20180810Application.pdf

EXECUTIVE OFFICES
I rurenrvrouNTArru Gns Coruperuv
555 SOUTH COLE ROAD o p.O. BOX 7608 . BO|SE, TDAHO 83707 . [phone] o FAX:[phone]
August 10,2018
Ms. Diane Hanian
Commission Secretary
Idaho Public Utilities Commission
472 W . Washington Street
P.O. Box 83720
Boise, ID 83720-0074
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U>oRE: Case No. INT-G-18-02
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 l,
201 8.
Please acknowledge receipt of this filing by stamping and returning a copy of this Application
cover letter to us.
Should you have any suggestions regarding the attached, please don't hesitate to contact me at
[phone].
Very truly yours,
P. McGrath
Director, Regulatory Affairs
Intermountain Gas Company
Enclosure
Mark Chiles
Scott Madison
Preston Carter
cc:
INTERMOUNTAIN GAS COMPANY
CASE NO. INT.G.18.O2
APPLICATION,
EXHIBITS,
AND
WORKPAPERS
In the Matter of the Application of INTERMOUNTAIN GAS COMPANY
For Authority to Change its Prices on October 1, 2018
(October 1,2018 Purchased Gas Cost Adjustment Filing)
Preston N. Carter, ISB No. 8462
Givens Pursley LLP
601 W. Bannock St.
Boise,Idaho 83702
Telephone: [phone]
Attomeys for Intermountain Gas Company
In the Matter of the Application of
INTERMOLTNTAIN GAS COMPANY
for Authority to Change its Prices
BEFORE THE IDAHO PUBLTC UTILITIES COMMISSION
Case No. INT-G-I8-02
APPLICATION
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 ofthe ldaho Public Utilities Commission ("Commission"), hereby requests
authority, pursuant to Idaho Code Sections 6l-307 and 6l-622, to place into effect October 1, 2018
new rate schedules which will decrease its annualized revenues by $24.5 million. Because of changes
in Intermountain's gas related costs, as described more fully in this Application, Intermountain's
eamings will not be impacted as a result of the proposed changes in prices and revenues. Exhibit No.
I is a swnmary of the overall price changes by class of customer and is affached hereto and
incorporated herein by reference. Intermountain's current rate schedules showing proposed changes
are attached hereto and included within Exhibit No. 2 and is incorporated herein by reference.
Intermountain's proposed rate schedules are attached hereto as Exhibit No. 3 and is 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
Preston N. Carter
Givens Pursley LLP
601 W. Bannock St.
Boise,Idaho 83702
APPLICATION - 2
In support of this Application, Intermountain does allege and state as follows:
L
Intermountain is a gas utility, subject to the jurisdiction of the Commission, engaged in the
sale of and distribution of natural gas within the State of Idaho under authority of Commission
Certificate No. 219, issued December 2,1955, as amended and supplemented by Order No. 6564,
dated October 3, 1962.
Intermountain provides natural gas service to the following Idaho communities and counties
and adjoining areas:
Ada County - Boise, Eagle, Garden City, Kuna, Meridian, and Star;
Bannock County - Arimo, Chubbuck,Inkom, Lava Hot Springs, McCammon, and Pocatello;
Bear Lake County - Georgetown, and Montpelier;
Bingham County - Aberdeen, Basalt, Blackfoot, Firth, Fort Hall, Moreland/fuverside, and Shelley;
Blaine County - Bellevue, Hailey, Ketchum, and Sun Valley;
Bonneville County - Ammon, Idaho Falls, Iona, and Ucon;
Canyon County - Caldwell, Greenleaf, Middleton, Nampa, Parma, and Wilder;
Caribou County - Bancroft, Grace, and Soda Springs;
Cassia County - Burley, Declo, Malta, and Raft River;
Elmore County - Glenns Ferry, Hammett, and Mountain Home;
Fremont County - Parker, and St. Anthony;
Gem County - Emmett;
Gooding County - Gooding, and Wendell;
Jefferson County - Lewisville, Menan, Rigby, and Ririe;
Jerome County - Jerome;
Lincoln County - Shoshone;
Madison County - Rexburg, and Sugar City;
Minidoka County - Heyburn, Paul, and Rupert;
Owyhee County - Bruneau, and Homedale;
Payette County - Fruitland, New Plymouth, and Payette;
Power County - American Falls;
Twin Falls County - Buhl, Filer, Hansen, Kimberly, Murtaugh, and Twin Falls;
Washington County - Weiser.
Intermountain's properties in these locations consist of transmission pipelines, liquefied
natural gas storage facilities, a compressor station, distribution mains, services, meters and regulators,
and general plant and equipment.
IL
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 Intermountain from firm transportation
providers including Northwest Pipeline LLC ("Northwest" or'Northwest Pipeline"), 2) a decrease in
Intermountain's Weighted Average Cost of Gas ("WACOG"), 3) an updated customer allocation of
APPLICATION - 3
gas related costs pursuant to the Company's Purchased Gas Cost Adjustment ("PGA") provision, 4)
the inclusion of temporary surcharges and credits for one year relating to natural gas purchases and
interstate transportation costs from Intermountain's deferred gas cost accounts, 5) benefits resulting
from Intermountain's management of its storage and firm capacity rights on various pipeline systems,
6) a portion of the costs accrued related to Intermountain's Case No. INT-G-16-02 General Rate Case
and, 7) customer benefits generated by changes to the federal and state income tax codes.
Intermountain also seeks with this Application to eliminate the temporary surcharges and credits
included in its current prices during the past 12 months, pursuant to Case No. INT-G-17-05. The
aforementioned changes would result in a price decrease to Intermountain's RS, GS-l and LV-l
customers and a price increase to Intermountain's T-3 and T-4 customers.
These price changes are applicable to service rendered under rate schedules affected by and
subject to Intermountain's PGA, initially approved by this Commission in OrderNo.26l09, Case No.
INT-G-95- 1, and additionally approved through subsequent proceedings.
Exhibit No. 4 contains pertinent excerpts from applicable pipeline tariffs. Exhibit No. 5
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. 4 and 5 are attached hereto and incorporated herein by reference.
ilI.
The current temporary and cost of gas related prices of Intermountain are those approved by
this Commission in OrderNo. 33887, Case No. INT-G-I7-05.
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-17-05.
The permanent transportation and storage costs included with this Application reflect a net
increase of $620,781 as compared to those same costs included in Case No. INT-G-I7-
05. Northwest Pipeline transportation and storage costs reflect the reduction in transportation and
storage rates pursuant to FERC Docket No. RP17-346-000 resulting in a reduction of $694,908 in
annual transportation and storage costs to the Company's customers. The Company's upstream
APPLICATION.4
transportation charges increased $1.3 million resulting from rate changes from the Company's
upstream transportation providers in addition to the acquisition of additional upstream capacity. This
same additional capacity puts the Company in a stronger position to leverage the capacity releases
that provide benefits to the Company's customers as well as gain access to gas supplies through
southern Alberta, Canada, which are projected to be some of the lowest cost supplies over the next 5
to 10 years.
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. 5 include $1.8 million in savings from Intermountain's
management of these storage assets.
Exhibit No. 5, Lines I through 20, details the proposed changes to Intermountain's prices
resulting from Intermountain's cost of storage, interstate and upstream capacity from its various
suppliers.
v.
The WACOG reflected in Intermountain's proposed prices is $0.22724 per therm, as shown
on Exhibit No. 5, Line 22, Col. (f1. This compares to $0.26020 per therm currently included in the
Company's tariffs.
Advanced drilling technologies continue to increase drilling efficiencies 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 as compared to even a year ago.
Additionally, the proposed WACOG includes benefits to Intermountain's customers
generated by the Company's management of its significant natural gas storage assets. Because gas
added to storage is procured during the summer season when prices are typically lower than during
the winter, the cost of Intermountain's storage gas is normally less than what could be obtained on
the open market in winter months. Additionally, in an effort to further stabilize the prices paid by our
customers during the upcoming winter period, Intermountain has entered into various fixed price
agreements to lock-in the price for portions of its underground storage and other winter o'flowing"
supplies.
APPLICATION - 5
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 201 8 - 2019 PGA period. Intermountain will employ, in addition to those
fixed price agreements already in place, cost effective price arrangements to further secure the price
of flowing gas embedded within this Application when, and if, those pricing opportunities materialize
in the marketplace.
Intermountain believes that timely natural gas price signals enhance its customers' ability to
make informed and appropriate energy use decisions. The Company is committed to alert customers
to any significant impending price changes before their winter natural gas usage occurs. By
employing the Company's Energy Efficiency programs, customer mailings, the Company's website,
and various media resources, Intermountain will continue to educate its customers regarding the wise
and efficient use of natural gas, billing options available to help manage their energy budget, and any
pending natural gas price changes.
vI.
Pursuant to the Commission's Order in Case No. INT-G-17-05,Intermountain included
temporary credits in its October 7,2017 prices for the principal reason of passing back to its customers
defened gas cost benefits. Line27 of ExhibitNo. 5 reflects the elimination ofthese temporary credits.
VII.
Intermountain's PGA tariff includes provisions whereby Intermountain's proposed prices will
be adjusted for updated customer class sales volumes and purchased gas cost allocations.
Intermountain's proposed prices include a fixed cost collection adjustment pursuant to these PGA
provisions, as outlined on Exhibit No. 6, Line25. The price impact of this adjustment is included on
Exhibit No. 5, Line 28. The Fixed Cost Collection Rate resulting from the adjustment plus the annual
difference in demand charges from Exhibit No. 5, Lines I -20, Col. (h) is shown on Exhibit No. 6,
Lne29. Exhibit No. 6 is attached hereto and incorporated herein by reference.
vIII.
Intermountain proposes to pass through to its customers the benefits that will be generated
from the management of its transportation capacity totaling $5.5 million as outlined on Exhibit No.
8. These benefits include credits from a segmented release of a portion of Intermountain's firm
capacity rights on Northwest Pipeline as well as credits generated from Intermountain's upstream
pipeline capacity. Intermountain proposes to pass back these credit amounts via the per therm credits,
APPLICATION - 6
as detailed on Exhibit No. 8 and included on Exhibit No. 7, Line 1. Exhibit Nos. 7 and 8 are attached
hereto and incorporated herein by reference.
IX.
Intermountain proposes to allocate defened gas costs from its Account No. 1 91 balance to its
customers through temporary price adjustments to be effective during the l2-month period ending
September 30,2019, as follows:
1) Intermountain has deferred fixed gas costs in its Account No. 191. The credit amount
shown on ExhibitNo. 9, Line7, Col. (b) of $15.1 million is attributable to a true-up of the collection
of interstate pipeline capacity costs, the true-up of expense issues previously ruled on by this
Commission, and mitigating capacity release credits generated from the incremental release of
Intermountain's pipeline capacity. Intermountain proposes to true-up these balances via the per therm
debits and credits, as detailed on Exhibit No. 9 and included on Exhibit No. 7, Line2. Exhibit No. 9
is attached hereto and incorporated herein by reference.
2) Intermountain has also deferred in its Account No. 191 a variable gas cost credit of $5.0
million, as shown on Exhibit No. 10, Line 2, Col. (b). This deferred debit is attributable to
Intermountain's variable gas costs since October 1,2017. Intermountain proposes to pass back this
balance via a per therm credit, as shown on Exhibit No. 10, Line 4, Col. (b) and included on Exhibit
No. 7, Line 3.
3) Finally, Intermountain has deferred in its Account No. 191 defened gas costs related to
Lost and Unaccounted for Gas as shown on Exhibit No. 10, Lines 5 through 26, Col. (b). This deferral
results in a per therm increase to Intermountain's sales and transportation customers, as illustrated on
Exhibit No. 10. This per therm increase is included on Exhibit No. 7, Line 3. Exhibit No. l0 is
attached hereto and incorporated herein by reference.
x.
Pursuant to Commission Order No. 32793, Case No. INT-G-13-02, Intermountain has
defened in its Account No. 191 variable gas cost credits associated with sales of liquefied nattral gas
at its Nampa, Idaho facility. Intermountain proposes to pass back this $529,445 sales credit as outlined
on Exhibit No. I 1, Line 7 . Exhibit No. 1 1 is attached hereto and incorporated herein by reference.
APPLICATION - 7
xI.
Pursuant to Commission OrderNo. 33887, Case No. INT-G-17-05, Intermountain established
a regulatory asset to amortize over a five-year period $378,614 related to extemal General Rate Case
costs associated with Case No. INT-G-16-02. Exhibit No. l2 summarizes the amortization of those
costs which are included on Exhibit No. 7, Lines 5 8. 6. Exhibit No. 12 is attached hereto and
incorporated herein by reference.
XII.
Pursuant to Commission Order No. 34073, Case No. GNR-U-18-01, the Company was
directed to credit customers for tax-related benefits it received from January I - May 31, 2018 which
amounted to$2.7 million. Exhibit l3 summarizes the customer class credits associated with this same
tax benefit and is included on Exhibit No. 7, Line 7. Exhibit No. 13 is attached hereto and incorporated
herein by reference.
xIII.
Intermountain has allocated the proposed price changes to each of its customer classes based
upon Intermountain's PGA provision. However, a straight cents per therm price change was not
utilized for the LV-l tariff as no fixed costs are cturently recovered in the tail block of the LV-l tariff.
The proposed changes in the WACOG, and variable deferred debits and credits as outlined on Exhibit
Nos. l0 and I l, are applied to all three blocks of the LV-l tariff. However, all adjustments relating to
fixed costs are applied only to the first two blocks of the LV-l tariff.
xrv.
As outlined on Exhibit No. 2, Page 1, Lines 2l through 29,the T-3 and T-4 tariffs include the
following adjustments: a) the removal of existing temporary price changes; b) the Lost and
Unaccounted for Gas increase as outlined on Exhibit No. 10; c) the LNG Sales Credits are applied to
theT-4tariffasillustratedonExhibitNo. 1l,Line7,Col.(f);d)atemporaryadjustmenttorecovera
portion of Intermountain's Case No. INT-G-16-02 General Rate Case related expenses and; e)
defened credits associated with federal and state income tax reform. The net change from these
aforementioned adjustments result in a rate increase for the Company's T-3 and T-4 customers.
APPLICATION - 8
xv.
The proposed price changes herein requested among the classes of service of Intermountain
reflect a just, fair, and equitable pass-through of changes in gas related costs to Intermountain's
customers.
xVI.
This Application has been brought to the attention of Intermountain's customers through a
Customer Notice and by a Press Release sent to daily and weekly newspapers, and major radio and
television stations in Intermountain's service area. The Press Release and Customer Notice are
attached hereto and incorporated herein by reference. Copies of this Application, its Exhibits, and
Workpapers have been provided to those parties regularly intervening in lntermountain's rate
proceedings.
xvII.
Intermountain requests that this matter be handled under modified procedure pursuant to
Rules 201-204 of the Commission's Rules of Procedure. Intermountain stands ready for immediate
consideration of this matter.
APPLICATION - 9
XVIIL
WHEREFORE, Intermountain respectfully petitions the ldaho Public Utilities Commission as
follows:
a. That the proposed rate schedules herewith submitted as Exhibit No. 3 be approved without
suspension and made ef[ective as of October l, 2018 in the manner shown on Exhibit No. 3.
b. That this Application be heard and acted upon without hearing under modified procedure,
and
c. For such other relief as this Commission may determine proper herein.
DATED at Boise, Idaho, this 10th day of August, 2018.
INTERMOUNTAIN GAS COMPANY Givens Pursley LLP
By (By
Preston N. Carter
Attorney for Intermountain Gas CompanyAffairs
APPLICATION - IO
/
CERTIFICATE OF MAILING
I HEREBY CERTIFY that on this 10th day of August, 2018, I served a copy of the
foregoing Case No. INT-G-I8-02 upon:
Ed Finklea
Alliance of Western Energy Consumers
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,ID 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 - 1I
EXHIBIT NO. 1
CASE NO. INT.G.18.O2
INTERMOUNTAIN GAS COMPANY
SUMMARY OF PRICE CHANGES
(2 pages)
Exhibit No. 1
Case No. INT-G-18-02
lntermountain Gas Company
Page 'l of 2
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Exhibit No. 1
Case No. INT-G-18-02
lntermountain Gas Company
Page 2 ol 2
Line No.
(a)
Deferrals:
INT-G-1 7-05 Temporanes Removed
Add INT-G-1 &02 Temporaries:
Fixed Deferred Gas Costs
Variable Defened Gas Costs
Lost & Unaccounted For Gas Costs
LNG Sales Credit
Defened General Rate Case Costs
Tax Reform Defenal
Total Temporaries Added
Total Defenals
Base Rate Price Change:
Fixed Cost Changes:
NWP Full Rate Reservation
NWP Discounted Reservation
Upstream Full Rate
Upstream Discounted
SGS & LS
Other Storage Facility
Total Fixed Cost Change
Changes in WACOG
Reallocation of Fixed Costs
II{TERMOUNTAIN GAS COMPANY
ANALYSIS OF INT.G-18.{'2 PRICE CHAI{GE
Amount
$ (20,553,640 {'z)
(5,040,702) p)
786,421 tl)
(529,445) 6)
66,986 (6)
(2,731,84\ t7)
$ (619,134) {8)
(44,1 26) p)
2,9'13,851 (10)
(1,598,162) (11)
(31,M8) {14
(13)
620,781
(11,955,M9) (11)
(6,034,11o) (15)
Total
(b)(c)
20,840,697 (r)
I
2
3
4
(
6
7
o
I
10
11
12
13
14
15
'16
17
18
19
20
21
22
23
t4
$
(28,002,226)
$ (7,161,529)
25
26
Total Base Rate Price Changes (17,368,378)
Total Annual Price Change $ (24,529,907)
Annual Price Change per Exhibit No, 1, Page 1
Difference Due to Rounding
$ (24,529,$1)(16)
$(576)
{') See WorkpaperNo. S, Line2, Columns (b) - (0 times Exhibit No, 1, Page 1, Lines 2-4,6& 8, Column (b)(') See Exhibit N0.8, Line 3, Column (b), plus Exhibit No.9, Line 7, Cotumn (b)(') See Exhibit No. '10, Line 2, Column (b)(o) See Exhibit No, 10, Line 10 plus Line 18, Column (b)(u) See Exhibit No. 1'1, Line 5, Column (b)(u) See Exhibit No. 12, Page 1, Line 6, Cdumn (b) plus Exhibit No, 12, Page 2, Line 4, Cotumn (b)0 See Exhibit No, 13, Line 1, Column (b)(8) See Exhibit No. 5, Line 3, Column (h)(e) See Exhibit No. 5, Line 4, Column (h)(r0) See Exhibit N0.5, Line 5, Column (h)
{11) See Exhibit No, 5, Line 6, Column (h)
t12) See Exhibit No. 5, sum of Lines I - '19, Column (h)
(13) See Exhibit N0.5, Line 20, Column (h)(11) See Exhibit No. 5,-line22,Column (h)(15) See Exhibit No. 5, Line 28, Columns (i) - (k), times Line 24, Columns (i)- (k)(16) See Exhibil No. 1, Page 1, Line 10, Column (e)
Description
EXHIBIT NO.2
CASE NO. INT.G.18.O2
INTERMOUNTAIN GAS COMPANY
CURRENT TARIFFS
Showing Proposed Price Changes
(10 pages)
Exhibit No. 2
Case No. INT-G-18-02
lntermountain Gas Company
Page I of 10
Line
No.Rate Class
INTERMOUNTAIN GAS COMPANY
Comparison of Proposed October 1,2018 Prices
To June 1,2018 Prices
Prices per
Case No. GNR-U-18.01
Order No. 34073
Proposed
Adjustment
Proposed
Oclober 1, 2018
Prices
(a)(b)(c)(d)
0.57231 $(0.06675) $0.505561RS
GS-1
$
2
3
4
5
b
7
I
o
Block 1
Block 2
Block 3
Block 4
CNG Fuel
Block 1
Block 2
0.58312
0.55964
0.53697
0.46841
0.53697
0.46841
0.56864
0.58312
0.55964
0.53697
0 46841
0.30000
0.37581
0.35792
0.26956
0.03790
0.01506
0.00515
0.28092
0.02395
0.00847
0.00260
(0.07049)
(0.07049)
(0.0704s)
(0.07049)
(0.07049)
(0.0704e)
(0.06675)
(0.0704e)
(0.0704e)
(0.07049)
(0.07049)
(0.06852) (3)
(0.06852) (3)
(0.05446) (1)
0.00083 6)
0.00083 (5)
0.000ffi F)
0.00647 (6)
0.51263
0.48915
0.46648
0 39792
0.46648
0.39792
0.50189
0.51263
0.48915
0.46648
0.39792
0.30000
0.30729
0.28940
0.21510
0.03873
0.01589
0.00598
0.28739
0.02395
0.00847
0.00260
'lo ls'R (1)
ls.c (2)11
12
13
14
15
16
17
18
19
20
Block 1
Block 2
Block 3
Block 4
Demand Charge
Block 1
Block 2
Block 3
Block 1
Block 2
Block 3
Demand Charge
Block 1
Block 2
Block 3
21
22
23
24
25
26
27
28
29
LV.1
T-3
T-4
(1) The lS-R price is based on the RS price and receives the same PGA ad.justments
(') The lS-C price is based on the GS-1 price and receives the same PGA adjustments
(3) See Workpaper No. 6, Line 13, Column (e)
(a) See Workpaper No. 6, Line 17, Column (e)
(5) Remove INT-G-17-05 temporary from Workpaper No. 8, Line 5, Column (e) plus temporary
from Exhibit No. 7 Line 8, Column (e)
(6) Remove INT-G-17-05 temporary from Workpaper No. 8, Line 5, Column (fl plus temporary
from Exhibit No. 7 Line 8, Column (f)
Exhibit No. 2
Case No. INT-G-18-02
lntermountain Gas Company
Page 2 of 10
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l.P.U.C. Gas Tariff
Rate Schedules
+hir€l Revised Fourth Sheet No. 1 (Page 1 of 1)
Name Intermountain Gas Gompanyof Utility
Exhibit No. 2
Case No. INT-G-'18-02
lntermountain Gas Company
Page 3 of 10
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 Effectivellafrgffi funef.ffi
P€+€r+lJ.{O+i}
Diane M. Hanian Secretary
$e€5426) (s0.07741)
$€*€e2e $0.22724
$€'J€964 $0.18901
$0.16305
Customer Charge:
Per Therm Charge:
*lncludes the following:
Cost of Gas:
$5.50 per bill
$+6723+* $0.50556
'l) Temporary purchased gas cost adjustment
2) Weighted average cost of gas
3) Gas transportation cost
Distribution Cost:
EE Charge:$0.00367
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for the cost of purchased gas as provided for in Rate Schedule PGA.
This adjustment is incorporated into the calculation of the Cost of Gas stated on customer bills.
ENERGY EFFICIENCY CHARGE ADJUSTMENT:
This tariff is subject to an adjustment for costs related to the Company's Energy Efficiency program as
provided for in Rate Schedule EEC. The Energy Efficiency Charge is separately stated on customer bills.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the Company's Tariff, of
which this rate schedule is a part.
rssued by: lntermountain Gas Company
By: Michael P. Mccrath Title: Director - Regulatory Affairs
Effective: JuneJ#{€ October 1. 2018
l.P.U.C. Gas Tariff
Rate Schedulesfiffi Revised Fiftv-Eiqhth Sheet No. 3 (Page 1 of 2)
Name lntermountain Gas Companyof Utility
Exhibit No. 2
Case No. INT-G-18-02
lntermountain Gas Company
Page 4 of 10
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
IDAHO PUBLIC UT!LITIES COMMISSIONApproved EffectiveilafrC,{.l.le48 Jsne{,r2e48
P€iF€lilJ4e7il
Diane M. Hanian Secretary
$€5S€{+- $0.51263
$€€69e$- $0.48915
$e.63697* $0.46648
$9,169.t1* $0.39792
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 @
*lncludes the following
Cost of Gas:
Distribution Cost:
Block One:
Block Two:
Block Three:
Block Four:
Block One:
Block Two:
Block Three:
Block Four:
$e€€e€q ($0.07698)
$g3€e2e $0.22724
$g3e{A7 $0.17772
1 ) Temporary purchased gas cost adjustrnent
2) Weighted average cost of gas
3) Gas transportation cost
First
Next
Next
Over
First
Next
Next
Over
$0.1 8465
$0.16117
$0.1 3850
$0.06994
lssued by: lntermountain Gas Company
By: Michael P. Mccrath Title: Director - Regulatory Affairs
Eifective: Jcnet-+e+g October 1. 2018
l.P.U.C. Gas Tariff
Rate Schedules
fi$fseveng Revised Fiftv-Eiohth Sheet No. 3 (Page 2 of 2)
Name lntermountain Gas Companyof Utility
Exhibit No. 2
Case No. INT-G-18-02
lntermountain Gas Company
Page 5 of 10
Rate Schedule GS-1
GENERAL SERVIGE
(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 @Ovel|0,000 therms per bill @
IDAHO PUBLIC UTILITIES COMMISSIONApproved EffectiveUafel+Cff fueefrfOff
Per C),|* 3{073
Diane M. Hanian Secretary
$es3€€[z. $0.46648
$€14€84+* $0.39792
$e€€€eq ($0.076e8)
$0+€€2e $0.22724
$e3€{+7 s0.17772
$0.1 38s0
$0.06994
*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.
BILLING ADJUSTMENTS:
Any GS-'l 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 incuned to serve the customer during the
GS-1 service period not paid by the customer during the time the customer was using GS-1 service.
Any GS-1 customer who leaves the GS-1 service will have refunded to them, upon exiting the GS-1
service, any excess gas commodity or transportation payments made by the customer during the time
they were a GS-1 customer.
tssued by: lntermountain Gas Company
By: Michael P. Mccrath Title: Director - Regulatory Affairs
Effective: Jsn€#€{8 October 1. 2018
1.
LP.U.C. Gas Tariff
Rate Schedules
Feurteenth Revised Fifteenth SheetNo. 4 (Paae1ol2\
Name
of Utility !ntermountain Gas Gompany
Exhibit No. 2
Case No. INT-G-18-02
lntermountain Gas Company
Page 6 of 10
Rate Schedule lS-R
RESIDENTIAL !NTERRUPTIBLE SNOWMELT SERV!CE
APPLICABILITY:
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 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 Company can reasonably accommodate said relocation and Customer agrees to
pay all related costs.
RATE
Monthly minimum charge is the Customer Charge
$5.50 per bill
$e#6€e$. $0.50189
1 ) Temporary purchased gas cost adjustment
2) Weighted average cost of gas
3) Gas transportation cost
IDAHO PUBLIC UTILITIES COMMlSSIONApproved Effective$*Vef#+e fsnefrfgfe
P€F€rilJ4e73
Diane M. Hanian Secretary
($e-€€.426) (s0.07741)
$0+€e2e s0.22724$€ffi4 s0.18901
Customer Charge:
Per Therm Charge:
*lncludes the following
Cost of Gas:
Distribution Cost:$0.16305
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company's Purchased
Gas Cost Adjustment Schedule.
tssued by: lntermountain Gas Gompany
By: Michael P. Mccrath Title: Director - Regulatory Affairs
Effective: June-l#+S Oclober 1. 2018
Exhibit No. 2
Case No. INT-G-18-02
lntermountain Gas Company
Page 7 of 10
l.P.U.C. Gas Tariff
Rate Schedules
F€udeen{h Revised Fifteenth Sheet No. 5 (Paqe 1 of2)
Name
of Utilitv lntermountain Gas Gompany
IDAHO PUBLIC UTILITIES COMMISSIONApproved Effectivell*y++Aefe fuae-t#Off
P€#€+LA.{$I3
Diane M. Hanian Secretary
$€ss€{+- $0.51263
$€s€ger $0.48915
$e€3€97'50.46648
$€1468++* S0.39792
Rate Schedule lS-G
SMALL COMMERICAL INTERRUPTIBLE SNOWMELT SERVICE
APPLICABILITY:
Applicable to any customer otherwise eligible to receive gas service under Rate Schedule GS-l 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 intenuptible at the sole discretion of the
Company.
FACILITY REIMBURSEMENT GHARGE:
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, priorto 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
*lncludes the following
Cost of Gas:
Distribution Charge
Block One:
Block Two:
Block Three:
Block Four:
Block One:
Block Two:
Block Three:
Block Four:
200 therms per bill @
'l ,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 @
$e€6e€q ($0.07698)
$e*€e2e s0.22724
s€i?+147 $0.17772
$0.18465
$0.161 17
$0.1 38s0
$0.06994
1 ) Temporary purchased gas cost adjustment
2) Weighted average cost of gas
3) Gas transportation cost
First
Next
Next
Over
First
Next
Next
Over
tssued by: lntermountain Gas Company
By: Michael P. Mccrath
Effective: Jun€i+2048
Title: Director - Regulatory Affairs
l.P.U.C. Gas Tariff
Rate Schedules
si*ratriflh Revised Sixtv-Sixth Sheet No. 7 (Paoe 1 of 2)
Name
of Utilitv lntermountain Gas Company
Exhibit No. 2
Case No. INT-G-18-02
lntermountain Gas Company
Page 8 of 10
IDAHO PUBLIC UTILITIES COMMISSIONApproved Effectiveilafal#+e funefrfgf8
Per e,N, 31073
Diane M. Hanian Secretary
Rate Schedule LV-l
LARGE VOLUME FIRM SALES SERVICE
AVAILABILITY
Available at any mutually agreeable delivery point on the Company's distribution system to any existing
customer receiving service under the Company's rate schedule LV-1 or any customer not previously served
under this schedule whose usage does not exceed 500,000 therms annually, upon execution of a one-year
minimum written service contract for firm sales service in excess of 200,000 therms per year.
MONTHLY RATE:
Demand Charge:
Per Therm Charge:
$0.30000 per MDFQ therm
Block One:
Block Two:
Block Three:
Block One:
Block Two:
Block Three
First
Next
Over
250,000 therms per bill @
500,000 therms per bill @
750,000 therms per bill @
$0,37581. $0.30729$ffi $0.28940
$0*€856- $0.2'1510
*lncludes the following
Cost of Gas:
Distribution Cost:
1 ) Temporary purchased gas cost adjustment
Block One and Two
Block Three
2) Weighted average cost of gas
3) Gas transportation cost (Block One and Two only)
($€€{€84) ($0.04583)
$9€0€29 ($0.01521)
$e3€€2e $0.22724
$+.+e645 $0.09s88
First
Next
Over
250,000 therms per bill @ $0.03000
500,000 therms per bill @ $0.01211
750,000 therms per bill @ $0.00307
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 by: !ntermountain Gas Gompany
By: Michael P. Mccrath
Effective: Jrrf,€-{JO4€ October 1. 2018
Title: Director - Regulatory Affairs
1.
2.
Exhibit No. 2
Case No. INT-G-18-02
lntermountain Gas Company
Page 9 of 10
l.P.U.C. Gas Tariff
Rate Schedules
Si*eesth Revised Seventeenth Sheet No. 8 (Paoe 1 of 2)
Name
of Utility !ntermountain Gas Company
!DAHO PUBLIC UTILITIES COMMISSIONApproved EffectiveUafS+,-?g+8 fun++regf+
Per e,N, 31073
Diane M. Hanian Secretary
Rate Schedule T-3
INTERRUPTIBLE DISTRIBUTION TRANSPORTATION SERVICE
AVAILABILITY:
Available at any point on the Company's distribution system to any customer upon execution of a one year
minimum written service contract.
MONTHLY RATE:
Per Therm Charge: Block One: First 100,000 therms transported @ $0€379e- $0.03873
Block Two: Next 50,000 therms transported @ $0€{€06- $O.OlSB9
Block Three: Over 150,000 therms transported @ $e€O+l€- $0.00598
*lncludes lemporary purchased gas cost adjustment of{$0€00€3} $0.00020
ANNUAL MINIMUM B!LL:
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 GONDITIONS:
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 T-4 customer electing this schedule may concurrently utilize Rate Schedule T-3 on the
same or contiguous property.
tssued by: lntermountaan Gas Company
By: Michael P. McGrath _ Title: Director - Regulatory Affairs
Eifective: Jrn€-li?e€ October 1. 2018
2.
3.
4.
5.
6.
7.
l.P.U.C. Gas Tariff
Rate Schedules
Fi*e€nth Revised Sixteenth Sheet No. I (Paqe 'l of 2)
Name
of Utilitu lntermountain Gas Company
Exhibit No. 2
Case No. INT-G-18-02
lntermountain Gas Company
Page 10 of 10
IDAHO PUBLIC UTILITIES COMMISSIONApproved EffectiveilafrS4ff fune-+fgC8
P€#€rilJ4e7il
Diane M. Hanian Secretary
Rate Schedule T-4
FIRM DISTRIBUTION ONLY TRANSPORTATION SERVICE
AVAILABILIry:
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:$S*8e92 per MDFQ therm* $0.28739
Per Therm Charge:Block One:
Block Two:
Block Three:
First
Next
Over
250,000 therms transported @ $0.02395
500,000 therms transported @ $0.00847
750,000 therms transported @ $0.00260
3.
4.
5.
*lncludes temporary purchased gas cost adjustment of $eig€€8) ($0.01261)
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
(MDFO), which will be stated in and in effect throughout the term of the service contract.
The monthly demand charge will be equal to the MDFQ times the demand charge rate. Demand
charge relief will be afforded to those T4 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 T4
on the customer's same or contiguous property.
tssued by: lntermountaan Gas Company
By: Michael P. Mccrath Title: Director - Regulatory Affairs
Eifective: Jene.+.4{€ October 1. 2018
6.
EXHIBIT NO.3
CASE NO. INT.G-18-02
INTERMOUNTAIN GAS COMPANY
PROPOSED TARIFFS
(8 pages)
l.P.U.C. Gas Tariff
Rate Schedules
Fourth Revised Sheet No. 1 (Page 1 of 1)
Name
of Utility Intermountain Gas Company
Exhibit No. 3
Case No. INT-G-I8-02
lntermountain Gas Company
Page 1 of8
Rate Schedule RS
RESIDENTIAL SERVICE
APPLIGABILITY:
Applicable to any customer using natural gas for residential purposes.
RATE:
Monthly minimum charge is the Customer Charge.
Customer Charge:
Per Therm Charge:
*l ncludes the following:
Cost of Gas:
$5.50 per bill
$0.50556.
1) Temporary purchased gas cost adjustment
2) Weighted average cost of gas
3) Gas transportation cost
($0.07741)
$0.22724
$0.1 8901
Distribution Cost:
EE Charge:
$0.16305
$0.00367
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for the cost of purchased gas as provided for in Rate Schedule PGA.
This adjustment is incorporated into the calculation of the Cost of Gas stated on customer bills.
ENERGY EFFICIENCY CHARGE ADJUSTMENT:
This tariff is subject to an adjustment for costs related to the Company's Energy Efficiency program as
provided for in Rate Schedule EEC. The Energy Efficiency Charge is separately stated on customer bills.
SERVICE CONDITIONS
All natural gas service hereunder is subject to the General Service Provisions of the Company's Tariff, of
which this rate schedule is a part.
rssued by: lntermountain Gas Gompany
By: Michael P. McGrath Title: Director - Regulatory Affairs
Effective: October 1, 2018
l.P.U.C. Gas Tariff
Rate Schedules
Fifty-Eighth Revised Sheet No.3 (Page 1 of 2)
Name
of Utility lntermountain Gas Company
Rate Schedule GS-l
GENERAL SERVICE
APPLICABILITY:
Applicable to customers whose requirements for natural gas do not exceed 2,000 therms per day, at any point
on the Company's distribution system. Requirements in excess of 2,000 therms per day may be 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:
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 @
Exhibit No. 3
Case No. INT-G-18-02
lntermountain Gas Company
Page 2 of 8
$0.51263.
$0.48915.
$0.46648.
$0.39792.
($0.076e8)
$0.22724
$0.17772
$0.1 846s
$0.161 1 7
$0.1 3850
$0.06994
1) Temporary purchased gas cost adjustment
2) Weighted average cost of gas
3) Gas transportation cost
First
Next
Next
Over
First
Next
Next
Over
tssued by: Intermountain Gas Company
By: Michael P. McGrath Title: Director - Regulatory Affairs
Effective: October 1, 2018
l.P.U.C. Gas Tariff
Rate Schedules
Fifty-Eighth Revised Sheet No.3 (Page 2of 2)
Name
of Utility !ntermountain Gas Company
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 @
Exhibit No. 3
Case No. INT-G-18-02
lntermountain Gas Company
Page 3 of 8
$0.46M8.
$0.39792.
($0.076e8)
$0.22724
$0.17772
$0.1 3850
$0.06994
*l ncludes 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 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.
BILLING ADJUSTMENTS:
Any GS-1 customerwho leaves the GS-1 service will pay to lntermountain Gas Company, upon exiting
the GS-1 service, all gas and transportation related costs incurred to serve the customer during the
GS-1 service period not paid by the customer during the time the customer was using GS-1 service.
Any GS-1 customer who leaves the GS-1 service will have refunded to them, upon exiting the GS-1
service, any excess gas commodity or transportation payments made by the customer during the time
they were a GS-1 customer.
tssued by: lntermountain Gas Company
By: Michael P. McGrath Title: Director - Regulatory Affairs
Effective: October 1, 2018
1.
l.P.U.C. Gas Tariff
Rate Schedules
Fifteenth Revised Sheet No. 4 (Page 1 of2)
Name
of Utility lntermountain Gas Company
Exhibit No. 3
Case No. INT-G-18-02
lntermountain Gas Company
Page 4 of 8
Rate Schedule lS-R
RESIDENTIAL INTERRUPTIBLE SNOWMELT SERVICE
APPLICABILITY:
Applicable to any residential customer otherwise eligible to receive service under Rate Schedule RS who
has added 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 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:
*lncludes the following:
Cost of Gas:
$5.50 per bill
$0.50189.
1) Temporary purchased gas cost adjustment
2) Weighted average cost of gas
3) Gas transportation cost
($0.07741)
$0.22724
$0.18901
Distribution Cost:$0 16305
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: October 1, 2018
l.P.U.C. Gas Tariff
Rate Schedules
Fifteenth Revised Sheet No. 5 (Paqe 1 of2)
Name
of Utilitv lntermountain Gas Company
*lncludes the following:
Cost of Gas:
Distribution Charge:
Block One:
Block Two:
Block Three:
Block Four:
Block One:
Block Two:
Block Three:
Block Four:
200 therms per bill @
1,800 therms per bill @
8,000 therms per bill @
10,000 therms per bill @
200 therms per bill @
1,800 therms per bill @
8,000 therms per bill @
10,000 therms per bill @
Exhibit No. 3
Case No. INT-G-18-02
lntermountain Gas Company
Page 5 of 8
$0.51263.
$0.48915.
$0.46648.
$0.39792.
($0.076e8)
$0.22724
$o.'17772
$0.18465
$0.16117
$0.13850
$0.06994
Rate Schedule lS-C
SMALL COMMERICAL INTERRUPTIBLE SNOWMELT SERVICE
APPL!CAB!LITY:
Applicable to any customer otherwise eligible to receive gas service under Rate Schedule GS-1 who has
added natural gas snowmelt equipment after 61112010. The intended use of the snowmelt equipment is to
melt snow and/or ice on sidewalks, driveways or any other similar appurtenances. Any and all such
applications meeting the above criteria will be subject to service under Rate Schedule lS-C and will be
separately and individually metered. All service hereunder is interruptible at the sole discretion of the
Company.
FACILITY REIMBURSEMENT CHARGE
All new interruptible Snowmelt service customers are required to pay for the cost of the Snowmelt meter set
and other related facility and equipment costs, prior to the installation of the meter set. Any request to alter
the physical location of the meter set and related facilities from Company's initial design may be granted
provided, however, the Company can reasonably accommodate said relocation and Customer agrees to pay
all related costs.
RATE:
Monthly minimum charge is the Customer Charge.
Customer Charge:
Per Therm Charge:
$9.50 per bill
1) Temporary purchased gas cost adjustment
2) Weighted average cost of gas
3) Gas transportation cost
First
Next
Next
Over
First
Next
Next
Over
tssued by: Intermountain Gas Company
By: Michael P. McGrath Title: Director - Regulatory Affairs
Effeclive: October 1, 201 8
LP.U.C. Gas Tariff
Rate Schedules
Sixty-Sixth Revised Sheet No. 7 (Page 1 of2)
Name
of Utility !ntermountain Gas Company
Rate Schedule LV-1
LARGE VOLUME FIRM SALES SERVICE
AVAILABILITY:
Available at any mutually agreeable delivery point on the Company's distribution system to any existing
customer receiving service under the Company's rate schedule LV-1 or any customer not previously served
under this schedule whose usage does not exceed 500,000 therms annually, upon execution of a one-year
minimum written service contract for firm sales service in excess of 200,000 therms per year.
MONTHLY RATE:
Demand Charge: $0.30000 per MDFQ therm
Per Therm Charge:250,000 therms per bill @
500,000 therms per bill @
750,000 therms per bill @
Exhibit No. 3
Case No. INT-G-18-02
lntermountain Gas Company
Page 6 of 8
$0.30729.
$0.28940.
$0.21510.
Block One:
Block Two:
Block Three:
Block One:
Block Two:
Block Three:
First
Next
Over
*lncludes the following
Cost of Gas: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)
($0.04583)
($0.01521)
$0.22724
$0.09588
$0.03000
$0.01211
$0.00307
Distribution Cost:
PURCHASED GAS GOST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company's Purchased
Gas Cost Adjustment Schedule.
SERVICE CONDIT!ONS:
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 by: lntermountain Gas Company
By: Michael P. McGrath Title: Director - Regulatory Affairs
Effective: October 1, 2018
First
Next
Over
250,000 therms per bill @
500,000 therms per bill @
750,000 therms per bill@
2.
1.
l.P.U.C. Gas Tariff
Rate Schedules
Seventeenth Revised Sheet No.8 (Paqe 1 of 2)
Name
of Utility lntermountain Gas Company
Exhibit No. 3
Case No. INT-G-18-02
lntermountain Gas Company
Page 7 of 8
Rate Schedule T-3
INTERRUPTIBLE DISTRIBUTION TRANSPORTATION SERVICE
AVAILABILITY:
Available at any point on the Company's distribution system to any customer upon execution of a one year
minimum written service contract.
MONTHLY RATE:
Per Therm Charge:Block One:
Block Two:
Block Three:
First
Next
Over
100,000 therms transported @ $0.03873.
50,000 therms transported @ $0.01589.
150,000 therms transported @ $0.00598.
2
*lncludes temporary purchased gas cost adjustment of $0.00020
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 customerwhich have not been nominated and accepted for delivery by the interstate pipeline.
An existing T-4 customer electing this schedule may concurrently utilize Rate Schedule T-3 on the
same or contiguous property.
tssued by: lntermountain Gas Company
By: Michael P. McGrath Title: Director - Regulatory Affairs
Effective: October 1, 2018
J
4
5
6
7
l.P.U.C. Gas Tariff
Rate Schedules
Sixteenth Revised Sheet No.9 (Pase 1 of 2\
Name
of Utility lntermountain Gas Company
Exhibit No. 3
Case No. INT-G-18-02
lntermountain Gas Company
Page 8 of 8
Rate Schedule T4
FIRM DISTRIBUTION ONLY TRANSPORTATION SERVICE
AVAILABILITY:
Available at any mutually agreeable delivery point on the Company's distribution system to any customer
upon execution of a one year minimum written service contract for firm distribution transportation service in
excess of 200,000 therms per year.
MONTHLY RATE
Demand Charge:$0.28739 per MDFQ therm*
Per Therm Charge:Block One:
Block Two:
Block Three
First
Next
Over
250,000 therms transported @ $0.02395
500,000 therms transported @ $0.00847
750,000 therms transported @ $0.00260
*lncludes temporary purchased gas cost adjustment of ($0.01261)
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company's Purchased
Gas Cost Adjustment Schedule.
SERVIGE GONDITIONS:
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
(MDFO), which will be stated in and in effect throughout the term of the service contract.
The monthly demand charge will be equal to the MDFQ times the demand charge rate. Demand
charge relief will be afforded to those 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 T4
on the customer's same or contiguous property.
tssued by: lntermountain Gas Company
By: Michael P. McGrath Title: Director - Regulatory Affairs
Effective: October 1, 2018
3
4
5
6
EXHIBIT NO.4
CASE NO. INT.G.18.O2
INTERMOUNTAIN GAS COMPANY
PERTINENT EXCERPTS PERTAINING TO INTERSTATE PIPELINES AND RELATED
FACILITIES
(35 pages)
Exhibit No. 4
Case No. INT-G-18-02
lntermountain Gas Company
Page 1 of35
NORTHWEST PIPELINE LLC
(10 pages)
Exhibit No. 4
Case No. INT-G-18-02
lntermountain Gas Company
Page 2 of 3520170818-3011- FERC PDF (Unofficial) 08/1-8/20]-7
160 FERC fl 61,008
FEDERAL ENERGY REGULATORY COMMISSION
WASHINGTON, D.C.20426
August 18,2017
In Reply Refer To:
Northwest Pipeline LLC
Docket No. RP I 7-346-000
Northwest Pipeline LLC
295 Chipeta Way
P.O. Box 58900
Salt Lake City, UT 84158-0900
Attention: Laren Gertsch
Director, Rates & Tariffs
Reference: Petition for Approval of a Stipulation and Settlement Agreement
Dear Mr. Gertsch:
l. On January 23,2017, Northwest Pipeline LLC (Northwest) petitioned the
Commission for approval of a Stipulation and Settlement Agreement (2017 Settlement),
in lieu of its obligation to file a Natural Gas Act (NGA) general section 4 rate case.'
Northwest states that on April26,2012, the Commission approved its Petition for
Approval of Settlement in Docket No. RP l2-490-000 (2012 Settlement) which satisfied
its requirement to file a NGA general section 4 rate case. In the instant petition,
Northwest states that section 14.4 of the 2012 Settlement requires it to file an NGA
general section 4 rate case not later than July I ,2017 , for rates to become effective not
later than January l, 2018, unless Northwest has entered into a pre-filing settlement
effectively satisfying the NGA general section 4 rate case filing requirement.2 Northwest
states that the Settling Parties3 agree that if this 2017 Settlement is timely approved by
' The filing is made pursuant to Rule 207(a)(5) of the Commission's Rules of
Practice and Procedure. l8 C.F.R. $ 385.207(a)(5) (2017).
2 Northwest Pipeline GP,l39 FERC fl 61,071 (2012).
3 Article II of the 2017 Settlement defines Settling Parties as (a) any party
identified in Appendix A of the 2017 Settlement or (b) any party or shipper not identified
(continued)
Exhibit No. 4
Case No. INT-G-18-02
lntermountain Gas Company
Page 3 of 35201-70818-3011 FERC PDF (Unofficial) 08/1-8/2017
Docket No. RP I 7-346-000 1
the Commission, Northwest will have satisfied the requirement to make a rate filing in
2017 as to the Settling Parties. Northwest states that the Settling Parties have
successfully resolved their issues through the 2017 Settlement in a practical and carefully
constructed fashion, eliminating the need for testimony, discovery, hearing and briefing
of the matters resolved. Northwest states that the avoidance of litigation is a valuable
outcome, benefiting the Settling Parties, the Commission and the public interest.
Northwest states that it does not expect the 2017 Settlement to be contested because
100 percent of the shippers who actively participated in the settlement discussions
support this 2017 Settlement. Northwest states that92 percent of Northwest's long-term
firm transportation and storage capacity shippers support and 8 percent do not oppose the
2017 Settlement.
2. In a separate filing made on March 29,2017 (March Filing) in Docket No. RP17-
567-000, Northwest states that three days after Northwest filed its 2017 Settlement, the
Commission was left without a quorum. Northwest states that due to the lack of a
quorum, no action has been taken by the Commission to approve the uncontested2}lT
Settlement and that Commission staff lacks the authority to approve the 2017 Settlement
pursuant to the Order Delegating Further Authority to Staff in Absence of Quorum.a
Consequently, Northwest filed revised tariff records in the March Filing to extend the
time by which it must file an NGA general section 4 rute case and otherwise amend
(l) section 14.4 of the 2012 Settlement; and (2) Article X and sections l4.l and 14.2 of
the2017 Settlement. Northwest states that the extension of time is necessary to preserve
the rate reductions agreed to in the 2017 Settlement and accommodate the delay in
Commission action on the 2017 Settlement due to a lack of quorum. The March Filing
was accepted on April l2,2on.s
3. The Commission by this letter order approves the2017 Settlement to be effective
according to its terms,6 and directs Northwest to file tariff records consistent with the
proforma tariff records included in Appendix F of the 2017 Settlement, to be effective
January 1,2018.
in Appendix A that either supports, or does not oppose the 2017 Settlement as a whole
and/or any of its underlying provisions.
n Agrncy Operations in the Absence of a Quorum,l5S FERC'1T61,135 (2017).
s Northwest Pipeline LLC,Docket No. RPlT-567-000 (Apr 12,2Ol7) (delegated
letter order) (April 2017 Order).
6 According to Article XI, the 2017 Settlement will become effective on the date
that an order approving the 2017 Settlement becomes a final order.
Exhibit No. 4
Case No. INT-G-18-02
lntermountain Gas Company
Page 4 of 3520170818-3011- FERC pDF (Unofficial) 08/a8/2017
Docket No. RP I 7-346-000 -3-
4. Public notice of the 2017 Settlement filing was issued on January 24,2017.
Interventions and protests were due as provided in section 154-210 of the Commission's
regulations (18 C.F.R. $ 154.210 (2017)). Pursuant to Rule 214 (18 C.F.R. $ 385.214
(2017)), 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 comments in opposition to the settlement were filed.
5. The following is a summary of the major provisions of the 2017 Settlement.
6. Article I states that the terms of the 2017 Settlement are a carefully crafted
compromise and that the Settling Parties request that it be approved in its entirety without
modifi cation or condition.
7 . Article II defines the Settling Parties and states that the 2017 Settlement is a
negotiated resolution of only those issues expressly set forth in the 20 l7 Settlement
8. Article III identifies the annual cost-of-service underlying the Settlement Rates,
and provides the two phases of rates that will be implemented.
9. Article IV describes the agreed rate design principles used in deriving the
Settlement Rates. According to section 4.1, General Transmission System, the rates for
all transportation Rate Schedules are based on a straight fixed variable ("SFV") rate
design. Section 4.2, Storage, provides that the rates under the Plymouth LNG and
Jackson Prairie rate schedules will be the same as those established in the 2012
Settlement. Section 4.3, Evergreen l5-Year Contract Roll-In, provides that the rates for
Rate Schedule TF-l (Large Customer), TF-l (25-Year Evergreen), Rate Schedule TF-2
and Rate Schedule TI-l to be effective January 1,2018, through September 30,2018,
as shown on Appendix B, reflect the allocation of costs to the TF-l (15-Year Evergreen)
contracts. The section states that the rates for Rate Schedule TF-l (Large Customer),
TF-l (25-Year Evergreen), Rate Schedule TF-2, and Rate Schedule TI-l to be effective
October 1,2018, through the remainder of the Settlement Term, as shown on
Appendix C, reflect the roll-in of the TF-l (15-Year Evergreen) contracts that will expire
on September 30,2018.
10. Article V states that the depreciation, amortization and net negative salvage rates
used in deriving the Settlement Rates are shown in Appendix D to the 2017 Settlement.
I l. Article VI states that if the U.S. federal income tax rate applicable to corporations
should be reduced or increased for any taxable period(s) between January 1,2018, and
the end of the Settlement Term, then Northwest will record a regulatory liability or asset
account. It explains how the amount to be placed into that regulatory liability or asset
account will be determined and how Northwest will amortize the balance in that account
over a period of five years after the Settlement Term.
Exhibit No.4
Case No. INT-G-18-02
lntermountain Gas Company
Page 5 of 3520r-70818-3011 FERC pDF (Unofficial) 08/]-8/20]-7
Docket No. RPI 7-346-000 -4-
12. Article VII refers to the surviving terms of Article VI of Northwest's prior rate
case settlement in Docket No. RPl2-490-000 relating to its ongoing treatment of Post-
Retirement Benefits Other than Pensions (PBOP), and updates the amount of Northwest's
regulatory liability related to PBOPs.
13. Article VIII states that the Settlement Rates for Phase I Rates are set forth in
Appendix B of the 2017 Settlement and shall become effective January l, 2018, and
remain in effect through September 30,2018, and that the Settlement Rates for Phase 2
Rates are set forth in Appendix C of the 2017 Settlement and shallbecome effective
October 1,2018, and remain in effect through the end of the Settlement Term.
14. Article IX states that the Settling Parties may not submit comments to the
Commission that oppose any provision of the 201 7 Settlement.
15. Article X defines the term Contesting Parties and explains that if there are any
Contesting Parties, Northwest will file an NGA section 4 general rate case by June 30,
2017, with regard to such Contesting Parties consistent with the 2017 Rate Filing
requirement. It also provides that Contesting Parties forego any and all rights or
obiigations under the 2017 Settlement.T
16. Article XI describes when the 2017 Settlement will become effective depending
upon whether it is approved by the Commission (a) without modification or condition or
(b) with modification or condition. It details the Settling Parties' rights and the
procedures to be followed if the Commission approves the 2017 Settlement with
modification or condition. It explains what happens to the 2017 Settlement if it is
withdrawn by Northwest or if it is rejected by the Commission in its entirety. It also
defines the Settlement Term.
17. Article XII defines the nine month and one day Moratorium during which the
Settling Parties are prohibited from taking certain actions inconsistent with the 2017
Settlement. It provides the standards of review to be applied if the Commission were to
consider any change to the terms of the 2017 Settlement during the Moratorium as
follows: "the standard of review for any changes to this Settlement proposed by a Settling
Party shall be the Mobile-Sierro'public interest' standard."8 The standard of review for
changes proposed by a non-Settling Party, or the Commission acting sua sponte, shall be
7 Amended by the March Filing and accepted by the April2017 Order.
8 Article XII (citing United Gas Pipe Line v. Mobile Gas Service Corp.,350 U.S
332 (1956), Federal Power Commission v. Sierra Pacific Power Co., 350 U.S. 348
(1956), and Morgan Stanley Copital Group, Inc. v. Public Utility District No. I of
Snohomish County,554 U.S. 527 (2008) (Morgan Stonley)).
Exhibit No.4
Case No. INT-G-18-02
lntermountain Gas Company
Page 6 of 3520170818-3011 FERC PDF (Unofficial) 08/L8/20]_7
Docket No. RP I 7-346-000 5
"the ordinary 'just and reasonable' standard."e Article XII also requires Northwest to file
an NGA section 4 general rate case with rates to become effective not later than January
1,2023, unless Northwest has entered into a Pre-Filing Sefflement or a post-Moratorium
NGA section 5 general rate case has been filed on or before January 1,2023, regarding
Northwest's rates.
18. Article XIII states that the provisions of the 2017 Settlement are not severable and
if the 2017 Settlement is not approved, then it shall be treated as privileged. It also states
that the 2017 Settlement does not establish precedent, long standing practice or settled
practice of the Commission. It states that no party shall be deemed to be the drafter of
the 2017 Settlement and that it shall be interpreted in accordance with the laws of Utah.
19. Article XIV describes the actions Northwest will take if the 2017 Settlement
approval process is completed before June 30, 20171' after June 30,2017; before
January 1,2018; or on, or after, January l, 2018.10
20. Article XV provides that the 2017 Settlement does not constitute a recent rate
review under the Commission's Policy Statement on Cost Recovery Mechanisms for
Modernization of Natural Gas Facilities, l5 I FERC n 61,047 , clarification denied,
I 52 FERC n il ,046 (2015), but that Northwest will not be precluded from seeking
Commission approval for a cost recovery mechanism pursuant to such policy statement
that would take effect after the Moratorium.
21. The Commission has stated that when a pipeline has negotiated an agreement with
its customers and others to change its rates or terms and conditions of service and the
pipeline desires approval of the agreement before making an actual NGA section 4 tariff
filing, the pipeline should simply file, pursuant to section 385.207 of the Commission's
regulations,ll a petition for approval of the agreement. If the Commission approves
the agreement, it will direct that the pipeline file, pursuant to NGA section 4(d) and
section 154.20312 of the Commission's regulations, actual tariff records implementing
e See Morgan Stanley,554 U.S. at 535.
'o On Ma..h 29, 2Ol7 , Northwest filed tariff records to extend the time by which it
must file an NGA section 4 general rate case and to make other changes to preserve and
implement rate reductions agreed to by Northwest and its shippers in the 2017
Settlement. See April 12,2017 delegated letter order in Docket No. RPlT-567-000
approving these revisions.
" r8 c.F.R. $ 38s.207(a)(s) (2017).
12 l8 c.F.R. $ 154.203 (zot7).
201-7081-8-30r-r- FERC PDF (Unofficial) 08/L8/2017
Docket No. RP I 7-346-000
Exhibit No. 4
Case No. INT-G-18-02
lntermountain Gas Company
Page 7 of 35
-6-
the agreement consistent with the terms of the agreement as approved by the
Commission. The Commission will treat such a filing as a filing to comply with the
Commission's order approving the agreement, and the Commission will place tariff
records that properly implement the agreement, as approved, into effect on the date
provided forin the agreement.13
22. The 2017 Settlement was such a negotiated agreement filed in lieu of a rate case,
relieving participants from litigation and administration costs of such a proceeding and,
in addition, resolving system-wide rate issues consistent with the Commission's guidance
for settlements outside the context of an existing proceeding.la In particular, the 2Ol7
Settlement will provide a reduction from Northwest's currently effective rates and
provides rate stability until January 1,2023.
Accordingly, the Commission finds that the uncontested 2017 Settlement appears to be
fair, reasonable and in the public interest, and therefore, the Commission approves the
2017 Settlement. The Commission directs Northwest to file tariff records through the
eTariff portalthat implement the2017 Settlement consistent with its terms. The
Commission's approval of the 2017 Settlement does not constitute acceptance of, or
precedent regarding, any principle or issue in this proceeding.
By direction of the Commission.
Nathaniel J. Davis, Sr.,
Deputy Secretary.
rt Dominion Transmission, Inc.,l I I FERC fl 61,285 (2005).
tn Id.
Exhibit No. 4
Case No. INT-G-18-02
lntermountain Gas Company
Page 8 of 35
Appendix C
NORTHWEST PIPELINE LLC
DocketNo. RPl7-
Summary of Daily Settlement Rates l/
Exclusive of Surcharges
Effective October 1, 2018
Rate
(b)(a)
Line Rate Schedule
TF.1
Resen€tion Charge Large Customer
- E\,ergreen - 2s-year
5 Volumetric Charge - Large Customer6 - E\ergreen -25-yeat
7 - Small Customer
8 TF-2
I ResenEtion Charge10 Volumetric Charge11 Tt-1
12 Maximum Volumetric Chage Z
13 Minimum Volumetric Charge14 SGS-2F Pre.Expansion'15 Demand Charge16 Capacity Demand Charge17 SGS-2F Expansion18 Demand Charge19 Capacity Demand Charge20 sGS-2t21 Volumetric Charge22 SGS-2F Volumetric Bid Rates Pr+Expansion23 Withdrawal Charge24 Storage Charge25 SGS-2F Volumetric Bid Rates Expansion26 Withdrawal Charge27 Storage Charge28 LS.2F29 Demand Charge30 Capacity Demand Charge31 Liquetrction Charge32 Vaporization Charge33 LS-2t 3/34 Maximum Volumetric Charge
35 Minimum Volumetric Charge
36 LS-2F Volumetric Bid 3/
37 Vaporization Demand Related Charge
38 Storage Capacity Charge
39 DEX.140 Maximum Volumetric Charge
41 Manimum Volumetric Charge42 PAL
43 Maximum Volumetric Charge44 Minimum Volumetric Charge
2018
2019
2020
2021
2022
2023
2024
2025
$0.098ss
$0.091 89
$0.08667
$0.081 94
$0.07696
$0.071 99
$0.06680
$0.06552
'l
2
3
$0.39033
$0.32039
$0 00832
$0.00832
$0.69427
$0.39033
$0.00832
$0.39865
$0.00832
$0.01 562
$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
$0.00331
$0.39865
s0.00000
s0.39865
$0.00000
45 Facilities ResenEtion Surcharge tcr the Columbia Gorge 1999 Expansion 4/s0.09855
1i Refrects resenation, demand and capacity demand charges as daily rates.
2/ Designed on a 100o/o load factor basis ofthe Rate Schedule TF-1 (Large Customer) rates.
3/ LS-21 and LS-2F \plumetric bid senice will also be assessed Rate Schedule LS-2F liquefaction and \aporization charges
4/ Rates br the years 2018 brward are as bllo\,\,s (surcharge ends March 31 , 2025):
Exhibit No. 4
Case No. INT-G-18-02
lntermountain Gas Company
Page 9 of 3520180323-3075 FERC pDF (Unofficial) 03/23/2078
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 I 8-488-000
Issued: March 23,2018
Northwest Pipeline LLC
P.O. Box 58900
Salt Lake city, UT 84158-0900
Attention: LarenGertsch,Director
Rates and Tariffs
Reference: 2018 Summer Fuel Filing
Dear Ms. Gertsch:
On February 28,2}ll,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, which require adjustments to its fuel reimbursement factors by April 1 of each
year. Northwest proposes the following adjustments to its factors: a) an increase from
I .00 percent to 1. 16 percent for Rate Schedules TF- l, TF-2, TI- l, and DEX- I
(transportation and exchange services); b) an increase from 0.15 percent to 0.17 percent
for Rate Schedules SGS-2F and SGS-2I (underground storage services); c) no change to
the current 0.53 percent for Rate Schedules LS-2F, LS-3F, LS-21, and LD-41
(liquefaction and storage services); and d) no change to the current 0.53 percent for Rate
Schedules LS-2F, LS-3F and LS-21 (vaporization services). Northwest also proposes no
change for 2018 to facility charges under Rate Schedules LS-3F and LD-41. The
referenced tariff record is accepted, effective April l, 2018, as proposed.
Public notice of the filing was issued on March 1, 2018. Interventions and protests
were due as provided in section 154.210 of the Commission's regulations (18 C.F.R.
$ 154.210 (2017)). Pursuant to Rule 214 (18 C.F.R. $ 385.214 (2017)), all timely filed
l Northwest Pipeline LLC; FERC NGA Gas Tariff; Fifth Revised Volume No. l,
SheetNo. 14. Fuel Use Factors.2l.0.0.
Exhibit No. 4
Case No. INT-G-18-02
lntermountain Gas Company
Page 10 of 3520180323-3075 FERC pDF (Unofficial) 03/23/20L8
Docket No. RP I 8-488-000 .)
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 Ac| 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
l8 c.F.R. $ 38s.713 (2017).
Sincerely{fufrry"-
Marsha K. P alazzi, Director
Division of Pipeline Regulation
Exhibit No.4
Case No. INT-G-18-02
lntermountain Gas Company
Page 11 of35
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. I
Twenty-First Revised Sheet No. l4
Superseding
Twentieth Revised Sheet No. 14
1.L5%
0. s0t
Rate Schedules TF-1,, TF-2, TI-1, and DEx-1
Rate Schedule TF-1 - Evergreen Expansion
Incremental Surcharge (1)
Rate Schedule TFL-1
Rate Schedule TIL-l-
Rate Schedules SGS-2F and SGS-2I
Rate Schedules LS-2F, LS-3F and LS-2ILiquefaction
Vaporization
Rate Schedule LD-4I
Liquefaction
STATEMENT OF FUEL USE REQUIREMENTS FACTORS
FOR REIMBURSEMENT OF FUEL USE
applicable to Transportation Service Rendered Under
Rate Schedules Contained in this Tariff, Fifth Revised Vol-ume No
The rates set forth on Sheet Nos. 5, 6, 7, 8 and 8-A are exclusive offuel use reguirements. Shipper sha11 reimburse Transporter in-kind for itsfuel use reguirements in accordance with Section 14 of the General Terms and
Conditions contained herein.
The fuel use reimbursement furnished by Shlppers shall- be as follows
for the applicable Rate Schedules included in this Tariff:
t-
0.L7"6
0. s3?
0.53?
0.53u
The fuel use factors set forth above shall- be calculated and adjusted
as explained in Section l-4 of the ceneral Terms and Conditions. Fuel
reimbursement quantities to be supplied by Shippers to Transporter shal1 be
det.ermined by applying the factors set forth above to the quantity of gas
nominated for receipt by Transport.er from Shipper for transportation,
,fackson Prairie injection, Plyrnouth liquefaction, Plymouth vaporization, or
for deferred exchange, as applicable.
Footnote
(1) In addition to the Rate Schedule TF-l- fuel use requirements factor, the
Evergreen Expansion Incremental Surcharge will apply to the quantit.y of gas
nominated for receipt at the Sumas, SIPI or pacific Pool receipt points under
Evergreen Expanslon servj-ce agreements.
Exhibit No. 4
Case No. INT-G-18-02
lntermountain Gas Company
Page 12 of35
NOVA GAS TRANSMISSION LTD.
(7 pages)
Exhibit No. 4
Case No. INT-G-18-02
lntermountain Gas Company
Page 13 of35
National Energy
Board
Of{ice national
de l'6nergie
ORDER TG-004-2018
IN THE MATTER OF the National Energ,, Board
Act (Act) and the regulations made thereunder; and
IN THE MATTER OF an application filed by
NOVA Gas Transmission Ltd. (NGTL) with the
National Energy Board (Board) pursuant to
subsection l9(2) and Part IV of the Act filed under
file OF-Tolls-Group I -N081 -201 8-01 .
BEFORE the Board on l9 June 2018:
WHEREAS on 12 August2010, the Board issued Order TG-004-2010 approving the toll design
methodology and terms and conditions of service on the NGTL System;
AND WHEREAS on 24 November 2017, the Board approved in Order TGI-001-2017 NGTL's
application for interim 2018 rates, tolls and charges (2018Interim Tolls) for services on the
NGTL System effective I January 2018, and NGTL's abandonment surcharges for 2018
effective 1 January 2018 (2018 Abandonment Surcharges);
AND WHEREAS on 21 March 2018, NGTL's Tolls, Tariff, Facilities and Procedures
Committee endorsed, through Resolution T2017-02 a settlement for establishing the NGTL
System revenue requirement and its components for the period I January 2018 to 3l December
2019 (the Settlement);
AND WHEREAS on 23 March 2018, NGTL filed an application requesting Board approval of
the Settlement and the resulting revised 2018 interim rates effective 1 May 2018 (Revised 2018
Interim Tolls) and final20l8 rates (the Application);
AND WHEREAS on l7 April20l8 NGTL filed revised versions of Attachment I (Receipt
Point Rates) and Attachment 2 (Delivery Point Rates) to the Table of Rates that were provided as
part of Attachment B, Tab-4 to the Application;
AND WHEREAS on 19 April 2018, the Board approved in Order TGI-002-2017 NGTL's
application for Revised 2018 Interim Tolls effective 1 May 2018, and continuation of NGTL's
2018 Abandonment Surcharges approved in Order TGI-001-2017;
C"anad?f
Exhibit No. 4
Case No. INT-G-18-02
lntermountain Gas Company
Page 14 of35
-2-
AND WHEREAS on 31 May 2018 NGTL filed Updated Attachment 1, (Receipt Point Rates) to
the Table of Interim 2018 Revised Rates (Table) of NGTL's Gas Transportation Tariff, effective
I June 2018;
AND WHEREAS in the Application NGTL advised the Board that the Revised 2018 Interim
Tolls are consistent with the Settlement and NGTL's existing toll design approved in Order
TG-004-2010;
AND WHEREAS in the Application NGTL advised the Board that the proposed 2018
Abandonment Surcharges have been calculated in accordance with the Board approved
methodology from the MH-001-2013 Decision;
AND WHEREAS no party has actively opposed the Settlement or has proposed an alternative to
the Board;
AND WHEREAS the Board has considered the Application for approval of the Settlement,
Final 201 8 Rates and 201 8 Abandonment Surcharges and has decided to approve the Application
as filed;
THEREFORE, IT IS ORDERED pursuant to subsection l9(2) and Part IV of the Act that:
l. The Settlement is approved as filed;
2. NGTL's 2018 Interim Tolls for the period 1 January 2018 to 30 April 2018 and
Revised 2018 Interim Tolls for the period I May 2018 to 31 December 2018, as
approved, respectively, in Order TGI-001-2017 and Order TGI-002-2018, are
approved as 2018 Final Tolls;
3. NGTL's 2018 Abandonment Surcharges, as approved in Order TGI-001-2017 and in
Order TGI-002-2018 are approved as 2018 Final Abandonment Surcharges;
l, NGTL's Settlement Reporting Obligations to the Board are those described in
Application, Attachment A-2018-2019 Settlement, item 2(F)(v), PDF page 8 of 54r,
and item 2(Fxiii) as modified in item 5. below;
2. NGTL shall provide the Board with the capital project information on a quarterly
basis as specified in item 2(F) (iii) of the Tolls, Tariff, Facilities, and Procedures
Committee Reporting of the Application, Attachment A-2018-2019 Settlement,
PDF page 8 of54; and
1 NEB Filing ID 49075 I - I
TG-004-2018
Exhibit No. 4
Case No. INT-G-18-02
lntermountain Gas Company
Page 15 of 35
-J-
3. NGTL shall provide the NGTL System unit transportation cost data in the Annual
Plan for three historical years and the five forecast years covered in each year's
Annual Plan. The unit transportation cost will be calculated by dividing NGTL's
actual or forecast revenue requirement by the System's actual or forecast annual
throughput. This filing requirement will take effect with NGTL's filing of its
2018 Annual Plan with the Board, which is expected in December 2018.
NATIONAL ENERGY BOARD
Original signed by
Sheri Young
Secretary ofthe Board
TG-004-2018
NOVA Gas Transmission Ltd
Exhibit No. 4
Case No. INT-G-18-02
lntermountain Gas Company
Page 16 of35
Table of Rates, Tolls and Charges
Page 1 of 1
Service Rates, Tolls and Charges
l. Rate Schedule FT-R
Refer to Attachment " 1" for applicable FT-R Demand Rate per month based on a three-year term (Price
Point "B") & Surcharge for each Receipt Point
Average Firm Service Receipt Price (AFSRP) $207 .20 /103m3 / month
2. Rate Schedule FT-RN Refer to Attachment "l" for applicable FT-RN Demand Rate per month & Surcharge for each Receipt Point
3. Rate Schedule FT-D I
Refer to Attachment"2" for applicable FT-D Demand Rate per month based on a one year term (Price Point
"2") & Surchuge for each Group I or Group 2 Delivery Point
Average FT-D Demand Rate for Group I Delivery Points $5.24 /GJ
FT-D Demand Rate for Group 2 Delivery Points $4.99 /GJ
FT-D Demand Rate for Group 3 Delivery Points $5.99 /GJ
4. Rate Schedule STFT STFT Bid Price = Minimum of 100% of the applicable FT-D Demand Rate based on a one year term (Price
Point "Z") for each Group I Delivery Point
5. Rate Schedule FT-DW FT-DW Bid Price = Minimum of 125% of the applicable FT-D Demand Rate based on a three year term
(Price Point "Y") for each Group I Delivery Point
6. Rate Schedule FT-P I Refer to Attachment "3" for applicable FT-P Demand Rate per month
7. Rate Schedule LRS-3 LRS-3 Demand Rate per month $129.55 /103m3 i month
8. Rate Schedule IT-R Refer to Attachment "l" for applicable IT-R Rate for each Receipt Point
9. Rate Schedule IT-D I Refer to Attachment "2" for applicable IT-D Rate for each Delivery Point
10. Rate Schedule FCS The FCS Charge is determined in accordance with Attachment "l" to the applicable Schedule of Service
I l. Rate Schedule PT The PT Charge is determined in accordance with the applicable Schedule ofService
12. Rate Schedule OS Schedule No.
201794371r
2017939621
2017939620
2017939619
201794478'.7
Charee
$121.30
$121.30
$l2t.30
$ 121.30
$121.30
/103m3 / month
/103m3 / month
/103m3 / month
/103m3 / month
/103m3 / month
2011475772
20t7849279
$9,250.00
$788.00
/ month
/ month
2003004522 Applicable IT-R and IT-D Rate
20114'16052 I
20114760s4
$0.1 64 I
$717,000.00
/ GJ subject to
Minimum Annual
Charge
2017887638 / 201476092 I
2016721799 I 20167 59254
$0.095
$ 1,000.00
/ GJ and
/ month
13. Rate Schedule CO2 Tier
I
2
J
CO, Rate ($/103m3)
543.5',7
430.09
279.2'.1
14. Monthly Abandonment
Surcharge 2 $10.51 7163s137616n1,$0.28 /CJ/month
15. Daily Abandonment
Surcharge 3 $0.35 /103m3/day $0.0091 /CJ/day
l. ServicemderrateSchedulesFT-D,FI-PmdlT-DfordeliverystatiomidentifiedinAttachment2,mdstationsidentifiedonrateSchedulesOSNo.20ll4T6092,uesubject
to the ATCO PifElines Frmchise Fees puswt to pilagmph 15.13 of the General Tems ud Conditions.
2. Monthly Abmdoment Suchrge applicable to Rate Schedules FT-R, FT-D, Ff-P, FT-RN, F[-DW, STFT, LRS-3, md the following Rate Schedules OS: 2017943711,
201't 939621, 20t1 939620, 20t7 939619, 20179447 I'1.
3. DailyAbmdommtSuchugeapplicabletoRateScheduleslT-R"IT-D,LRS,thefollowingRateSchedulesOS:2011476052,2011416054,201'1887638,2011476092,
201 6721799, 2Ol 67 59254, 2003004522, md if applicable Over-RN Gas.
Effective: May 1,2018
Exhibit No. 4
Case No. INT-G-18-02
lntermountain Gas Company
Page 17 of35
o TransCanada
ln business to deliver
450 I Street S.W.
Calgary, Alberta T2P 5Hl
Phone: [phone]
Fax: [phone]
Email: [e-mail]
Filed Electronically
NationalEnergy Board
Suite 210, 517 Tenth Avenue SW
Calgary, Alberta T2R 0A8
Attention: Ms. Sheri Young, Secretary of the Board
Dear Ms. Young:
Re: NOVA Gas Transmission Ltd. (NGTL)
Gas Transportation Tariff (Tariff)
Updated Attachment I and Attachment 2 to the Table of Final 2018 Rates, Tolls and
Charges (Final 2018 Rates)
NGTL attaches for filing with the Board pursuant to section 60(lXa) of the National Energt
Board Act an updated Attachment I (Receipt Point Rates) and Attachment 2 (Delivery Point
Rates) to the Table of Final 2018 Rates (Table) of the Tariff, effective July l, 2018.
The Board approved on June 19,2018 the previously approved Interim 2018 Revised Tollsr as the
Final20l8 Rates effective May 1,2018 with OrderTG-004-2018 (NEB Filing ID:A92601). The
updates to Attachment 1 and Attachment 2 of the Table reflects the new meter stations that are
expected to go into service during July 2018.
Attachment I to the Table has been updated to include a new receipt point at the Wildrose
receipt meter station. The Final 2018 FT-R and IT-R rates for the station are provided in the
following table:
Attachment 2 to the Table has been updated to include the Hays Sales delivery point at the
existing Hays receipt meter station, the North Heart River Sales delivery point at the existing
North Heart River receipt meter station and the Wildcat Hills Sales delivery point at the existing
Wildcat Hills receipt meter station. The Final 2018 FT-D and IT-D rates for the stations are
provided in the following table:
t NGTL's 2018 Interim Tolls for the period January l, 2018 to April 30, 2018 and Revised 2018 Interim Tolls for
the period May l, 2018 to December 31, 2018, as approved respectively, in Order TGI-001-2017 and Order TGI-
002-20 I 8.
Station
Number Station Name Legal Description
FT-R Demand Rate
($/103m3/month)
lT-R Rate
($/103m3/d)
Page No. on
Attachment 1
5172 Wildrose sw-25-067-05 W6M 194.45 7.35 24
June 28,2018
Exhibit No. 4
Case No. INT-G-18-02
lntermountain Gas Company
Page 18 of 35
June 28,2018
Ms. S. Young
Page 2 of2
The rates were detennined in accordance with NGTL's current rate design methodology
approved by the Board in Reasons for Decision RHW-l-2010 and Order TG-04-2010 on
August 12,2010.
If the Board requires additional information regarding this filing, please contact Mark Manning
by phone at [phone] or by email at [e-mail].
Yours truly,
NOVA Gas Transmission Ltd.
Original signed by
Bemard Pelletier
Director, Regulatory Tolls and Tariffs
Canadian Natural Gas Pipelines
Attachment
cc: TTFP
NGTL System Shippers
Station
Number Station Name Legal Description
FT-D Demand Rate
($/GJ/month)
lT-D Rate
($/GJ/d)
Page No. on
Attachment 2
3694 Hays Sales 11-31-013-14 W4M 4.99 0.1 805 4
3693 North Heart River Sales 09-20-085-17 WsM 4.99 0.1 805 o
3695 Wildcat Hills Sales 16-15-026-05 WsM 4.99 0.1 805 8
NOVA Gas Transmission Ltd
Group l
Delivery
Point
Number
Group I Delivery Point Name
FT-D Demand Rate
Prico Point "Z"
(i/GJ/mo)
lT-D Rate
(l/GJ/d)
Attachment 2
2018 Final Delivery Point Rates
Page 1 of 9
0.1805
0.1805
0.1 805
0.1 805
0.1 805
0.1945
0.1 805
0.1 945
Exhibit No. 4
Case No. INT-G-18-02
lntermountain Gas Company
Page 19 of35
Yes
Yes
Yes
Yes2
Yes
Yes2
Yes
2000
3111',!
31 110
31112
3002
1958
3886
6404
4.99
4.99
4.99
4.99
4.99
5.38
4.99
5.38
ALBERTA-8.C. BORDER
ALLIANCE CLAI RMONT INTERCONNECT APN
ALLIANCE EDSON INTERCONNECT APN
ALLIANCE SHELL CREEK INTERCONNECT APGC
BOUNDARY LAKE BORDER
EMPRESS BORDER
GORDONDALE BORDER
MCNEILL BORDER
31 000
31 001
3880
31 003
31 002
3'r 004
31 005
31 006
3214
31 007
31 008
3868
3297
3059
31 009
3562
31012
3488
3237
3662
32'16
31 35
3288
3423
310't 3
31014
3299
3068
3268
3933
3655
3067
3285
3468
3295
3225
3259
A.T. PLASTICS SALES APN
ADM AGRI INDUSTRIES SALES APN
AECO INTERCONNECTION
AGRIUM CARSELAND SALES APS
AGRIUM FT. SASK SALES APN
AGRIUM REDWATER SALES APN
AINSWORTH SALES APGP
AIR LIQUIDE SALES APN
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
4.99
4.99
4.99
4.99
4.99
4.99
4.99
4.99
4.99
4.99
4.99
4.99
4.99
4.99
4.99
4.99
4.99
4.99
4.99
4.99
4.99
4.99
4.99
4.99
4.99
4.99
4.99
4.99
4.99
4.99
4.99
4.99
4.99
4.99
4.99
4.99
4.99
0.1 805
0.1 805
0.1805
0.1 805
0.1 805
0.1 805
0.1 805
0.1 805
0.1 805
0.1 805
0.1 805
0.1 805
0.1805
0.1 805
0.1 805
0.1 805
0.1 805
0.1 805
0.1 805
0.1 805
0.1805
0.1805
0.1805
0.1805
0.1805
0.1 805
0.1805
0.1805
0.1805
0.1805
0.1 805
0.1 805
0.1805
0.1805
0.1805
0.1805
0.1805
Group 2
Delivery
Point
Number
Group 2 Delivery Poinl Name
FT.O Oemand Rate
Price Point "2"
(t/GJ/mo)
lT-D Rate
(3/GJ/d)
Subj6ct to
ATCO
Pipelines
Franchise
Feesl
Effective: May 1, 2018 (Amended: July 1, 2018)
Exhibit No. 4
Case No. INT-G-18-02
lntermountain Gas Company
Page 20 of 35
FOOTHILLS PIPE LINES LTD.
(3 pages)
Exhibit No. 4
Case No. INT-G-18-02
lntermountain Gas Company
Page 21 of35
o TransCanada
ln business to deliver
450-lStreetSW
Calgary, Alberta T2P 5Hl
Tel: [phone]
Fax [phone]
Email: [e-mail]
October 31,2017
National Energy Board
Suite 210, 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 1,2018
Foothills encloses for filing pursuant to section 60( I Xa) of the National Energt Board Actl rates
and charges for transportation service on Foothills Zones 6,7,8 and 9 to be effective
January 1,2018 (Effective 2018 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 Table of Effective
Rates for 2018
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 Decision with respect to Foothills'
Abandonment Surcharges effective January I , 201 8, which are also included in the Table of
Effective Rates for 2018. The supporting information on the Abandonment Surcharges
calculation is provided in the attached Schedule G.
Foothills met with shippers and interested parties on October 18,2017 , and presented the
preliminary 2018 revenue requirement and preliminary Effective 2018 Rates. Based on this
consultation, Foothills is not aware of any objections to its proposal for establishing the Effective
2018 Rates.
' R.S.C. 1985, c. N-7, as amended, and the regulations made thereunder,
Exhibit No. 4
Case No. INT-G-18-02
lntermountain Gas Company
Page 22 ot 35
October 31, 2017
Ms. S. Young
Page 2 of 2
Foothills understands that any party that is opposed to the rates and charges will advise the
Board accordingly.
Foothills will notify its shippers and interested parties of this filing and post a copy of it on
TransCanada's Foothills System website at:
http ://www.tccustomerexpress.com/93 4.html
Communication regarding this application should be directed to:
Mark Manning
Senior Project Manager, Tolls and Tariffs
Canadian Gas Pipelines
TransCanada Pipel-ines Limited
450-lStreetSW
Calgary, Alberta T2P 5Hl
Telephone: [phone]
Facsimile : (403) 920-23 47
Emai I : mark_manning@transcanada. 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
Joel Forrest
Director Canadian Law
Natural Gas Pipelines
TransCanada Pipelines Limited
450-l StreetSW
Calgary, Alberta T2P 5Hl
Telephone : [phone] | 5 6
Facsimile: [phone]
Emai I : j [e-mail]
Exhibit No. 4
Case No. INT-G-18-02
lntermountain Gas Company
Page 23 of 35
Foothills Pipe Lines Ltd.Page I
TABLE OF EFFECTIVE RATES
1.. Rate Schedule FT, Firm Transportation Service
Demand Rate
($/GJ/Km/Month)
Zone6 0.0053089826
ZoneT 0.0024594335
ZoneS* 0.0130154360
Zone9 0.0077406397
2. Rate Schedule OT, Overrun Transportation Service
Commodity Rate
($/GJ/Km)
Zone 6 0.0001919961
ZoneT 0.0000889439
3. Rate Schedule IT, Interruptible Transportation Service
Commodity Rate
($/GJ/Km)
Zone 8x 0.0004706952
Zone9 0.0002799355
4. Monthly Abandonment Surcharge**
All Zones 0.09 4 I 626428 ( $/GJ/lvlonth)
5. Daily Abandonment Surcharge***
All Zones
+ For Zone 8, Shippers Haul Distance shall be 170.7 km.
0.0030957522 ($/GJ/Day)
**Monthly Abandonment Surcharge applicable to Rate Schedule Firm Transportation Service, and Short Term Firm
Transportation Service for all zones.
xx*Daily Abandonment Surcharge applicable to Rate Schedule Overrun Transportation Service for Tnne 6 & 7 ,
Interruptible Transportation Service for zone 8 & 9, and Small General Service for Zone 9.
TARIFF_ PHASE I Effective Date: January I , 20 I 8
Exhibit No. 4
Case No. INT-G-18-02
lntermountain Gas Company
Page 24 of 35
GAS TRANSMISSION NORTHWEST LLC
(5 pages)
Exhibit No. 4
Case No. INT-G-18-02
lntermountain Gas Company
Page 25 of 35201'7L228-3033 FERC pDF (Unofficial) L2/28/20L7
l6l FERC fl 61,305
FEDERAL ENERGY REGULATORY COMMISSION
WASHINGTON, DC 20426
December 28,2017
In Reply Refer To:
Gas Transmission Northwest LLC
Docket No. RPI 8-l 84-000
Gas Transmission Northwest LLC
700 Louisiana Street
Suite 700
Houston, TX77002
Attention: John A. Roscher, Director
Rates & Tariffs
Dear Mr. Roscher:
l. On November 27 ,2017 , pursuant to section 4 of the Natural Gas Act,
Gas Transmission Northwest LLC (GTN) submitted proposed tariff recordsr to
implement two new hourly services: Rate Schedule Firm Hourly Service (FHS)
and Rate Schedule Interruptible Hourly Service (lHS). GTN states that the proposed
new services will provide additional transportation options and flexibility to shippers
whose intra-day gas requirements may not be uniform and who may require accelerated
flow rates during particular periods of the gas day.
2. GTN states that FHS willprovide shippers greater flexibility by allowing GTN to
offer firm transportation service at hourly flow rates greater than ll24th of a shipper's
Maximum Daily Quantity (MDQ). GTN states that under FHS, a shipper may contract
for firm transportation service up to a specified Maximum Hourly Quantity (MHQ),
and an hourly flow rate ranging between ll4th and ll24th of the shipper's MDQ.2
GTN explains that the MHQ allows the shipper to receive delivery of its MDQ at an
I See Appendix.
2 Proposed Rate Schedule FHS, section 5.6.
Exhibit No. 4
Case No. INT-G-18-02
lntermountain Gas Company
Page 26 of 352077L228-3033 FERC PDF (Unofficial) 12/28/2017
Docket No. RPI 8-184-000 1-L-
accelerated rate over a specified number of hours during the day. GTN states that, once a
shipper has received quantities equal to its MDQ or MHQ, GTN will only offer further
capacity to the shipper on an interruptible basis as overrun. GTN states that it shall offer
FHS on both its Mainline and Extension Facilities and only when there is available,
unsubscribed system capacity. GTN states that the addition of FHS will not degrade
existing firm services, nor the operations of interconnection pipelines. GTN states that
FHS will have the same scheduling and curtailment priority as firm service (Rate
Schedule FTS-I) and limited firm service and that FHS overrun volumes will have a
scheduling and curtailment priority equal to interruptible service (Rate Schedule ITS-l)
and IHS. GTN states that the reservation rates for FHS are derived from GTN's currently
effective Rate Schedule FTS-l mileage and non-mileage reservation rate components.3
3. In addition, GTN proposes to implement IHS to provide similar hourly flow
flexibility on an interruptible basis to shippers who do not wish to contract for hourly
service on a firm basis. GTN states that although IHS shippers will not be entitled to
reserve an hourly quantity, GTN will attempt to flow the daily nomination at an hourly
flow rate designated by the shipper as part of its nomination, on a best efforts basis.
GTN states that IHS service will not adversely affect existing firm service on its system
or the operations of interconnection pipelines. GTN indicates that interruptible service
under IHS will have the same scheduling and curtailment priority as Rate Schedule ITS-l
and overruns on any of GTN's firm services. GTN describes the rates for IHS as derived
from the 100 percent load factor rate equivalent of the effective rate components (i.e.,
Mileage, Non-Mileage, and Delivery Charge Components) for a shipper selecting an
MHQ equal to l/lOth of the MDQ under FHS. According to GTN, the derived rate
represents the maximum recourse rate for IHS shippers regardless of their nominated
level of hourly flow.a
4. GTN states that as FHS and IHS are new services and GTN is not able to predict
the extent to which these services will be utilized, GTN is unable to adequately predict
the revenue that may be expected from these services for the l2 months commencing
January 1,2018. Accordingly, GTN requests waiver of section 15a.202(a)(l)(viii) of the
Commission's regulations, which requires that tariff filings for a new service include an
estimate of the effect on costs and revenues for the l2-month period commencing on the
effective date of the new service.s GTN seeks an effective date for the tariff provisions
ofJanuary 1,2018.
3 Filing at 3.
n Id. at 4-5.
s l8 c.r'.R. g ba.202(a)(l)(viii) (zot7).
Exhibit No. 4
Case No. INT-G-18-02
lntermountain Gas Company
Page27 ot3520L7t228-3033 FERC PDF (Unofficial) 1-2/28/20L7
Docket No. RP I 8-l 84-000 -4-
5. GTN's filing was noticed on November 28,2017, with interventions and protests
due on or before December 11,2017. Pursuant to Rule 214 (18 C.F.R. $ 385.214
(2017)), all timely filed motions to intervene and any unopposed motions to intervene
out-of-time filed before the issuance date of this order are granted. Granting late
intervention at this stage of the proceeding will not disrupt this proceeding or place
additional burdens on existing parties. No protests or adverse comments were filed.
6. The Commission finds that FHS and IHS increase shippers' options without
degrading previously contracted-for services. The Commission encourages pipelines to
develop new services to use their systems more efficiently.6 Similar to the Commission's
finding in Texas Eastern, we find the hourly services proposed by GTN to be just and
reasonable.' GTN has satisfactorily demonstrated that Rate Schedule FHS and Rate
Schedule IHS will not have any adverse impact on existing customers on its system.
7. When a pipeline proposing a new rate schedule lacks the operating experience
necessary to provide a reliable projection of possible revenues or costs related to the
new service, the Commission has often conditioned its approval upon the filing of an
activity report following the first year of service.s This appears appropriate here where
GTN acknowledges that it is unable to adequately predict the revenue that may be
expected from these services for the l2 months commencing January 1,2018. Therefore,
the Commission will require GTN to file an activity report within 45 days after the
conclusion of the FHS and IHS Rate Schedules' first year of operation. The report must
detail (1) the date service was rendered for each transaction, (2) the volume shipped
under each transaction, (3) monthly volumes, (4) the name of the shipper for each
transaction, (5) whether the shipper is an affiliate of GTN, (6) the rate charged for each
transaction, (7) the revenues received for each transaction, and (8) the monthly revenues
for this service. Such information will provide interested parties actual information that
can be used to monitor GTN's FHS and IHS activity and revenues.
u E.g., Gulf South Pipeline Co., LP, 157 FERC fl 6l ,054, atP 7 (2016).
' Texot Eastern Transmission, L.P.,134 FERC fl 61,068 (201l).
8 See Gulf South Pipeline Co., LP,136 FERC fl 61,086, atP 24 (2}ll); Northwest
Pipeline Corp.,l00 FERC n61,336, at PP 9, 12 (2002).
Exhibit No. 4
Case No. INT-G-18-02
lntermountain Gas Company
Page 28 of 35201-71228-3033 FERC PDF (Unofficial) 1-2/28/20L7
Docket No. RPI 8-l 84-000 -5-
8. Accordingly, the Commission accepts the GTN tariff records referenced in
the Appendix, effective January 1,2018, and grants GTN's request for waiver of
section 15a.202(a)(l)(viii) of the Commission's regulations. GTN is hereby directed to
file an activity report within 45 days after the first year of service of Rate Schedule FHS
and Rate Schedule IHS, as discussed above.
By direction of the Commission.
Nathaniel J. Davis, Sr.,
Deputy Secretary.
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. 1-A
DAILY
MILEAGE (a)
(Dth-MILE)
Max. Min.
BASE 0.000434 0.000000
STF (e) (e) 0.000000
EXTENSION CHARGES
MEDFORD
E-l (f) 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) 0.00r282 0.000000
CARTY LATERAL
E4 (p) --
ovERRLiN CHARGE 0)
SURCHARGES
ACA (k)
Issued: November 27, 2017
Effective: January l, 2018
Exhibit No. 4
Case No. INT-G-18-02
lntermountain Gas Company
Page 29 of 35
PART 4.I
4.1 - Statement of Rates
FTS-I, LFS-I, and FHS Rates
v. 1 7.0.0 Superseding v. 1 5.0.0
STATEMENT OF EFFECTIVE RATES AND CHARGES FOR
TRANSPORTATION OF NATURAL GAS
Rate Schedules FTS-1, LFS-1, and FHS
For Rate Schedules FTS-1 and LFS-l:
RESERVATION
DAILY
NON-MTLEAGE (b)
(Dth)
Max. Min.
0.034393 0.000000
(e) 0.000000
DELIVERY (c)
(Dth-MILE)
Max. Min.
0.000016 0.000016
0.000016 0.000016
FUEL (d)
(Dth-MrLE)
Max. Min.
0.0050% 0.0000%
0.0050% 0.0000%
0.004641 0.000000 0.000026 0.000026
0.000000 0.000000
0.000000 0.000000
0.001283 0.000000 0.000000 0.000000
0.166475 0.000000 0.000000 0.000000
(k) (k)
Docket No. RPI 8-1 84-000
Accepted: December 28, 2017
Exhibit No. 4
Case No. INT-G-18-02
lntermountain Gas Company
Page 30 of 35
DOMINION ENERGY QUESTAR PIPELINE, LLC
(3 pages)
Exhibit No. 4
Case No. INT-G-18-02
lntermountain Gas Company
Page 31 of352017721-9-3036 FERC PDF (Unofficial) 72/t9/20L7
FEDERAL ENERGY REGULATORY COMMISSION
WASHINGTON, D.C. 20426
OFFICE OF ENERGY MARKET REGULATION
In Reply Refer To:
Letter Order Pursuant to $ 375.307
Dominion Energy Questar Pipeline, LLC
Docket No. RP I 8-206-000
December 19,2017
Dominion Energy Questar Pipeline, LLC
c/o Dominion Energy Services, Inc.
333 South State Street
P.O. Box 45360
Salt Lake city, UT 84145-0360
Attention: L. Bradley Burton
Director - Regulatory Rates, Certificates and Tariffs
Reference: Fuel Gas Reimbursement Percentage Filing
Dear Mr. Burton:
On November 30, 2077, Dominion Energy Questar Pipeline, LLC (DEQP) filed a
tariff recordl to reflect a change in its Fuel Gas Reimbursement Percentage (FGRP).
DEQP requests the tariff record be accepted with an effective date of January 1,2018.
DEQP's tariff record is accepted to be effective January 1,2018, as proposed.
Public notice of the filing was issued on November 30, 2017. lnterventions and
protests were due as provided in section 154.210 of the Commission's regulations (18
C.F.R. $ 154.210 (2017)). Pursuant to Rule 214 (18 C.F.R. $ 385.214 (2017)), all timely
filed motions to intervene and any unopposed motions to intervene out-of-time filed
before the issuance date of this order are granted. Granting late interventions at this stage
of the proceeding will not disrupt the proceeding or place additional burdens on existing
parties. No protests or adverse comments were filed.
I Dominion Energy Questar Pipeline, LLC, FERC NGA Gas Tariff, Tariffs,
Statement of Rates. Statement of Rates. 13.0.0.
Exhibit No. 4
Case No. INT-G-18-02
lntermountain Gas Company
Page 32 of 3520L7t219-3035 FERC pDF (Unofficial) L2/79/20],7
Docket No. RP I 8-206-000
This acceptance for filing shall not be construed as constituting approval of the
referenced filing or of any rate, charge, classification, or any rule, regulation, or practice
affecting such rate or service contained in your tariff; nor shall such acceptance be
deemed as recognition of any claimed contractual right or obligation associated
therewith; and such acceptance is without prejudice to any findings or orders which have
been or any which may hereafter be made by the Commission in any proceeding now
pending or hereafter instituted by or against your company.
This order constitutes final agency action. Requests for rehearing by the
Commission may be filed within 30 days of the date of issuance of this order, pursuant to
r8 c.F.R. $ 38s.713 (2017).
Sincerely,
Marsha K. P alazzi, D irector
Division of Pipeline Regulation
2
Exhibit No. 4
Case No. INT-G-I8-02
lntermountain Gas Company
Page 33 of 35
Dominion Energy Questar Pipeline, LLC
FERC Gas Tariff
Second Revised Volume No. 1
Statement of Rates
Section Version: 13.0.0
STATEMENT OF RATES
Rate Schedule/
Type of Charge(a)
PEAKING STORAGE
Firm Peaking Storage
Monthly Reservation
Maximum 4/.........
Minimum.............,
Usage Charge
Injection
Withdrawal
Service - PKS
Charge
CLAY BASIN STORAGE
Firm Storage Service - FSS
Monthly Reservation Charge
Deliverability
Maximum 4/ .................
Minimum.......
Capacity
Maximum
Minimum.......
Usage Charge
Injection 1/
Withdrawal
Authorized Overrun Charge ...........
MaximumU...Minimuml/....
Interruptible Storage Service - ISS
Usage Charge
Inventory 5/
Maximum
Minimum.......
Injection 1/
Withdrawal
OPTIONAL VOLUMETRIC RELEASES /
Peaking Storage Service - PKS
Maximum 4/ .................
Minimum.......
Firm Storage Service - FSS
Maximum 4/ .................
Minimum.......
Storage Usage Charges Applicable to Volumetric Releases 6/
Peaking Storage Service - PKS:............
Injection
Withdrawal ....
Clay Basin Storage Service - FSS:
Injection 1/
Withdrawal ....
PARK AND LOAN SERVICE. PAL1
Daily Charge
Maximum
Minimum.......
Delivery Chargel/
FUEL REIMBURSEMENT - 2.0o/o (0.2o/o utility and 1.8yo compressor fuel) for Rate Schedule PAL1
Base
Tariff
Rate ($)
(b)
2.87375
0.00000
0.03872
0.03872
2.85338
0.00000
0.02378
0.00000
0.01049
0.01781
0.303 1 5
0.01781
.40890
.00000
.57068
.00000
...0.03872
...0.03872
...0.05927
...0.00000
...0.01049
...0.01781
0
0
...0.01049
...0.01781
...0.30315
...0.00000
...0.02830
Filed On: November 30,2077 Effective On: January 1, 2018
Exhibit No.4
Case No. INT-G-18-02
lntermountain Gas Company
Page 34 of 35
FEDERAL ENERGY REGULATORY COMMISSION
ANNUAL CHARGES UNIT CHARGE
(1 pages)
Exhibit No. 4
Case No. INT-G-18-02
lntermountain Gas Company
Page 35 of 35
FEDERAL ENERGY REGULATORY COMMISSION
WASHINGTON. D.C.20426
FY 2017 GAS ANNUAL CHARGES
CORRECTION FOR ANNUAL CHARGES LTNIT CHARGE
June 26, 2018
The annual charges unit charge (ACA) to be applied to in fiscal year 2019 for recovery of
FY 2018 Current year and 2017 True-Up is $0.0013 per Dekatherm (Dth). The new ACA
surcharge will become effective October l, 2018.
The following calculations were used to determine the FY 2018 unit charge:
2018 CURRENT:
Estimated Program Cost $66,791,000 divided by 49,985,774,086 Dth : 0.0013362002
2017 TRUE-UP:
Debit/Credit Cost ($316,993) divided by 47,717,356,257 Dth (0.0000066431)
TOTAL UNIT CHARGE = 0.0013295571
If you have any questions, please contact Raven A. Rodriguez at [phone] or e-mail
at Raven. Ro drigtez@ferc. gov.
PUBLIC
EXHIBIT NOS. 5.13
CASE NO. INT.G.18.O2
INTERMOUNTAIN GAS COMPANY
(10 pages)
Exhibit No. 5
Case No. INT-G-18-02
lntermountain Gas Company
Page 1 of '1
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Case No. INT-G-18-02
lntermountain Gas Company
Page 1 of 1
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Case No. INT-G-18-02
lntermountain Gas Company
Page 1 of 1
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Case No. INT-G-18-02
lntermountain Gas Company
Page 1 of 1
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Case No. INT-G-18-02
lntermountain Gas Company
Page 1 of 1
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INTERMOUNTAIN GAS COMPANY
Proposed Temporary Surcharges (Credits) - Variable Gosts
Description
Exhibit No. 10
Case No. INT-G-18-02
lntermountain Gas Company
Page 1 of 1
Amount
1
2
4
5
6
7
8
(a)
Account 1910 Variable Amounts Which Apply to RS, GS-I, and LV-l:
Account 1910 Variable Costs
Normalized Sales Volumes (111117 - 12131117)
Proposed Temporary Surcharge (Credit) - Variable Costs
Lost and Unaccounted For Gas Amounts Which Apply to RS and GS-l:
Lost and Unaccounted For Gas Amounts from INT-G-17-05 (Account 1910.2120)
Lost and Unaccounted For Gas Amortization (Account 1910.2130)
(Over)/Under Collection of Lost and Unaccounted For Gas from INT-G-17-05
Lost and Unaccounted For Gas INT-G-18-02
Total Lost and Unaccounted For Gas Amounts Which Apply to RS and GS-1
Normalized Sales Volumes (111117 - 12131117)
Proposed Temporary Surcharge (Credit) - Lost and Unaccounted For Gas Costs
(b)
$ (5,040,702) (1)
362,713,871
$ (0.013s0)
$(639,441)e)
725,932 t3l
86,491
519,013 (4)
$605,504
355,340,256
$0.00170
$(218,673) (5)
226,764 $l
8,091
172,g26 t7l
s 180,91 7
364,463,691
$0.00050
$0.00050
31 3,530,305
$1 56,765
17,280,720
$0.00907
I
10
11
12
17
18
19
20
21
22
23
24
25
26
13 Lost and Unaccounted For Gas Amounts Which Apply to LV-1, T-3, and T-4:
14 Lost and Unaccounted For Gas Amounts from INT-G-17-05 (Account 1910.2120)
15 Lost and Unaccounted For Gas Amortization (Account 1910.2140)
16 (Over)/Under Collection of Lost and Unaccounted For Gas from INT-G-17-05
Lost and Unaccounted For Gas INT-G-18-02
Total Lost and Unaccounted For Gas Amounts Which Apply to LV-1, T-3, and T4
Normalized Sales Volumes (111117 - 12131117)
Proposed Temporary Surcharge (Credit) - Lost and Unaccounted For Gas Costs
Convert T4 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 T-4 Sales Volumes (111117 - 12131117)
Total Temporary Collected
Billing Determinants 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 16, Column (f)
(2) See Workpaper No. 5, Page 2, Line 2, Column (c)
(3) See Workpaper No. 5, Page 2, Line 8, Column (d)
(a) See Workpaper No. 5, Page 2, Line 29, Column (d), plus Line 35, Column (e)
(5) See Workpaper No. 5, Page 2, Line 3, Column (c)
(6) See Workpaper No. 5, Page 2, Line 14, Column (d)
(7) See Workpaper No. 5, Page 2, Line 30, Column (d), plus Line 39, Column (e)
Exhibit No. 11
Case No. INT-G-18-02
lntermountain Gas Company
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Case No. INT-G-18-02
lntermountain Gas Company
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Case No. INT-G-18-02
lntermountain Gas Company
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Case No. INT-G-18-02
lntermountain Gas Company
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