18 C.F.R. $ 385.214 (201,6)), all timely
filed motions to intervene and any unopposed motion to intervene out-of-time filed
before the issuance date of this order are granted. Granting late intervention at this stage
rNorthwest Pipeline LLC,FERC NGA Gas Tariff, Fifth Revised Volume No. l,
Sheet No. 200. GT&C - Index. 7.0.0, Sheet No. 281. Extension of ll'ime Provisions.4.0.0,
and Sheet No. 282. Extension of Time Provisions" 4.0.0.
Exhibit No. 3
Case No. INT-G-17-05
lntermountain Gas Company
Page 12 of 41
20L704L2-3021 FERC pDF (Unofficial) 04/1,2/201,7
Docket No. RP17-5 67 -000
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
such acceptance be deemed as recognition of any claimed contractual right or obligation
associated therewith; and such acceptance is without prejudice to any findings or orders
which have been or may hereafter be made by the Commission in any proceeding now
pending or hereafter instituted by or against your company.
This order constitutes final agency action. Requests for rehearing by the
Commission may be filed within 30 days of the date of issuance of this order, pursuant to
l8 c.F.R. $ 385.713 (20t6).
Sincerely,
Monique Watson, Acting Director
Division of Pipeline Regulation
Exhibit No. 3
Case No. INT-G-'17-05
lntermountain Gas Company
Paoe l3 of41' -2-
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. I
Exhibit No. 3
Case No. INT-G-17-05
lntermountain Gas Company
Page 14 of 41
Fourth Revised Sheet No.281
Superseding
Third Revised Sheet No. 281
GENERAL TERMS AND CONDITIONS (Continued)
21. EXTENS]ON OF T]ME PROVISIONS
This tariff provlsion amends: (1) the March 75,20L2 settfement in
Docket No. RP12-490-000, approved, Northwest Pipeline GP, 139 F.E.R.C.
S 61,071 (2012) (*2012 Settlement"); and (2) the January 23, 20L1
settl-ement pending Commission approval pursuant to the "Petition of
Northwest Pipelj-ne LLC for Approval of Settl-emeoL," in Docket Nos.
RP17-346-000 et af. ("2011 Settlement"), j-n order to accommodate the
delay in Commission action on the 2017 Settl-ement due to a lack of a
quorum. Except as amended by this tariff record, Lhe 2072 Settlement
and 2017 Settfement remain unchanged, except that the 2017 Settlement
as fil-ed in Docket Nos. RP17-346-000 et al. will be conformed to
reflect the amendments in this tariff record.
(a) Amendment Lo 2072 Settl-ement
The date by which Transporter must fil-e an NGA section 4 general rate
case pursuant to section 14.4 of Lhe 2012 settlement is extended to
one-hundred and twenty (120) days after a final Commission order
addressing Lhe 2017 Settlement. The requirement to file an NGA section
4 general rate case wj-Il be satisfied upon a final Commission order
approving the 2017 Settfement.
(b) Amendments to 20L7 Settlement
The 2017 Settlement is amended as follows:
1. Pursuant to Article X, the date by which Northwest must
fil-e an NGA sectlon 4 generaf rate case as to any Contesting
Party excluded from the Settl-ement pursuant to Article X is
extended to one-hundred and twenty (120) days after a final
Commission order addressing the 2017 Settl-ement.
2. Section l-4.1- of the 2017 Settlement sha11 be deleted i-n i-ts
entirety and replaced with the following:
If the Settlement approval process is not completed before
November 28, 207'7, then Northwest will file with the Commission
by no later than December L, 201-7, tariff records placing the
Phase 1 Rates lnto effect January I, 2078, and another filing by
no l-ater than August 31, 2018, placj-ng the Phase 2 Rates into
effect October 1, 201-8, 1n accordance with Articles IfI and VIII
of this Settlement. Such filing(s) sha1l constitute ful-l
satisfaction of the 2017 Rate Fil-ing Requj-rement.1
1 Completion of the Settfement approval process means a Ej-na1 Order by the
Commisslon from which: (a) Northwest has no remainlng right to withdraw
pursuant to Sections 11.3 or 11.5 (if applicable) and (b) no other Settling
Party has a remaj-ning right to cease its particj-pation pursuant to Section
1-7.4 (if applicable).
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. 1
Exhibit No. 3
Case No. INT-G-17-05
lntermountain Gas Company
Page 15 of 4'l
Fourth Revised Sheet No. 282
Superseding
Third Revised Sheet No. 282
GENERAL TERMS AND CONDITIONS (Continued)
2'7. EXTENSION OF TIME PROVISIONS (Continued)
3. Section L4.2 of Lhe 207'7 Settfement shal-I be del-eted in i-ts
entirety and replaced with the following:
If the Settlement approval- process is completed by January 1,
20L8, then no refund or surcharge wiJ-l be due any Settling Party.
If the Settlement approval process is completed after January 1,
2018, or if tariff records implementing the Settlement Rates are
not made effective January 1, 2078, then Northwest wifl continue
charging its currently effective rates pursuant to the 2012
Settlement until the effectiveness of the new rates pursuant to
the Commission's Final Order addresslng the Settlement. ViTithin
sixty (60) days following such Final Order, Northwest will
provide refunds, with interest at the Commission approved rate,
to place the Settling Parties in the same position as if the
Settlement approval process had been completed by January 1,
201_8.
Exhibit No. 3
Case No. INT-G-17-05
lntermountain Gas Company
Paoe 16 of41Appen?ix B
NORTHWEST PIPELINE LLC
DocketNo. RP17-
Summary of Daily Settlement Rates 1I
Exclusive of Surcharges
Effective January 1, 2018
Line Rate Schedule
1 TF-,I
2 Resenation Charge - Large Customer
3 -Ewrgreen-15-year
4 - E\ergreen -25-year
Volumetric Charge - Large Customer
- Erergreen - 1s-year
- E\ergreen - 2s-yeat
- Small Customer
TF-2
Resenation Charge
Volumetric Charge
Tl-1
Maximum Volumetric Charge 2/
Minimum Volumetric Charge
SGS-2F Pre-Expanslon
Demand Charge
Capacity Demand Charge
SGS-2F Expansion
Demand Charge
Capacity Demand Charge
SGS.2I
Volumetric Cha€e
SGS-2F Volumetric Bid Rates Pr+Expansion
Withdrawal Charge
Storage Charge
SGS-2F Volumetric Bid Rates Expansion
Withdrawal Charge
Storage Charge
LS.2F
Demand Charge
Capacity Demand Charge
Liquefaction Charge
Vaporization Charge
LS-2t 3/
Maximum Volumetric Charge
Minimum Volumetric Charge
LS-2F Volumetric Bid 3/
Vaporization Demand Related Charge
Storage Capacity Charge
DEX.1
Maximum Volumetric Charge
Minimum Volumetric Charge
PAL
Maximum Volumetric Charge
Minimum Volumetric Charge
2018
20't9
2020
2021
2022
2023
2024
2025
$0.09855
$0.09189
$0.08667
$0.081 94
$0.07696
$0.071 99
$0.06680
$0.06552
(b)(a)
Rate
$0.39294
$0.3s077
$0.32093
$0.00832
$0.00832
$0.00832
$0.69427
$0.39294
$0.00832
$0.401 26
$0.00832
$0.01562
$0.00057
$0.04056
$0.00348
$0.00224
$0.01 562
$0.00057
$0.04056
$0.00348
$0.02587
$0.00331
$0.90855
$0.03386
$0.00662
$0.00000
$0.02587
$0.00s31
$0.40126
$0.00000
$0.40126
$0.00000
5
6
7II
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33u
35
36
37
38
39
40
41
42
43
44
45
46 Facilities Resenation Surcharge for the Columbia Gorge 1999 Expansion 4/
1/ Refects resenation, demand and capacity demand charges as daily rates.
2/ Designed on a 1000/o load factor basis ofthe Rate Schedule TF-1 (Large Customer) rates.
3/ LS-21 and LS-2F \olumetric bid senice will also be assessed Rate Schedule LS-2F liquefaction and wporization charges.
4/ Rates fcr the years 2018 fi3rward are as follows (surcharge ends March 31, 2025):
$0.09855
20170321-3056 FERC pDF (Unofficiaf) 03/21,/2017
FEDERAL ENERGY REGULATORY COMMISSION
WASHINGTON, D.C, 20426
OFFICE OF ENERGY MARKET REGULATION
In Reply Refer To:
Letter Order Pursuant to $ 375.307
Northwest Pipeline LLC
Docket No. RPl 7-445-000
Issued: March 21,2017
Northwest Pipeline LLC
P.O. Box 58900
Salt Lake City, UT 84158-0900
Attention: LarenGertsch,Director
Rates and Tariffs
Reference: 2017 Summer Fuel Filing
Dear Ms. Gertsch
On February 28,2017,Northwest Pipeline LLC (Northwest) filed a tariff recordr
to comply with Sections 14.12 and 14.20 of the General Terms and Conditions in its
tariff. These Sections require a) the fuel reimbursement factors for the transportation rate
schedules to be determined semi-annually to become effective on April 1 and October I
each year and b) the fuel reimbursement factors for storage rate schedules to be
determined annually to become effective April 1 of each year. Northwest proposes that
the referenced tariff record become effective on April 1,2017. We accept the referenced
tariff record, effective April 1,2017, as proposed.
Northwest proposes the following adjustments to its fuel reimbursement factors:
a) an increase from I .19 percent to I .28 percent in the factor for Northwest's
transportation services under Rate Schedules TF-l, TF-2, TI-1, and DEX-I; b) a decrease
from 0.23 percent to 0.15 percent in the factor for Northwest's underground storage
services under Rate Schedules SGS-2F and SGS-2I; c) a decrease from 0.71 percent to
0.53 percent for Northwest's liquefaction factor for liquefied natural gas (LNG) storage
services under Rate Schedules LS-l, LS-2F, LS-3F, LS-2I, and LD-4I; and d) an increase
I Northwest Pipeline LLC; FERC NGA Gas Tariff; Fifth Revised Volume No. l,
Sheet No. 14. Fuel Use Factors. 19.0.0.
Exhibit No. 3
Case No. INT-G-17-05
lntermountain Gas Company
Page 17 ot 41
2017032L-3056 FERC pDF (Unofficial) 03/21,/201,7
Docket No. RP 1 7-445-000
from 0.34 percent to 0.53 percent for Northwest's vaporization factor for LNG storage
services under Rate Schedules LS-l, LS-2F, LS-3F and LS-2I. As part of its annual
Summer Fuel Filing, Northwest must true-up the Liquefaction Facility Charge for Rate
Schedules LS-3F and LD-4I. Northwest proposes no change for 2017 to the estimated
LS-3F and LD-4I liquefaction charges.
Public notice of the filing was issued on March 2,2017. Interventions and protests
were due as provided in section 154.210 of the Commission's regulations (18 C.F.R.
$ 154.210 (2016)). Pursuant to Rule 214 (18 C.F.R. $ 385.214 (2016)), all timely filed
motions to intervene and any unopposed motion to intervene out-of-time filed before the
issuance date of this 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 hling or of any rate, charge, classification, or any rule,
regulation, or practice affecting such rate or service contained in your tariff; nor shall
such acceptance be deemed as recognition of any claimed contractual right or obligation
associated therewith; and such acceptance is without prejudice to any findings or orders
which have been or may hereafter be made by the Commission in any proceeding now
pending or hereafter instituted by or against your company.
This order constitutes final agency action. Requests for rehearing by the
Commission may be filed within 30 days of the date this order issues, pursuant to
l8 c.F.R. $ 38s.713 (2016).
Sincerely,
Monique Watson, Acting Director
Division of Pipeline Regulation
Exhibit No. 3
Case No. INT-G-17-05
Intermountain Gas Company
Paoe 18 of41'1 -L-
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. I
Exhibit No. 3
Casb No. INT-G-'l7-05
lntermountain Gas Company
Page 19 of41
Nineteenth Revised Sheet No. 14
Superseding
Eighteenth Revised Sheet No. 14
STATEMENT OF FUEL USE REQUIREMENTS FACTORS
FOR REIMBURSEMENT OF EUEL USE
Applicable to Transportatlon Servj-ce Rendered Under
Rate Schedules Contained in this Tariff, Fifth Revised Volume No. 1
The rates set forth on Sheet Nos. 5, 6, J, B and B-A are excl-usive of
fuel- use requirements. Shipper shall rej-mburse Transporter in-kind for 1ts
fuel use requirements in accordance with Section 14 of the General Terms and
Condi-tions contained herein,
The fuel use reimbursement furnished by Shippers shafl be as fol-fows
for the applicable Rate Schedules included in thj-s Tarj-ff:
Rate Schedules TE-1, TE-2, TI-1-, and DEX-I-
Rate Schedule TF-1 - Evergreen Expansion
fncrementaf Surcharge (l-)
Rate Schedule TFL-1
Rate Schedul-e TIL-1
Rate Schedules SGS-2F and SGS-2I
Rate Schedules LS-2E, LS-3F and LS-2I
Liquefaction
Vaporlzatj-on
Rate Schedule LD-4I
Liquefaction
1_.282
0.508
0. 158
0.538
0.538
0.53ts
The fuel use factors set forth above shall be calcul-ated and adjusted
as explained in Section 14 of the General Terms and Conditions. Fuel
reimbursement quantj-ties to be supplied by Shippers to Transporter sha11 be
determlned by applying the factors set forth above to the quantity of gas
nominated for receipt by Transporter from Shipper for transportation,
Jackson Prairle injection, Plymouth liquefaction, Plymouth vaporization, or
for deferred exchange, as applicable.
Footnote
(1) In addition to the Rate Schedule TE-1 fuel use requirements factor, the
Evergreen Expansion fncremental Surcharge will apply to the quantity of gas
nominated for receipt at the Sumas, SIPI or Pacific Pool- receipt poj-nts under
Evergreen Expansion service agreements.
Exhibit No. 3
Case No. INT-G-17-05
lntermountain Gas Company
Page 20 of 41
NOVA GAS TRANSMISSION LTD.
(4 pages)
oRDER TG-004-2017
IN THE MATTER OF the National Energt Board Act
(Act) and tlhe regulations made thereunder; and
IN THE MATTER OF an application made by NOVA Gas
Transmission Ltd. (NGTL) datedT April2017, for approval of the
Final2017 Rates, Tolls and Charges and the 2017 Abandonment
Surcharges pursuant to Part IV of the Act filed with the National
Energy Board (Board) under File OF-Tolls-Groupl-N081-2017-01 01.
BEFORE the Board on25 April2017.
WHEREAS on 7 April20l7, NGTL filed an application (Application) to set Final2}l7 Rates,
Tolls and Charges on the NGTL system for the period 1 January 2017 to 31 December 2017
(Final20l7 Tolls);
AND WHEREAS NGTL proposed to set Final 2017 Tolls for the period I January 2017 to the
first day of the month at least l0 days following Board approval of the Application (the Effective
Date) at the same level as the Interim 2017 Tolls approved by the Board in Order TGI-002-2016;
and for the period of the Effective Date to 3 I December 2017 at the level of the Final 20 I 7 Rates
set out in Attachment D to the Application; and with respect to Abandonment Surcharges, at the
level approved by the Board through Order TGI-002-2016 from I January 2017 to
3l December 2017;
AND WIIEREAS NGTL advised the Board that the applied-for Final 2017 Tolls are in accordance
with its 2016 and 2017 Revenue Requirement Sefflement approved by Board Order TG-001-2016 on
7 April 2016;
AI\D WHEREAS NGTL advised the Board that the FinalZ}l7 Tolls were determined using the
existing rate design methodology approved in Order TG-04-2010;
AND WHEREAS NGTL advised the Board that it is proposing to dispose of the difference
between the Final and Interim Revenue Requirements over the rest of 2017;
Exhibit No. 3
Case No. INT-G-17-05
lntermountain Gas Company
Page21 of41
(rrFP)
for
AND WHEREAS NGTL met with the Tolls, Tariff, Facilities and Procedures Committee
on 14 March2017 and presented its proposal for establishing Final 2016 Tolls and options
treatment of the variance;
AI\D WHEREAS the Board sought comments on the Application and no party has opposed the
Application;
AND WHEREAS the Board has determined that the applied-for tolls are just and reasonable;
/)
Exhibit No. 3
Case No. INT-G-17-05
lntermountain Gas Company
Page 22 ot 41
THEREFORE,IT IS ORDERED, pursuant to Part IV of the Act, tolls be set:
i) as Final for the period of I January 2017 to 3l May 2017, at the same level as the
interim tolls in place over that period as approved by the Board in
Order TGI-002-2016;
as Final for the period of 1 June 2017 to 3 I Decemb er 2017 , at the level of the
Final2017 Rates set out in Affachment D to the Application; and
iii) with respect to the Abandonment Surcharges, from I January 2017 to
3l December 2017, as Final at the level approved by the Board through
Order TGI-002-2016.
NATIONAL ENERGY BOARD
Original signed by
Sheri Young
Secretary of the Board
ii)
NOVA Gas Transmission Ltd.
Exhibit No. 3
Case No. INT-G-I7-05
lntermountain Gas Company
Table of Rat849t33rff df,arges
Page 1 of '1
Service Rates,Tolls and Charges
l. Rate ScheduleFT-R Refer to Attachment"l" forapplicable FT-RDernand Rate pernnnth bmedon a three-
yearterm (Price Point "B")& Surcharge foreachReceipt Point
Average Firm Service Receipt Price (AFSRP) $ 233.y2/lfnt
2. Ibte Schedule FT-RN Refer to Attachment"l" forapplicableFT-RNDemand Rate pernnnth & Surcharge
for each Receipt Point
3. Rate Schedule FT-Dr Refer to Attachment "2" for applicable FT-D Demand Rate per nnnth based on a one
yearterm (Price Point *2") & Surcharge foreach Goup I orGoup 2 Delivery Point
AverageFT-DDemand Rate forCroup I Delivery Points $ 5.61/Cr.I
FT-D Demand Rate forGoup 2 Delivery Points $ 5.37lCrI
FT-D Dennnd Rate forGoup 3 Delivery Points $ 6.,14lGI
4. RateScheduleSTFT STFTBid Price : Minimum of 100% oftheapplicable FT-DDenrandRatebased ona
one yearterm(Price Point "Z") foreach Croup 1 Delivery Point
5. Rate Schedule FT-DW FT-DW Bid Price : Min imum o f l25Yo of the app licab le FT-D Denran d Rate b ased o n
a three yearterm(Price Point "Y') for each Croup I Delivery Point
6. Rate Schedule FT-Pr Refer to Attachment"3" forapplicable FT-P Demand Rate pernnnth
7. RateScheduleLRS Contract Term
20 years
Effective LRS Rate ($/ l0rnf /dav)
7.97
8. Rate Schedule LRS-3 LRS-3 DenrandRatepernrcnth $ 129.55/103nf
9. Rate Schedule IT-R Refer to Attachrnent" l" forapplicable IT-RRate foreach Receipt Point
10. Rate Schedule IT-D'Refer to Attachment"2" forapplicable IT-DRate foreach Delivery Point
11. Rate Schedule FCS The FCS Charge is determined in accordance with Attachrnent " 1" to the applicable
Schedule ofService
12. RateSchedulePT The PT Charge is determined in accordancewith the applicable Schedule ofService
13. Rate Schedule OS Schedule No.Charse
2016800075
2016800076
2016800077
2016800078
2016805891
148.02
148.02
148.02
148.02
148.02
$
$
$
$
$
/l03nf /month
/l0rnf /nnnth
/l03nf / nronth
/ldnf /nronth
/l03nf / nronth
monthnronth
2011475772
2017849279
$
$
9.250.00
788.002003004522 Applicable IT-Rand IT-DRate
201147@54 $ 717,000.00 MinimumAnnual
20|475056 t20n476092 I $
2016721799 120167s92s4 $
0.095
1,000.00
/ GI and
/ nronth
14. Rate Schedule CO2 Tier
I
2
J
COa Rate ($/103nt')
554.29
438.58
284.76
15. Monthly Abandonment
Surcharge 2 $11.38/ldnf/nronth $0.30/Gl/nronth
16. Daily Abandonment
Surcharge 3 $0.3711dm /day $0.0099/GI/day
L Service under mte Schedules FT-D, FT-P and IT-D 6r delivery staions identifed in Attachment 2, and stations identifed on rate Schedules OS No
2011476092, are subj ect to the AT CO Pipelines Franchise Fees punuant to paragmph 1 5. l 3 of the General Tams and Conditions.
2. Monthly Abandonment Surcharge applicable to Rde Schedules FT-R, FT-D, FT-P, FI-RN, FT-DW, STFT, LRS-3, and the bllowing Rde Schedules
OS: 2016800075, 2016800076, 2016800077, 2016800078, and 2016805891.
3, DailyAbandonmentSurchargeapplicabletoRateScheduleslT-R,IT-D,LRS,thebflowingRaeSchedulesOS:2011476052,2011476054,20114750fi,
2011476092,2016721799,2016759254,2003004522, ard ifapplicable Ovo-Run Gas.
Effective Date: June 1,2017
Grcup 1
Delivery Point
ilumb€l
pe, Monlh
Prico Point'2"
($/GJ)
IT-D RE
Per Day
(3/GJ)
Gup I D.livery Point Nmc
NOVA Gas Transmission Ltd
ALLIANCE CLAIRMONT INTERCONNECT APN
ALLIANCE EDSON INTERCONNECT APN
ALLIANCE SHELL CREEK INTERCONNECT APGC
BOUNDARY LAKE BORDER
EMPRESS BORDER
GORDONDALE BORDER
MCNEILL BORDER
Exhibit No. 3
Case No. INT-G-17-05
lntermountain Gas Company
Page 24 o'f 41
Attachment 2
Delivery Point Rates
Page 1 of 5
31111
31110
31112
3002
1 958
3886
6/.04
5.37
5.37
5.37
5.37
c.J/
5.84
5.84
0.1941
0.194'1
0.'r941
0.1941
0.1941
o.2't't3
0.1941
0.2115
0.1941
0.'194't
0.1941
0.1941
0.1941
0.'t94't
0.1941
0.1941
0.1941
0.1941
0.1941
0.1941
0.1941
0.1941
0.1941
0.1941
0.'1941
0.194'1
0.1941
0.1941
0.'1941
0.194.1
0.'1941
0.1941
0.1941
0.1 941
0.1941
0.1941
0.1941
0.194.1
0.1 941
0.1941
0.194',1
0.1941
0.194'r
0.1941
0.1941
0.1941
0.1941
0.1941
0.1941
0.'1 1
0.'1941
0.1941
0.1941
0.1941
0.1941
0.1941
0.1941
0.1 941o.'t 1
0.1941
0.1941
0. r941
0.1941
0.194'l
0.1941
0.1941
0.1941
0.1941
0.1941
0.1941
0.'1941
0.1941
0.'194'l
0.1941
31001
3880
31@3
31002
3'1004
31005
31 006
3214
31 007
31@8
3868
3297
3059
31009
3!fi2
31012
3488
3237
3662
3216
3135
3288
3/.23
31013
31 014
3299
3068
3268
3933
3655
3067
3285
3468
3295
3259
3164
3289
3670
3918
31015
3678
3265
320/.
3293
3109
31016
3266
32$,2
3634
3165
3866uu
3157
3106
3101
31017
32ta
3495
31018
3907
3669
3665
3151
36,?2.
31019
ADM AGRI INDUSTRIES SALES APN
AECO INTERCONNECTION
AGRIUM CARSELAND SALES APS
AGRIUM FT. SASK SALES APN
AGRIUM REDWATER SALES APN
AINSWORTH SALES APGP
AIR LIQUIOE SALES APN
AKUINU RIVER WEST SALES
ALBERTA ENVIROFUELS SALES APN
ALBERTA HOSPITAL SALES APN
ALBERTA-MONTANA BORDER
ALDER FLATS SOUTH NO 2 SALES
ALLISON CREEK SALES
ALTASTEEL SALES APN
AMOCO SALES (BP SALES TAP)
APL JASPER SALES APN
ARDLEY SALES
ASPEN SALES
ATUSIS CREEK EAST SALES
AURORA NO 2 SALES
AURORA SALES
BANTRY SALES
BASHAW WEST SALES
BAYMAG SALES APS
BEAR CREEK COGEN SALES APGP
BEAR RIVER WEST SALES
BEAVER HILLS SALES
BENBOW SOUTH SALES
BIG EDDY INTERCONNECTION
BIG PRAIRIE SALES
BIGSTONE SALES
BILBO SALES
BLEAK LAKE SALES
BOOTIS HILL SALES
BOTHA SALES
BOULDER CREEK SALES
BRAINARD LAKE SALES
BRAZEAU EAST SALES
BRAZEAU SOUTH SALES
BUFFALO CREEK INTERCONNECTION
BUROETT COGEN SALES APS
BURNT RIVER SALES
BURNT TIMBER SALES
CABIN SALES
CADOGAN SALES
CALDWELL SALES
CALGARY ENERGY CENTRE SALES APS
CALUMET RIVER NO 2 SALES
CALUMET RIVER SALES
CANOE LAKE SALES
CANOE LAKE SALES NO 2
CARBON INTERCONNECTION
CARIBOU LAKE SALES
CARIBOU LAKE SOUTH SALES
CARMON CREEK SALES
CAROLINE SALES
CARSELAND COGEN SALES APS
CARSON CREEK SALES
CAVALIER SALES
CHAIN I.AKES COOP SALES APS
CHANCELLOR INTERCONNECTION
CHAPEL ROCK SALES
CHAWIN SALES
CHEECHAM WEST NO 2 SALES
CHEECHAT\i VVEST SALES
CHEVRON FT. SASK SALES APN
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5 J/
5 5/
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
5.37
Yes
Yes
Yes2
Yes
Yes2
Yes
Yes
lT-O Rato
per Day
(S/GJ)
per MonthGHp 2 t elivery Point l'lam Price Poant'Z'
($/GJ)Franchise
GrcUP 2
Point
Subjet to
ATCO Pip€line3
TARIFF
Yes
Effective Date: June 1,2017
Exhibit No. 3
Case No. INT-G-17-05
lntermountain Gas Company
Page 25 ol 41
FOOTHILLS PIPB LINES LTD.
(3 pages)
e)
Exhibit No. 3
Case No. INT-G-17-05
lntermountain Gas Company
Page 26 of 41
TransCanada
,n buiiness to deliver
450 - 'l Street SW
Calgary, Alberta T2P 5Hl
Tel: [phone]
Fax: [phone]
Email: bemard [e-mail]
October 31,2016
National Energy Board
517 Tenth Avenue SW
Calgary, Alberta T2R 0A8
Filed Electronically
Attention: Ms. Sheri Young, Secretary of the Board
Dear Ms. Young:
Re: Foothills Pipe Lines Ltd. (Foothills)
Statement of Rates and Charges effective January lr20l7
Foothills encloses for filing pursuant to section 60(l)(a) of the National Energt Board Actl rates
and charges for transportation service on Foothills Zones 6,7,8 and 9 to be effective
January 1,2017 (Effective 2016 Rates).
The following attachments are included with this letter:
o Attachment I consists of supporting Schedules A through G
o Attachments 2 and 3 are black-lined and clean copies, respectively, of the relevant section of
the Tariff showing the Effective 2017 Rates
The rates and charges are based on the methodology approved by the Board in
Decision TG-8-2004, as amended by Order TG-03-2007.
The filing is also made in accordance with the MH-001-2013 Decision2 with respect to Foothills'
Abandonment Surcharges effective January 1,2017, which are also included in the Table of
Effective 2017 Rates. The supporting information on the Abandonment Surcharges calculation is
provided in the attached Schedule G.
Foothills met with shippers and interested parties on October 12,2016, and presented the
preliminary 2017 revenue requirement and preliminary Effective 2017 Rates. On the basis of this
consultation, Foothills is not aware of any objections to its proposal for establishing the Effective
2017 Rates.
t R.S.C. 1985, c. N-7, as amended, and the regulations made thereunder.
2 See MH-001-2013 Decisio n, page 7 5.
Exhibit No. 3
Case No. INT-G-17-05
lntermountain Gas Company
Page27 ol 41October 31,2016
Ms. S. Young
Page2 of2
Foothills will notiff its shippers and interested parties of this filing and post a copy of it on
TransCanada's Foothills System website at:
http ://www.tran scanada.corn/customerexpres s/9 3 4.htm I
Communication regarding this application should be directed to:
Mark Manning
Senior Project Manager, Tolls and Tariffs
Canadian Gas Pipelines
TransCanada Pipelines Limited
450- I Street SW
Calgary, Alberta T2P 5Hl
Telephone: [phone]
Facsim i le : (403) 920 -23 47
Email : [e-mail]
Joel Forrest
Director Canadian Law
Natural Gas Pipelines
TransCanada Pipelines Limited
450-lStreetSW
Calgary, Alberta T2P 5Hl
Telephone: [phone]
Facsimile: [phone]
Email : j oe l_forrest @tr anscanada. com
Yours truly,
Foothills Pipe Lines Ltd.
Original signed by
Bernard Pelletier
Director, Regulatory Tolls and Tariffs
Canadian Gas Pipelines
Attachments
cc: Foothills Firm Shippers
Interruptible Shippers and Interested Parties
Foothills understands that any party that is opposed to the rates and charges will advise the
Board accordingly.
Foothills Pipe Lines Ltd.
Exhibit No. 3
Case No. INT-G-17-05
lntermountain Gas Company
Page 28 ot 4'l
Page I
TABLE OF EFFBCTIVE RATES
1. Rate Schedule FT, Firm Transportation Service
Demand Rate
($/GJ/Km/Ivlonth)
Zone 6 0.0041655042
Zone 7 0.0032610571
Zone 8* 0.0125111530
Zone 9 0.0087703201
2. Rate Schedule OT, Overrun Transportation Service
Commodity Rate
($/GJ/Km)
Zone6 0.0001506429
ZoneT 0.0001 179341
3. Rate Schedule IT, Interruptible Transportation Service
Commodity Rate
($/GJ/Km)
ZoneS* 0.0004524581
Zone 9 0.0003171732
4. Monthly Abandonment Surcharge**
All Zones 0.0923237 64 7 ($/GJ/i\4onth)
5. Daily Abandonment Surcharge***
All Zones 0.00303s30 I 9 ($/GJ/Day)
* For Zone 8, Shippers Haul Distance shall be 170.7 km.
**Monthly Abandonment Surcharge applicable to Rate Schedule Firm Transportation Service, and Short Term Firm
Transportation Service for all zones.
*'r'*Daily Abandonment Surcharge applicable to Rate Schedule Overrun Transportation Service for zone 6 & 7,
Intemrptible Transportation Service for zone 8 & 9, and Small General Service for zone 9.
TARIFF - PHASE I Effective Date: January 1,2017
Exhibit No. 3
Case No. INT-G-17-05
lntermountain Gas Company
Page 29 ot 41
GAS TRANSMISSION NORTHWEST LLC
(3 pages)
201-51-230-3008 FERC pDF (Unofficial) 72/30/2015
FEDERAL ENERGY REGULATORY COMMISSION
WASHINGTON, D.C, 20426
OFFICE OF ENERGY MARKET REGULATION
In Reply Refer To:
Letter Order Pursuant to
$ 37s.307(a)(7)(i)
Gas Transmission Northwest LLC
Docket No. RP I 6-235-000
December 30,2015
Gas Transmission Northwest LLC
700 Louisiana Street, Suite 700
Houston, TX 77002-2700
Attention:John A. Roscher, Director
Rates, Tariffs, and Certificates
Reference: Tariff Changes Necessitated by Leap Year
Ladies and Gentlemen:
On November 25, 201 5, Gas Transmission Northwest LLC (GTN) fi led tariff
recordsr to modifu the Medford Daily Negotiated Reservation Charges for service under
Rate Schedules FTS-l(E-2)(Diamond 1) and FTS-I(E-2)(Diamond 2) to reflect daily
charges computed on the basis of 366 days for leap years. GTN states that the proposed
reservation charges are calculated by multiplying the currently effective daily reservation
charges by 365, dividing the results by 366, and rounding to six decimal places. The
proposed reservation charges will remain in effect from January 1,2016 through
December 31,2016, as 2016 is a leap year. Further, GTN is a) relocating the leap year
reference from footnote (l) to footnote (h) within Section 4.3 of its tariff, b) adding leap
year charges to footnote (h) to eliminate the need for similar filings in future leap years,
c) removing a now-inapplicable reference to the Medford Extension annual revenue
requirement in footnote (h), and d) removing the reference to footnote (l), which will be
reserved for future use, from tbeE-2 (Diamond 1) and E-2 (Diamond 2) Rate Schedules
in Section 4. 1. GTN proposes that the referenced tariff records become effective on
January l, 2016. We accept the referenced tariff records, effective January I, 2016, as
proposed.
' Gar Transmission Northwest LLC, FERC NGA Gas Tariff, GTN Tariffs 4.1 -
Statement of Rates,FTS-1 and LFS-1 Rates. 15.0.0 and 4.3 - Statement of Rates,
Exhibit No. 3
Case No. INT-G-17-05
lntermountain Gas Company
Page 30 of 41
Footnotes to Statement of Effective Rates and Charges. 12.0.0.
201s1230-3008 FERC PDF (Unofficial) 1.2/30/207s
Docket No. RPI 6-235-000
Public notice of the filing was issued on December 1,2015. Interventions and
protests were due as provided in section 154.210 of the Commission's regulations (18
C.F.R. $ 154.210 (2015)). Pursuant to Rule 214 (18 C.F.R. $ 385.214 (2015)), all timely
filed motions to intervene and any unopposed motion to intervene out-of-time filed
before the issuance date of this 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
such acceptance be deemed as recognition of any claimed contractual right or obligation
associated therewith; and such acceptance is without prejudice to any findings or orders
which have been or may hereafter be made by the Commission in any proceeding now
pending or hereafter instituted by or against your company.
This order constitutes final agency action. Requests for rehearing by the
Commission may be filed within 30 days of the date this order issues, pursuant to
18 C.F.R. $ 38s.713 (2015).
Sincerely,
Nils Nichols, Director
Division of Pipeline Regulation
Exhibit No.3
Case No. INT-G-17-05
lntermountain Gas Company
Paoe 31 of41- -2-
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
DAILY
MILEAGE (a)
(Dth-MILE)
Max. Min.
BASE 0.000434 0.000000
STF (e) (e) 0.000000
EXTENSION CHARGES
MEDFORD
E-l (0 0.0027s9 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) 0.001282 0.000000
CARTY LATERAL
E-4 (p)
OVERRUN CHARGE CI)
SURCHARGES
ACA (k)
Exhibit No. 3
Case No. INT-G-17-05
lntermountain Gas Company
Pase 32 BTART 4.1
4.1 - Statement of Rates
FTS-I and LFS-I Rates
v. I 5.0.0 Superseding v. 14.0.0
STATEMENT OF EFFECTIVE RATES AND CHARGES FOR
TRANSPORTATION OF NATURAL GAS
Rate Schedules FTS-I and LFS-I
RESERVATION
DAILY
NON-MTLEACE (b)
(Dth)
Max. Min.
DELIVERY (c)
(Dth-MrLE)
Max. Min.
0.000016 0.000016
FUEL (d)
(Dth-MILE)
Max. Min.
0.0050% 0.0000%0.034393
(e)
0.004641
0.001283
0.16647s
0.000000
0.000000
0.000000
0.000000
0.000000
0.000026
0.000000
0.000026
0.000000
0.000016 0.000016 0.0050% 0.0000%
Issued: November 24, 2015
Effective: January l, 2016
0.000000 0.000000
0.000000 0.000000
0.000000 0.000000
(k) (k)
Docket No. RPI 6-235-000
Accepted: December 30, 2015
Exhibit No. 3
Case No. INT-G-17-05
lntermountain Gas Company
Page 33 of41
DOMINION ENERGY QUESTAR PIPELINE, LLC
(6 pages)
20L70627-3030 FERC PDF (Unofficial) 06/27/20L7
FEDERAL ENERGY REGULATORY COMMISSION
WASHINGTON, DC 20426
OFFICE OF ENERGY MARKET REGULATION
In Reply Refer To:
Letter Order Pursuant to $ 375.307
Dominion Energy Questar Pipeline, LLC
Docket No. RP1 7-768-000
June 27,2017
Dominion Energy Questar Pipeline, LLC
c/o Dominion Energy Questar Pipeline Services, Inc
333 South State Street, P.O. Box 45360
Salt Lake city, UT 84145-0360
Attention: L. Bradley Burton, General Manager
Federal Regulatory Affairs and FERC Compliance Officer
Reference: Change of Company Name
Dear Mr. Burton:
On May 30,2017, Dominion Energy Questar Pipeline, LLC (DEQP) filed tariff
recordsl to reflect the change of the listed company name in its Tariff, consistent with the
new company name. DEQP requests waiver of the Commission's 30-day notice
requirement to allow the tariff records to become effective June l, 2017. Waiver of the
notice requirement is granted and the tariff records are accepted effective June 1, 2017 , as
proposed.
Public notice of the filing was issued on May 31,2017. Interventions and protests
were due as provided in section 154.210 of the Commission's regulations (18 C.F.R. $
154.210 (2016)). Pursuant to Rule 214 (18 C.F.R. $ 385.214 (2016)), all timely filed
motions to intervene and any unopposed motion to intervene out-of-time filed before the
issuance date of this 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 fltled.
Exhibit No. 3
Case No. INT-G-17-05
lntermountain Gas Company
Page34 of 41
lSee Appendix.
20770627-3030 FERC PDF (Unofficial) 06/27/201.7
Docket No. RP17-768-000
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 constifuting
approval of the referenced filing or of any rate, charge, classification, or any rule,
regulation, or practice affecting such rate or service contained in your tariff; nor shall
such acceptance be deemed as recognition of any claimed contractual right or obligation
associated therewith; and such acceptance is without prejudice to any findings or orders
which have been or may hereafter be made by the Commission in any proceeding now
pending or hereafter instituted by or against your company.
This order constitutes final agency action. Requests for rehearing by the
Commission may be filed within 30 days of the date this order issues, pursuant to
18 C.F.R. $ 38s.713 (2016).
Sincerely,
Elizabeth Zerby, Acting Director
Division of Pipeline Regulation
Exhibit No. 3
Case No. INT-G-17-05
lntermountain Gas Company
Paoe 35 of 41'1-L-
201-70627-3030 FERC pDF (Unofficial) 06/27/20t7
Docket No. RP 1 7-768-000
Dominion Energy Questar Pipeline, LLC
FERC NGA Gas Tariff
Tariffs
Tariff Records Accepted Effective June I , 2017
Tariff. Second Revised Volume No. 1. 5.0.0
Preli m ina.ry Statement. Pre I imi nary Statement" 2. 0. 0
Pt. 1 Section 1. Definitions. 8.0.0
Pt. 1 Section 2.5. Access Agreement Request. 5.0.0
Pt. I Section 23.2. Shared Personnel and Facilities. 3.0.0
Pt. 3 Section 16.3. Operating Fuel and Shrinkage Reimbursement. 1.0.0
Questline Acctss,{elo1'Questl ine Access Asreement. 6.0.0
Tariff. Original Volume No. 2.2.0.0
Exhibit No. 3
Case No. INT-G-17-05
lntermountain Gas Company
Page 36 of 41
-J-
Appendix
20L672t9-3013 FERC PDF (Unofficial) 1.2/1.9/201.6
FEDERAL ENERGY REGULATORY COMMISSION
WASHINGTON, D.C. 20426
OFFICE OF ENERGY MARKET REGULATION
In Reply Refer To:
Letter Order Pursuant to
$ 37s.307(a)(7)(i)
Questar Pipeline, LLC
Docket No. RPI 7-203-000
December 19,2016
Questar Pipeline, LLC
333 South State Street
P.O. Box 45360
Salt Lake City, UT 84145
Attention:L. Bradley Burton, General Manager
Federal Regulatory Affairs
Reference: Annual Fuel Gas Reimbursement Percentage Filing
Ladies and Gentlemen:
On November 28,2016, Questar Pipeline, LLC (Questar) filed a tariff recordr to
reflect an increase in Questar's Fuel Gas Reimbursement Percentage (FGRP) from the
currently effective 1.37 percent to 1.56 percent. The proposed new rate is based on a
prospective recovery rate during 2017 of 1.61 percent and a -0.05 percent amortization to
refund over-recovered FGRP volumes from the October 1,2015 through September 30,
2016 deferral period. Questar requests the Commission approve the tariff record
effective January I,2017 . We accept the referenced tariff record, effective January 1,
2017, as proposed.
Public notice of the filing was issued on November 30, 2016. Interventions and
protests were due as provided in section 154.210 of the Commission's regulations (18
C.F.R. $ 154.210 (2016)). Pursuant to Rule 214 (18 C.F.R. $ 385.214 (2016)), all timely
filed motions to intervene and any unopposed motion to intervene out-of-time filed
before the issuance date of this 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.
I Questar Pipeline, LLC; FERC NGA Gas Tariff; Tariffs: Statement of Rates.
Statement of Rates. I1"0.0.
Exhibit No.3
Case No. INT-G-17-05
lntermountain Gas Company
Page37 ot41
201-61,21-9-3013 FERC PDF (Unofficial) t2/L9/2016
Docket No. RPI 7-203-000
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
such acceptance be deemed as recognition of any claimed contractual right or obligation
associated therewith; and such acceptance is without prejudice to any findings or orders
which have been or may hereafter be made by the Commission in any proceeding now
pending or hereafter instituted by or against your company.
This order constitutes final agency action. Requests for rehearing by the
Commission may be filed within 30 days of the date this order issues, pursuant to
18 C.F.R. $ 38s.713 (20t6).
Sincerely,
Jerry Pederson, Director
Division of Pipeline Regulation
Exhibit No. 3
Case No. INT-G-17-05
lntermountain Gas Company
Paoe 38 of 41-.,-L-
Dominion Energy Questar Pipeline, LLC
FERC Gas Tariff
Second Revised Volume No. 1
Exhibit No. 3
Case No. INT-G-17-05
lntermountain Gas Company
Page 39 of 41
Statement of Rates
Section Version: 11.0.0
Rate Schedule/
Type of Charge
(a)
PEAKING STORAGE
Firm Peaking Storage Service - PKS
Monthly Reservation Charge
Maximum 4/ ......,.........
Minimum
Usage Charge
Injection
Withdrawal
CLAY BASIN STORAGE
Firm Storage Service - FSS
Monthly Reservation Charge
Deliverability
Maximum 4/,,,,...........,,........
Minimum......
Capacity
Maximum
Minimum....,,
Usage Charge
InjectionU
Withdrawal
Authorized Overrun Charge ........
MaximumU
Minimuml/...
Interruptible Storage Service - ISS
Usage Charge
Inventory 5/
Maximum
Minimum......
InjectionU
Withdrawal
STATEMENT OF RATES
Base
Tariff
Rate ($)
(b)
2.87375
0.00000
o.o3B72
0.03872
2.85338
0.00000
o.02378
0.00000
0.01049
0.01781
0.30315
0.01781
..0.05927
..0.00000
..0.01049
.. 0,01781
OPTIONAL VOLUMETRIC RELEASES /
Peaking Storage Service - PKS
Maximum 4/ .....,,,,.......
Minimum......
Firm Storage Service - FSS
Maximum 4/
Minimum.....
Clay Basin Storage Service - FSS
Injectionl/
Withdrawal
PARK AND LOAN SERVICE - PAL1
Daily Charge
Maximum
Minimum.,...,
Delivery Chargel/
6fii;;;i;i; ili;;;;;67
.40890
.00000
.57068
.00000
0.03872
o.03872
.....0.01049
.....0.01781
0.30315
0.00000
0.02830
..3..0
FUEL REIMBURSEMENT - 2.Oo/o (0.2olo utility and 1.8olo compressor fuel) for Rate Schedule PAL1
Filed On: November 28,2OL6 Effective On: January L,2Ot7
Usage
Exhibit No. 3
Case No. INT-G-17-05
lntermountain Gas Company
Page 40 of 41
FEDERAL ENERGY REGULATORY COMMISSION
ANNUAL CHARGES UNIT CHARGE
(1 pages)
I.-EDI.:R A I, HNERCiY R bG UI,A'I'ORY COMMIS S ION
\\iA SHINGTON . D.C:. 24426
FY 2016 GAS ANNUAL CHARGES
CORRECTION FOR ANNUAL CHARGES UNIT CHARGE
June26,2017
The annual charges unit charge (ACA) to be applied to in fiscal year 2018 for recovery of
FY 2017 Current year and 2016 True-Up is $0.0013 per Dekatherm (Dth). The new ACA
surcharge will become effective October 1,2017 .
The following calculations were used to determine the FY 2017 unit charge:
Exhibit No. 3
Case No. INT-G-I7-05
lntermountain Gas Company
Page 41 ol 41
0.0012883798
(0.0000299819)
0.0012583879
2017 CTJRRENT:
Estimated Program Cost $61,436,000 dividedby 47,684,694,955 Dth
2016 TRUE-UP:
Debit/Credit Cost ($1,395,864) divided by 46,556,886,468 Dth
TOTAL T]NIT CHARGE :
If you have any questions, please contact Norman Richardson at [phone] or e-mail
at Norman.Richardson@ferc. gov.
PUBLIC
EXHIBIT NOS.4.13
CASE NO. INT.G-17-05
INTERMOTJNTAIN GAS COMPANY
(10 pages)
Exhibit No. 4
Case No. INT-G-17-05
lntermountain Gas Company
Page 1 of 1
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Case No. INT-G-17-05
lntermountain Gas Company
Page 'l of 1
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Case No. INT-G-17-05
lntermountain Gas Company
Page 1 of 1
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Exhibit No. 7
Case No. INT-G-17-05
Intermountain Gas Company
Page 1 of 1
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Case No. INT-G-17-05
lntermountain Gas Company
Page 'l of 'l
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No.
INTERMOUNTAIN GAS COMPANY
Proposed Temporary Surcharges (Credits). Variable Costs
Description
Exhibit No. 9
Case No. INT-G-17-05
lntermountain Gas Company
Page 1 of 1
Amount
1
2
3
4
5
b
7
8
(a)
Account 1910 Variable Amounts Which Apply to RS, GS-l, and LV-l:
Account 1910 Variable Costs
Normalized Sales Volumes (111116 - 12131116)
Proposed Temporary Surcharge (Credit) - Variable Costs
Lost and Unaccounted For Gas Amounts Which Apply to RS and GS-l:
Lost and Unaccounled For Gas Amounts from INT-G-16{3 (Account 1910-2120)
Lost and Unacmunted For Gas Amortization (Account 1910-2130)
(Over)/Under Collection of Lost and Unaccounted For Gas from INT-G-16-03
Lost and Unaccounted For Gas INT-G-17-05
Total Lost and Unaccounted For Gas Amounts Which Apply to RS and GS-1
Normalized Sales Volumes (111116 - 12131116)
Proposed Temporary Surcharge (Credit) - Lost and Unaccounted For Gas Costs
Lost and Unaccounted For Gas Amounts Which Apply to LV-1, T-3, and T"4:
Lost and Unaccounted For Gas Amounts from INT-G-16-03 (Acmunt 1910-2120)
Lost and Unaccounted For Gas Amortization (Account 1910-2140)
(Over)/Under Collection of Lost and Unaccounted For Gas from INT-G-16-03
Lost and Unacmunted For Gas INT-G-17-05
Total Lost and Unaccounted For Gas Amounts Which Apply to LV-1, T-3, and T4
Normalized Sales Volumes (111116 - 12131116)
Proposed Temporary Surcharye (Credit) - Lost and Unaccounted For Gas Costs
Convert T-4 Lost and Unaccounted For Temporary from a Volumetric Rate to a Demand Rate
Proposed Temporary Surcharge (Credit) - Lost and Unaccounted For Gas Costs (Line 20)
Normalized T4 Sales Volumes (111116 - 12131116)
Total Temporary Collected
INT-G-17{5 Demand Volumes
Proposed Temporary Surcharge (Credit) - Lost and Unaccounted For T"4 Demand Rate (Line 24 Divided by Line 25)
(1) See Workpaper No. 5, Page 1, Line 17, Column (f)
(2) See Workpaper No. 5, Page 2, Line 2, Column (c)
(3) See Workpaper No. 5, Page 2, Line 8, Column (d)
(o) See Workpaper No. 5, Page 2; Line 26, Column (d), plus Line 32, Column (e)
(s) See Workpaper No. 5, Page 2, Line 3, Column (c)
(0) See Workpaper No. 5, Page 2, Line 15, Column (d)
o See Workpaper No. 5, Page 2; Line 27, Column (d), plus Line 36, Column (e)
(b)
$ 2,440,$9 (1)
$ 0.00748
U (1,144,0$)(2)
1,327,682 t3\
1 83,649
(823,090) (4)
$ (639,441)
319,930,784
$ (0.00200)
(314,929) (5)
370,566 (6)
55,637
(274,3fi)at
$(218,673)
u3,878,821
$ (0.000er)
$(0.00064)
299,021,450
$ (191,374)
16,352,520
$ (0.01170)
I
10
11
12
13
14
15
16
17
18
19
20
$
21
22
23
24
25
26
326,524,361
Exhibit No.'10
Case No. INT-G-17-05
lntermountain Gas Company
Page 1 of 1
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Case No. INT-G-17-05
lntermountain Gas Company
Page 1 of '1
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Case No. INT-G-17-05
lntermountain Gas Company
Page 1 of 1
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Exhibit No. 13
Case No. INT-G-17-05
lntermountain Gas Company
Page 1 of 1
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NEWS RELEASE
and
CUSTOMER NOTICE
CASE NO. INT.G.17.O5
INTERMOT]NTAIN GAS COMPAIIY
(2 Pages)
4ffiffiilY'*
Intermountain Gas Company files decrease in prices as part of annual PGA
BOISE,IDAHO- August 1412017- Intermountain Gas Company filed its annual Purchased Gas Cost
Adjustment (PGA) application with the Idaho Public Utilities Commission to change its prices by an
overall average decrease of 7.9 percent or approximately $19.2 million. If approved, the decrease would
be effective Oct. l, 2017. The primary reason behind the proposed decrease is a decline in the price of
natural gas that Intermountain purchases for its customers. Because the price for gas is a pass-through
charge directly to its customers, Intermountain's earnings will not decrease because of the proposed
change in prices and revenues.
If approved, residential customers using natural gas will see an average decrease of 8.1 percent or
$3.32 per month based on average weather and usage. Commercial customers, on average, would see
a decrease of 9.2 percent or $16.42 per month.
The company is also proposing to eliminate the temporary surcharges and credits that have been
included in its current prices during the past year. Newer temporary surcharges and credits will be
included going forward.
"Because of industry-specific technological advances in exploration and production, nationwide supply
of natural gas continues to outpace demand, which contributes to lower natural gas prices," said Scott
Madison, Executive Vice President and General Manager of Intermountain Gas. "In addition,
Intermountain continues its long tradition of prudent management of pipeline capacity and summer
storage to ensure the best prices for our customers. We are proud to offer some of the lowest prices for
natural gas in the region and country."
Even with this proposed price decrease, Intermountain continues to urge all its customers to use energy
wisely. Conservation tips, information on government payment energy assistance and programs to
help consumers level out their energy bills over the year can be found on the company's website
www.intgas.com.
The Purchased Gas Adjustment application is filed each year to ensure the costs Intermountain incurs
on behalf of its customer are reflected in its sales prices. The request is a proposal and is subject to
public review and approval by the IPUC. A copy of the application is available for review at the
commission, and on its homepage at wrrw'.puc.idaho.gov as well as the company's website at
www.intsas.com . Written comments regarding the application may be filed with the commission.
Customers may also subscribe to the commission's RSS feed to receive periodic updates via email.
Intermountain Gas Company is a natural gas distribution company serving approximately 350,000
residential, commercial and industrial customers in 75 communities in southern ldaho. Intermountain is a
subsidiary of MDU Resources Group, Inc., which provides essential products and services through its
regulated energ/ delivery and construction materials and services businesses. It is traded on the New York
Stock Exchange os "MDU." For more information about MDU Resources, visit the company's website ot
wunu.mdu.com. For more information about Intermountain, visit wtvtt.intgas.com.
!t *,1. !t * *:f * **,f ,f !f *,t
Media Contact: Mark Hanson, Public Relations Sr., 701-530-1093
I{EWS RELIASE
fi INTERMOUNTAIN-
GAs COMPANYr A$ri*ryol#0i/&srEs 6Es. m
la lhe CoflrtrufiW lo Stri/r'Customer Notice
lntermountain Gas Company files decrease in prices as part of annual PGA
On August 14,2017- lntermountain Gas Company filed its annual Purchased Gas Cost Adjustment (PGA)
application with the ldaho Public Utilities Commission to change its prices by an overallaverage decrease of
T.9percentorapproximately$19.2million. lfapproved,thedecreasewouldbeeffectiveOct. 1,2017.The
primary reason behind the proposed decrease is a decline in the price of natural gas that lntermountain
purchases for its customers. Because the price for gas is a pass-through charge directly to its customers,
lntermountain's earnings will not decrease because of the proposed change in prices and revenues.
lf approved, residential customers using natural gas will see an average decrease of 8.1 percent or $3.32
per month based on average weather and usage. Commercialcustomers, on average, would see a
decrease of 9.2 percent or $16.42 per month.
The company is also proposing to eliminate the temporary surcharges and credits that have been
included in its current prices during the past year. Newer temporary surcharges and credits will be
included going forward.
"Because of industry-specific technological advances in exploration and production, nationwide supply of
natural gas continues to outpace demand, which contributes to lower natural gas prices," said Scott
Madison, Executive Vice President and General Manager of Intermountain Gas. "ln addition,
lntermountain continues its long tradition of prudent management of pipeline capacity and summer
storage to ensure the best prices for our customers. We are proud to offer some of the lowest prices for
naturalgas in the region and country."
Even with this proposed price decrease, lntermountain continues to urge all its customers to use energy
wisely. Conservation tips, information on government payment energy assistance and programs to help
consumers level out their energy bills over the year can be found on the company's website
www.intgas.com.
The Purchased Gas Adjustment application is filed each year to ensure the costs lntermountain incurs on
behalf of its customer are reflected in its sales prices. The request is a proposal and is subject to public review
and approval by the IPUC. A copy of the application is available for review at the commission, and on its
homepage at www.puc.idaho.gov as well as the company's website at www.intqas.com . Written comments
regarding the application may be filed with the commission. Customers may also subscribe to the
commission's RSS feed to receive periodic updates via email.
-,/.#\
WORIGAPER NOS. 1-8
CASE NO. INT-G.17.05
INTERMOUNTAIN GAS COMPANY
(16 pages)
Workpaper No. 1
Case No. INT-G-17-05
lntermountain Gas Company
Page 1 of2
INTERMOUNTAIN GAS COMPANY
Summary of Northwest Pipeline TF-l Full Rate Demand Costs
Line INT.G.16.03
AnnualTherms
rNT.G.16.03
Prices(l)
tNT.G.16.03
Annual CostNo.Transportation
(a)
TF-'l Reservation Contract #1
TF-1 Reservation Contract #2
TF-1 Reservation Contract #3
TF-1 Reservation Conkact #4
TF-1 Reservation Contract #5
TF-1 Reservation Contract #6
TF-1 Reservation Conhact#7
TF-1 Reservation Contract #8
TF-1 Reservation Contract #9
TF-1 Reservation Contract#10
TF-1 Reservation Contract #11
Total
Transportation
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
0.041977
0.052637
0.040972
0.040972
0.040972
0.040972
0.040972
0.040972
0.040972
0.040972
0.040972
(d)
$17,317,140
1,344,885
2,990,940
1,082,869
1,345,924
1,495,470
3,589,128
747,734
4,281,384
1,084,218
2,092,910
$ 37,372,602
rNT.G.17.05
Annual Cost
(b)(c)
1
2
3
4
5
6
7
8
I
10
11
12
$
894,757,350
Line
No.
tNT.G.17.05
Annual Therms
tNT.G.17.05
Prices(2)
(a)
TF-1 Reservation Contract #1
TF-1 Reservation Contract #2
TF-1 Reservation Conhact #3
TF-1 Reservation Contract tl4
TF-1 Reservation Contract #5
TF-1 Reservation Contract #6
TF-1 Reservation Contract #7
TF-1 Reservation Contract #8
TF-1 Reservation Contract #9
TF-1 Reservation Contract #1 0
TF-1 Reservation Contract #11
Total
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
51,08't ,750
0.040691
0.050152
0.039724
0.039724
0.039724
0.039724
0.039724
0.039724
0.039724
0.039724
0.039724
(d)
$16,786,576
1,281,371
2,899,853
1,049,892
1,304,933
1,449p24
3,479,822
724,965
4,150,994
't ,051 ,195
2,029,171
$ 36,208,696
$ (1,163,906)(3)
(b)(c)
13
14
15
16
17
18
19
20
21
22
23
24
25
$
894,757,350
TotalAnnual Cost Difference (Line 24 minus Line 12)
(1) lncludes Noftwest Pipeline charges for three months at leap year rates and for nine months at non-leap year rates.
(2) lncludes Northwest Pipeline charges for three months at 2017 rates and nine months at 2018 rates.
(3) See Exhibit No. 4, Line 3, Column,(h)
INTERMOU NTAIN GAS COMPANY
Summary of Northwest Pipeline TF-1 Discounted Demand Costs
Transportation
tNT.G.16.03
AnnualTherms
rNT-G-I6-03
Prices(1)
Workpaper No. 1
Case No. INT-G-17-05
lntermountain Gas Company
Page 2 ol 2
tNT.G.16.03
Annua! Cost
Line
No.
(a)
TF-1 Reservation Contract #1
TF-1 Reservation Contract #2
TF-1 Reservation Contract #3
TF-1 Reservation Contract #4
TF-1 Reservation Contract #5
TF-1 Reservation Contract #6
TF-1 Reservation Contract #7
Total
Transportation
(a)
TF-1 Reservation Contract #1
TF-1 Reservation Contract #2
TF-1 Reservation Contract #3
TF-1 Reservation Contract #4
TF-1 Reservation Contract #5
TF-1 Reservation Contract #6
TF-1 Reservation Contract #7
Total
(b)
18,250,000 $
29,404,400
58,400,000
36,500,000
32,850,000
11,497,500
4,530,000
191,431,900
0.026632
0.024583
0.024583
0.027861
0.008500
0,036875
0.032764
(d)
$486,031
722,849
1,435,651
1,016,920
279,225
423,967
148,420
$ 4,513,063
rNT-G-17.05
Annual Cost
1
2
3
4
5
6
7
8
Line
No.
INT-G.17-05
AnnualTherms
tNT.G.17-05
Prices G)
(b)
18,250,000
29,404,400
58,400,000
36,500,000
32,850,000
11,497,500
4,530,000
0.025821
0.023834
0.024327
0.027012
0,008500
0,035752
0.031987
(d)
471,230
700,836
1,420,691
985,952
279,225
411,059
144,900
(c)
I
10
11
12
13
14
15
16
$$
191,431,900 $ 4,413,893
17 TotalAnnualCost Difference (Line 16 minus Line 8)$ (99,170) (3)
(1) lncludes Northwest Pipeline charges for three months at leap year rates and for nine months at nonJeap year rates.
(2) lncludes Northwest Pipeline charges for three months at2017 rates and nine months at 2018 rates,
(3) See Exhibit No, 4, Line 4, Column (h)
(c)
INTERMOUNTAIN GAS COMPANY
Summary of Upstream Gapacity Full Rate Demand Costs
Workpaper No. 2
Case No. INT-G-17-05
lntermountain Gas Company
Page 1 ol 2
tNT.G.16.03
Annual Cost
Line
No.Transportation
tNT.G.16.03
Annual Therms
tNT.G.16.03
Prices
(a)
1 Upstream Agreement #1
2 Upstream Agreement #2
3 Upstream Agreement #3
4 Upstream Agreement #4
5 Upsheam Agreement#5
6 Upstream Agreement #6
7 Upstream Agreement #7
B Upstream Agreement #8
9 Total
10 Estimated Upsheam Capacity Release Credits
11 Total Annual Cost lncluding Capacity Release Credits
(b)
25,933,250
351,503,260
26,962,550
37,281,100
26,126,700
128,898,520
54,750,000
22,500,000
$ 0.008963
0.008968
0.008963
0.008962
0.016051
0.016051
0.016051
0.016051
232,428
3,152,403
241,656
334,128
419,372
2,068,974
878,801
361 ,1 52
(c)(d)
$
673,955,380
tNT.G.17.05
Annual Therms
7,688,914
(500,000)
Line
No.Trarypg4qlpn
tNT.G.t7.05
Prices
$ 7,188,914
tNT.G.17.05
Annual Cost
(a)(b)
25,933,250
351,503,260
26,962,550
37,244,600
26,126,700
128,898,s20
54,750,000
22,500,000
0.007728
0.007733
0.007728
0.007728
0.016051
0.016051
0.016051
0.016051
(c)(d)
$200,412
2,718,221
208,368
287,832
419,372
2,068,974
878,801
361 152
7,143,132
(500,000)
$ 6,M3,132
12
13
14
15
'16
17
1B
19
20
Upstream Agreement #1
Upstream Agreement #2
Upstream Agreement #3
Upstream Agreement #4
Upstream Agreement #5
Upstream Agreement#6
Upstream Agreement#7
Upstream Agreement #8
Total
$
673,9'18,890
21 Estimated Upstream Capacity Release Credits
22 Total Annual Cost lncluding Capacity Release Credits
23 Total Annual Cost Difference (Line 22 minus Line ll)
(1) See Exhibit No. 4, Line 5, Column (h)
j_(545,782I (1)
Workpaper No. 2
Case No. INT-G-17-05
lntermountain Gas Company
Page 2 of 2
INTERMOUNTAIN GAS COMPANY
Summary of Upstream Capacity Discounted Demand Costs
Line
No.Transportation
rNT-G.16.03
AnnualTherms
tNT.G.16.03
Prices
tNT-G.16-03
Annual Cost
(a)
1 Upstream Agreement #1
2 Upstream Agreement #2
3 Upstream Agreement #3
4 Upstream Agreement #45 Total
Transportation
(b)
62,050,000 $
37,003,700
452,311,650
37,657,050
589,022,400
tNT-G-17-05
AnnualTherms
(d)
$842,265
525,227
7,679,856
638,988
$ 9,686,336
INT.G-17.05
Annual Cost
(c)
0.013574
0.014194
0.016979
0.016969
Line
No.
tNT.G.t7.05
Prices
(a)
6 Upstream Agreement #1
7 Upstream Agreement #2
8 Upstream Agreement #3
9 Upstream Agreement #4
10 Total
(b)
62,050,000 $
36,974,500
452,31 1,650
37,657,050
(d)
$992,922
524,818
8,057,964
670,476
$ 10,236,180
$ s4g,g44 (1)
(c)
0.015841
0.014194
0,017815
0,017805
588,993,200
11 TotalAnnualCost Difference (Line 10 minus Line 5)
(1) See Exhibit No. 4, Line 6, Column (h)
Line
No.
INTERMOUNTAIN GAS COMPANY
Summary of Other Storage Facili$ Costs
Workpaper No. 3
Case No. INT-G-17-05
lntermountain Gas Company
Page 1 of 1
tNT.G.16.03
Annual Cost
(a)
Demand Cosb -
Clay Basin I Reservation
Clay Basin ll Reservation
Clay Basin lll Reservation
Clay Basin I Capacity
Clay Basin ll Capacity
Clay Basin lll Capacity
Total Demand Costs
Rexburg LNG Facility -
Transportation Reservation
Variable Transportation
Total Rexburg LNG Facility Costs
Storage Facilities
tNT.G.16.03
Monthly
Billing Determinant
(b)
266,250
221,880
213,010
31,950,000
26,625,000
25,560,000
84,1 35,000
tNT.G.17.05
Monthly
Billing Determinant
(b)
rNT.G.16.03
Prices
tNT-G-16-03
Monthly Cost
(c)(d)(e)
1
2
3
4
5
b
7
8
rr) $
(1)
(1)
(2)
(2\
(2'.t
(3)
0.285338
0.285338
0.285338
0.002378
0.002378
0.002378
75,971 $
63,311
60,780
75,977
63,314
60,782
91 1,652
759/32
729,360
911,724
759,768
729,384
$
9
10
11
12
$ 400,135 $ 4,801,620
$66,000
22,800
$88,800
$ (1,810,000)
$ 3,080,420
Line
No.
13 Storage Demand Charge Credit
14 Total Costs lncluding Storage Credit
Storage Facilities
(a)
15 Demand Costs -
16 Clay Basin I Reservation
17 Clay Basin ll Reservation
18 Clay Basin lll Reservation
19 Clay Basin I Capacity
20 Clay Basin ll Capacity
21 Clay Basin lll Capacity
22 Total Demand Costs
tNT-G-'t7.05
Prices
tNT-G-17.05
Monthly Cost
rNT.G.17-05
Annual Cost
266,250 (1) $
221,880 ()
213,010 (1)
31,950,000 (2)
26,625,000 e)
25,560,000 (2)
84,135,000 (3)
(c)
0.28s338 $
0.285338
0.285338
0.002378
0.002378
0.002378
(d)(e)
75,971
63,311
60,780
75,977
63,314
60,782
91 1,652
759,732
729,360
911,724
759,768
729,384
$
23 Rexburg LNG Facility -
24 TransportationReservation
25 VariableTransportation
26 Total Rexburg LNG Facility Costs
27 Estimated Storage Demand Charge Credit
28 Total Costs lncluding Storage Credit
29 Total Annual Cost Difference (Line 28 minus Line 14)
(1) Charge Based on Maximum Daily Withdrawal
(2)Charge Based on Maximum Contractual Capacity
(3)Non Additive Billing Determinants; lncludes only Capacity Volumes
(1) See Exhibit No. 4, Line 20, Column (h)
$400,135 $ 4,801 ,620
$66,000
22,800
$88,800
$ (1,810,000)
$ 3,080,420
$(4)
Workpaper No. 4
Case No. INT-G-17-05
lntermountain Gas Company
Page 1 of 1
INTERMOUNTAIN GAS COMPANY
Cost of Gas Allocators
Peak Demand Total
Peak DemandRS GS-1
-Ib)-T
LV.1
2
Peak Demand Per Customer
January 2017 Actual Customers
INT-G-17-05 Peak Demand Therms (Line 2 muliplied by Line 3)
Percent of Total
(1)Contracl Demand
8.01
3't4,365
2,5't8,064
oi"gque
38.54
32,638
1,257,869
32pr0f4
(d)
41,$0 (1)
L0!z%
(e)
3,817,463
100-0000%4
Line
No.Description
Workpaper No. 5
Case No. INT-G-17-05
lntermountain Gas Company
Page 1 of6
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lntermountain Gas Company
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Case No. INT-G-17-05
lntermountain Gas Company
Page 3 of 6
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Case No. INT-G-17-05
lntermountain Gas Company
Page 4 of 6
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Case No. INT-G-17-05
Intermountain Gas Company
Page 5 of 6
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Case No. INT-G-17-05
lntermountain Gas Company
Page 6 of 6
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INTERMOUNTAIN GAS COMPANY
Analysis of LV-l Tariff Block '1, Block 2, and Block 3 Adjustments
Block I Block 2
Therm Sales Therm Sales
Block 3
Therm Sales
Workpaper No. 6
Case No. INT-G-17-05
lntermountain Gas Company
Page 1 of 1
Total
(a)
LV-l Therm Sales (1/1/16 - 12131116)
Blocks 'l and 2 Therm Sales
Percent Therm Sales between Blocks 1 and 2
Proposed Adjustment to LV-1 Tariff (1)
LV-1 Therm Sales (1/'l116 - 12131116)
Annualized Adjustment (Line 4 multiplied by Line 5)
Annualized Adjustment (Line 6)
Percent Annualized Sales included in Block 'l and Block 2
Adjustment to Block 1 and 2 (Line 7 multiplied by Line 8)
Blockl and2Therms
11 Price AdjustmenUTherm Block 1 and 2 (Line 9 divided by Line 10)12 WACOG Commodity Charge Change {2)
13 Total Price AdjustmenUTherm Block I and Block 2
(b)
6,593,577
6,593,577
100.000%
(c)(d)(e)
6,593,577
6,593,577
100.000%
0.0394s
6,593,577
260,',t'tl
260,117
100.000%
260,117
6,593,577
0.0394s
0.00635
(0.03675)
0.00712
$(0.02328)
(0.03675)
_$_q oo2?9_
0
2
3
0
0.000%
4
5
6
I
I
9
10
14
15
'16
17
$
$
$
$
$
$Price Adjustment/Therm Block 3 (3)
WACOG Commodity Charge Change(2)
Eliminate INT-G-1 6-03 Variable Temporary
Total Price AdjustmenUTherm Block 3
(1)See Exhibit No. 4; Line 3'1, Column (k) minus the difference of Line 22, Column (Q minus Line 22, Column (c)
(2) See Exhibit No .4;Line22, Column (f) minus Line 22, Column (c)
(3) See Exhibit No. 6 Column (e), Lines 3 - 6
U
Workpaper No. 7
Case No. INT-G-17-05
lntermountain Gas Company
Page 1 of2
INTERMOUNTAIN GAS COMPANY
Analysis of Lost and Unaccounted For Gas ("L&U")
Line
No.Descri Detail Amount
(a)
Lost and Unaccounted For Gas INT-G-I6-03 (Therms)
(b)(c)
1
2
3
4
Actual Oct 15 - Sep 16 L&U (Iherms)
Actual Oct 15 - Sep 16 Sales
1,743,936
686,736,433
Oct 15 - Sep 16 L&U Factor (Line 2 divided by Line 3)0.254o/o
5 Lost and Unaccounted For Gas INT-G-17-05 (Therms)
6 Projected Oct 16 - Sep 17 L&U (Therms)7 Estimated Oct 16 - Sep 17 Sales
8 Oct 15 - Sep 17 L&U Factor (Line 6 divided by Line 7)
1,600,288
721,063,770 \1)
0.222%
I
10
11
12
13
Lost and Unaccounted For Gas lNT-G-I7-05 (Dollars)
Lost & Unaccounted For Gas (1910-2150)
Estimated Oct 16 - Sep 17 Sales
L&U rate per therm embedded in base rates
Oct 16 - Sep 17 Collection of Lost & Unaccounted for Gas
$ 227,852 a)
721,063,770 t1)
$ 0.00182
1,312,336
14 Projected L&U (Over)/Under Collection (Line 10 minus Line 13)$ (1 ,084,484)
{1) Estimated Oct 16 - Sep 17 Sales (Iherms)
RS
GS-1
lndustrial
TotalSales
238,650,239
123,027,603
359,385,928
721,063,770
(2) See Workpaper No. 5, Page 2, Line 20, Column (c)
Workpaper No. 7
Case No. INT-G-17-05
lntermountain Gas Company
Page 2 of 2
INTERMOUNTAIN GAS COMPANY
Lost and Unaccounted For Gas Statistics(1)
Check for Dead Orders
Year Check for Dead Orders Found Dead
Accounted
Percent Found Dead For Therms
2012
2013
2014
2015
2016
2017
5,089
5,041
6,102
5,974
3,593
2,202
213,590
258,839
251,250
150,762
152,488(2)
513
796
923
893
413
363
Occurrences
Drive Rate Errorc
Accounted For
ThermsYear
2012
2013
2014
2015
2016
2017 e)
3
3
15
10I
8
2,331
26,559
7,201
1,969
3,419
Occurrences
Pressure Errors
Accounted For
ThermsYear
2012
20'13
2014
2015
2016
2017 (2)
15
17
7
10
30
5
(64,400)
10,245
33,429
7,232
270
Gas Loss from Line Breaks, Line Purging and Reliefs
Accounted ForOccurrences ThermsYear
2012
2013
2014
2015
2016
2017 (2)
177
163
187
265
253
138
68,221
66,063
119,291
73,648
231,195
40,463
(') Gas loss resulting from these occurrences becomes accounted for gas
(2) Through June 2017
10%
16Yo
15o/o
15%
11%
160/o
Workpaper No. 8
Case No. INT-G-'I7-05
lntermountain Gas Company
Page 1 of 1
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