20190815Application.pdf

EXECUTIVE OFFICES
I rurenruou NTAIN Gas Coruperuv
55s SOUTH COLE ROAD . P.O. BOX 7608 . BOISE, IDAHO 83707 . [phone] o FAX: [phone]
REC E IVED
.i019 I,UG I 5 At{ ll: 03
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August 15,2019
Ms. Diane Hanian
Commission Secretary
Idaho Public Utilities Commission
P.O. Box 83720
Boise, lD 83720-0074
RE: Case No. INT-G-19-06
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,
20t9.
If you should have any questions regarding the attached, please don't hesitate to contact me at
(208) 377-60rs.
Very truly yours,
Lori A. Blattner
Director, Regulatory Affairs
Intermountain Gas Company
Enclosure
Mark Chiles
Preston Carter
cc:
tr*frW
INTERMOUNTAIN GAS COMPANY
CASE NO. INT.G.19-06
APPLICATION,
EXHIBITS,
AND
WORKPAPERS
In the Matter of the Application of INTERMOUNTAIN GAS COMPAI{Y
For Authority to Change its Prices on October 1, 2019
(October lr20l9 Purchased Gas Cost Adjustment Filing)
Preston N. Carter, ISB No. 8462
Givens Pursley LLP
601 W. Bannock St.
Boise,Idaho 83702
Telephone: (208) 388-l 200
Attomeys for Intermountain Gas Company
In the Matter of the Application of
INTERMOLINTAIN GAS COMPANY
for Authority to Change its Prices
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
Case No. INT-G-19-06
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 of the Idaho Public Utilities Commission ("Commission"), hereby
requests authority, pursuant to Idaho Code Sections 61-307 and 6l-622, to place into effect October
1,2019 new rate schedules which will decrease its annualized revenues by $1.1 million. Because of
changes in Intermountain's gas related costs, as described more fully in this Application,
Intermountain's earnings will not be impacted as a result of the proposed changes in prices and
revenues. Exhibit No. I is a summary of the overall price changes by class of customer and is
attached and incorporated by reference. Intermountain's current rate schedules showing proposed
changes are attached as Exhibit No. 2 and incorporated by reference. The resulting proposed rate
schedules are attached as Exhibit No. 3 and incorporated by reference.
Please address communications regarding this Application to:
Lori A. Blattner
Director - Regulatory Affairs
Intermountain Gas Company
Post Office Box 7608
Boise,ID 83707
INrenvouNTATN GAS COMPA}{Y'S AppITCeTION - 2
and
Preston N. Carter
Givens Pursley LLP
601 W. Bannock St.
Boise,Idaho 83702
In support of this Application,Intermountain alleges and states 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/Riverside, and Shelley;
Blaine County - Bellevue, Hailey, Ketchum, and Sun Valley;
Bonneville County - Ammon, Idaho Falls, Iona, and Ucon;
Canyon County - Caldwell, Greenleaf, Middleton, Nampa, Parma, and Wilder;
Caribou County - Bancroft, Grace, and Soda Springs;
Cassia County - Burley, Declo, Malta, and Raft River;
Elmore County - Glenns Ferry, Hammett, and Mountain Home;
Fremont County - Parker, and St. Anthony;
Gem County - Emmett;
Gooding County - Gooding, and Wendell;
Jefferson County - Lewisville, Menan, Rigby, and Ririe;
Jerome County - Jerome;
Lincoln County - Shoshone;
Madison County - Rexburg, and Sugar City;
Minidoka County - 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.
INTERMoTINTAIN GAS CoIT,PeNY,S APPLICATIoN - 3
Intermountain's properties in these locations consist of ransmission pipelines, liquefied
natural gas storage facilities, a compressor station, distribution mains, services, meters and
regulators, and general plant and equipment.
II.
With this Application,Intermountain seeks to pass through to each of its customer classes
changes in gas related costs resulting from: 1) costs billed to Intermountain from firm transportation
providers including Northwest Pipeline LLC ("Northwest" or'Northwest Pipeline"), 2)
replacement of long term segmented Northwest Pipeline capacity received from third parties with
firm Northwest Pipeline capacity held directly by Intermountain, 3) a decrease in Intermountain's
Weighted Average Cost of Gas ("WACOG"),4) anupdated customer allocation of gas related costs
pursuant to the Company's Purchased Gas Cost Adjustment ("PGA") provision, 5) 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, 6) benefits resulting from
Intermountain's management of its storage and firm capacity rights on various pipeline systems, 7)
benefits associated with the sale of liquefied natural gas from the Company's Nampa, Idaho facility,
8) a portion of the costs accrued related to Intermourtain's Case No. INT-G-16-02 General Rate
Case and, 9) the recovery of defened in-person customer payment fees. Intermountain also seeks to
eliminate the temporary surcharges and credits included in its current prices dwing the past 12
months, pursuant to Case No. INT-G-18-02. If approved, these changes would result in a price
decrease to Intermountain's RS, T-3, and T-4 customers and a price increase to Intermountain's GS-
I and LV-l customers.
IrrrpRvouqrenq Ges CoMpaNy's Appt-tcartoN - 4
These price changes are applicable to service rendered under rate schedules affected by and
subject to Intermountain's PGA, initially approved by this Commission in Order No. 26109, Case
No. NT-G-95-1, and additionally approved through subsequent proceedings.
III.
The Commission approved the current temporary prices, and prices related to the cost of
gas, in Order No. 34154, Case No. INT-G-I8-02.
Iv.
Intermountain's proposed prices incorporate all changes in costs relating to the
Company's firm interstate transportation capacity including, but not limited to, any price changes
or projected cost adjustments implemented by the Company's pipeline suppliers, as well as any
volumetric adjustments in contracted transportation agreements which have occurred since
Intermountain's PGA filing in Case No. INT-G-18-02. Exhibit No. 4, which contains pertinent
excerpts from applicable pipeline tariffs, is attached hereto and incorporated herein by reference.
Intermoturtain has historically contracted a portion of its firm transportation on Northwest
Pipeline through long-term segmented capacity contracts with third parties. As those contracts near
their expiration dates, Intermountain was able to negotiate contracts to replace the expiring capacity
with firm Northwest transportation capacity contracted directly between Intermountain and
Northwest. Additionally, Intermountain was able to extend its existing Northwest Pipeline transport
agreements as well as its Plymouth storage agreements. Taken together, these contract changes,
coupled with Northwest's tariff changes, result in an increase of $1,057,013 as shown on Exhibit
No. 5, Lines 3 and 4, attached and incorporated by reference. This capacity restructuring will allow
Intermountain to continue to provide its customers the safe, reliable , and economically priced
service they expect.
INrgnvotrNrent Gas CoMpANy's Appr-tcartoN - 5
V.
Intermountain continues to contract a variety of natural gas storage assets on Northwest
Pipeline's system as well as with Dominion Energy Questar Pipeline ("Dominion"). In addition
to providing operational reliability, these storage contracts can provide significant price stability
to customers. The value of these resources to Intermountain's customers was demonstrated over
the past winter season when supply interruptions in the Pacific Northwest caused daily natural
gas prices to significantly spike. Intermountain was able to utilize its liquefied natural gas
storage contracts on Northwest's system to mitigate the impact of the short-term price increase to
its customers.
In addition, Intermountain continues to effectively manage its natural gas storage assets
at Northwest's Jackson Prairie and Dominion's Clay Basin storage facilities. As shown in Line
20 of Exhibit No. 5 and supporting documents, Intermountain's management of these storage
assets resulted in approximately $1.8 million in savings.
Exhibit No. 5, Lines 7 through 20, details the proposed changes to Intermountain's prices
resulting from Intermountain' s storage contracts.
vI.
The WACOG reflected in Intermountain's proposed prices is $0.20904 per therm, as shown
on Exhibit No. 5, Line22, Col. (f). This comparesto $0.22724 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 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
INTpRUotxTAIN GAS COMPANY,S APPLICATION - 6
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 eflort to further stabilize the prices paid by
our customers during the upcoming winter period,Intermountain has entered into various fixed
price agreements to lock-in the price for portions of its underground storage and other winter
"flowing" supplies.
Intermountain believes thalthe 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 2019 - 2020 PGA period. Intermountain will employ, in
addition to those fixed price agreements already in place, cost effective price arrangements to
fi,rther 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.
INTERMoUNTAIN GAS CoMPANY,S APPIICAUON - 7
VII.
Pursuant to the Commission's Order in Case No. INT-G-18-02, Intermountain
included temporary credits in its October 1,2018 prices for the principal reason of passing back to
its customers deferred gas cost benefits. Line 27 of Exhibit No. 5 reflects the elimination of these
temporary credits.
In summary, Exhibit No. 5 outlines the price changes in 1) Intermountain's base rate gas
costs as previously described,2) its rate class allocation, and 3) adjustments to temporary surcharges
or credits flowing through to Intermountain's customers.
vm.
Under Intermountain's PGA tariff, 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, Line 25. 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 | - 20, Col. (h) is shown on Exhibit No. 6, Line 29 , attached and
incorporated by reference.
IX.
Intermountain proposes to pass through to its customers the benefits that will be generated
from the management of its transportation capacity, totaling $7.1 million as outlined on Exhibit No.
8. These benefits include credits from segmented releases 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, as detailed on Exhibit No. 8 and included on Exhibit No. 7 ,Lrne l, attached and
INTERMoUNTaN Gas CoMPANY,S APPLICATION . 8
incorporated by reference.
x.
Intermountain proposes to allocate deferred gas costs from its Account No. 191 balance to
its customers through temporary price adjustments to be effective during the l2-month period
ending September 30, 2020, as follows:
l) Intermountain has deferred fixed gas costs in its Account No. 191. The credit amount
shown on Exhibit No. 9, Line 7, Col. (b) of $17.8 million is attributable to a true-up of the collection
of interstate pipeline capacity costs, the true-up of expense issues previously ruled on by this
Commission, and mitigating capacity release credits generated from the incremental release of
Intermountain's pipeline capacity. Intermountain proposes to true-up these balances via the per
therm debits and credits, as detailed on ExhibitNo. 9 and included on ExhibitNo. 7,Line2,
attached and incorporated by reference.
2) Intermountain has also deferred in its Account No. 191 a variable gas cost debit of S4.6
million, as shown on Exhibit No. 10, Line2, Col. (b). This deferred debit is attributable to
Intermountain's variable gas costs since October 1, 2018. Intermountain proposes to pass back this
balance via a per therm debit, as shown on Exhibit No. 10, Line 4, Col. (b) and included on Exhibit
No. 7, Line 3.
3) Finally, Intermountain has deferred in its Account No. 191 deferred gas costs related to
Lost and Unaccounted for Gas as shown on Exhibit No. I 0, Lines 5 through 26, Col. (b). This deferral
results in a per therm 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. 10 is
attached hereto and incorporated herein by reference.
xI.
INTERMOUNTAIN GAS COMPANY,S APPITCATTON - 9
Pursuant to Commission OrderNo. 32793, Case No. INT-G-13-02, Intermountain has
deferred in its Account No. 191 gas cost credits associated with sales of liquefied natural gas at its
Nampa, Idaho facility. Intermountain proposes to pass back this $1.1 million sales credit as outlined
on Exhibit No. 1 1, Line 7 and shown on Exhibit No. 7, Line 4. Exhibit No. I I is attached hereto and
incorporated herein by reference.
XII.
As directed in Commission Order No. 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-I6-02. Exhibit No. l2 summarizes the
amortization and true-up of those costs which are included on Exhibit No. 7, Lines 5 and 6. Exhibit
No. l2 is attached and incorporated by reference.
xrII.
In Commission OrderNo.34099, CaseNo.INT-G-18-01, the Company was directed to defer
and later collect through the PGA the fees associated with in-person customer payments at third party
vendors. Exhibit No. 13 summarizes the customer class surcharges associated with these previously
deferred costs and are included on Exhibit No. 7,Line 7. Exhibit No. l3 is attached and incorporated
by reference.
XIV.
Intermountain has allocated the proposed price changes to each of its customer classes based
upon Intermountain's PGA provision. However, a staight cents per therm price change was not
utilized for the LV-l tariff as no fixed costs are currently recovered in the tail block of the LV-l tariff.
The proposed changes in the WACOG, and variable deferred debits and credits as outlined on Exhibit
INrpRvornqranq Gas CoupaNy's Appt-lcarroN - l0
No. 7, Lines 3 through 7, are applied to all three blocks of the LV-l tariff. However, all adjustments
relating to fixed costs are applied only to the frst two blocks of the LV-l tadff.
xv.
As outlined on Exhibit No. 2, Page 1, Lines 2l through 29,the T-3 and T-4 tariffs include the
following adjustrnents: a) the removal of existing temporary price changes; and b) the inclusion of
proposed temporary price changes from Exhibit No. 7. The net change from these aforementioned
adjustments result in a rate decrease for the Company's T-3 and T-4 customers.
xvl.
The proposed price changes herein requested among the classes of service of Intermountain
reflect a just, fair, and equitable pass-through of changes in gas related costs to Intermountain's
customers.
XVII.
This Application has been brought to the attention of Intermountain's customers through a
Customer Notice and by a Press Release sent to daily and weekly newspapers, and major radio and
television stations in Intermoturtain's service area. The Press Release and Customer Notice are
attached and incorporated by reference. Copies of this Application, its Exhibits, and Workpapers
have been provided to those parties regularly intervening in Intermountain's rate proceedings.
XVIII.
Intermountain requests that this matter be handled r;nder modified procedure pursuant to
Rules 201-204 of the Commission's Rules of Procedure. Intermountain stands ready for immediate
consideration of this matter.
xrx.
lntermountain respectfully petitions the Idaho Public Utilities Commission as follows:
INrgRuotxTAIN GAS COMPA}vY'S AppIICarrON - I I
a. That the proposed rate schedules submitted as Exhibit No. 3 be approved without
suspension and made effective as of October 1,2019 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: August 15,2019.
INTERMOUNTAIN GAS COMPANY GIVENS PURSLEY LLP
By By
Lori Blatbrer Preston N. Carter
Attomey for Intermountain Gas CompanyDirector - Regulatory Affairs
In'renuouurans GAs CotvrPANY's APPUCATIoN - 12
CERTIFICATE OF MAILING
I HEREBY CERTIFY that on August 15,2019,I served a copy of the foregoing Case
No. INT-G-I9-06 upon:
Ed Finklea
Alliance of Westem 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.
Lori A. Blattner
Director - Regulatory Affairs
INTERMOTINTaTN GaS COMPANY,S APPITCAUON - 13
EXHIBIT NO. 1
CASE NO. INT-G.19.06
INTERMOUNTAIN GAS COMPANY
SUMMARY OF PRICE CHANGES
(2 pages)
Exhibit No. 1
Case No. INT-G-19-06
lntermountain Gas Company
Page 1 of 2
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Exhibit No. 1
Case No. INT-G-19-06
lntermountain Gas Company
Page2 ot 2
Line No.Description
INTERTIOUNTAIN GAS COMPANY
ANALYSIS OF INTC.19{'6 PRICE CHAI{GE
Amount Total
(a)
Defenab:
INT-G-'1 &02 Temporaries Reversed
Add INT-G-1 $06 Temporanes:
Fixed Defened Gas Costs
Variable Defened Gas Costs
Lost and Unaccounted For Gas Costs
LNG Sales Credit
Defened General Rate Case Costs and Tax Reform
ln-Person Payment Fees Defenal
Total Temporaries Added
Total Defenals
Base Rate Price Chanoe:
Fixed Cost Changes:
NWP TF-1 Reservation (Full Rate)
NWP TF-1 Reservation (Discounted)
Upstream Capacity (Full Rate)
Upstream Capacity (Discounted)
SGS-2F and LS-2F
Other Storage Facility
Total Fixed Cost Change
Changes in WACOG
Reallocation of Fixed Costs
Total Base Rate Price Changes
Total Annual Price Change
Annual Price Change per Exhibit No. 1, Page 'l
Difference Due to Rounding
(b)(c)
28,780,148 (r)
1
2
3
4
E
6
7
8
o
10
11
12
13
14
15
16
17
'18
19
20
21
22
23
24
$
$ (24,967,380) €)
4,557,004 {3)
171,054 (4)
(1,'r29,239) F)
288,906 G)
93,211 0)
(6,794,231) (14)
(3,638,365) (15)
$ 3,536 (8)
1,053,477 ts)
(53,486) (10)
556,459 (1r)
3,335 (12)
10,200 (13)
1,573,521
(20,986,444)
$ 7,793,704
$ (1,065,371)
$ (1,064,194 (t6)25
26 $ (1,174)
{1) See Workpaper No. 8, Line 2, Columns (b) - (0 times Exhibit No. 1, Page '1, Lines 2 - 4, 7 and g, Column (b)(') See Exhibit No.8, Line 3, Column (b), plus Exhibit N0.9, Line 7, Column (b)(') See Exhibit No. 10, Line 2, Column (b)
(n) See Exhibit No. 10, Line 10 plus Line 18, Column (b)
(u) See Exhibit No. 11 , Line 5, Column (b)
(6) See Exhibit No. 12, Page 1, Line 9, Column (b) plus Exhibit No, 12,Page2, Line 4, Column (b)
(7) See Exhibit No. 13, Line 2, Column (b)(') See Exhibit N0.5, Line 3, Column (h)
(n) See Exhibit No. 5, Line 4, Column (h)
('o) See Exhibit N0.5, Line 5, Column (h)
(11) See Exhibit N0.5, Line 6, Column (h)
(") See Exhibit No. 5, sum of Lines 9 - 1 9, Column (h)
(") See Exhibit N0.5, Line 20, Column (h)
('n) See Exhibit No.5,Line2z,Column (h)
(15) See Exhibit No, 5, Line 28, Columns (i) - (k), times Line 24, Columns (i) - (k)
(16) See Exhibit No, 1, Page 1, Line 11, Column (e)
(8,8s9,075)
EXHIBIT NO.2
CASE NO. INT-G.I9.06
INTERMOUNTAIN GAS COMPANY
CURRENT TARIFFS
Showing Proposed Price Changes
(10 pages)
Exhibit No. 2
Case No. INT-G-19-06
lntermountain Gas Company
Page 1 of 10
No.
INTERTOUNTAIN GAS COiIPANY
Comparison of Proposed October 1,2019 Prices
To October 1, 2018 Prices
Prices per
Case No. INT-G-I8-02
Order No. 34154
Line
1RS
Rate Class
Proposed
Adjustment
Proposed
October 1,2019
Prices
(a)(b)(c)(d)
0.50556$(0.00466)$0.50090$
2
3
4
5
6
7
8
I
GS-1
ls.R (1)
ts.c €)
LV.1
T.3
T.4
Block 1
Block 2
Block 3
Block 4
CNG Fuel
Block 1
Block 2
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
0.215'10
0.03873
0.01589
0.00598
0.28739
0.02395
0.00847
0.00260
0.00085
0.00085
0.0008s
0.00085
0.00085
0.00085
(0.00466)
0.00085
0.00085
0.00085
0.00085
0.00032 (3)
0.00032 (3)
0.00ffi9 (4)
0.51348
0.49000
0.46733
0.39877
0.46733
0.39877
0.51348
0.49000
0.46733
0.39877
0.30000
0 30761
0.28972
0.22349
0.03871
0.01587
0.00596
0.28469
0.02395
0.00847
0.00260
10
11
12
't3
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
(0.00002)
(0.00002)
(0.00002)
6)
(5)
(5)
(o.oo27o)(6)
(') The lS-R price is based on the RS price and receives the same PGA adjusfnents
(2) The lS-C price is based on the GS-1 price and receives the same PGA adjustments
(t) S." workp.p.r No. 6, Line 13, Column (e)
(a) Se" Workpaper No. 6, Line '17, Column (e)
(5) Remove INT-G-18-02 temporary from Workpaper No. 8, Line 5, Column (e) and add temporary
from Exhibit No. 7 Line 8, Column (e)
(6) Remove INT-G-18-02 temporary from Workpaper No. 8, Line 5, Column (f) and add temporary
from Exhibit No. 7 Line 8, Column (f)
0.49723
Exhibit No. 2
Case No. INT-G-19-06
lntermountain Gas Company
Page 2 of 10
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l.P.U.C. Gas Tariff
Rate Schedules
feu*lr Revised ft Sheet No. 1 (Page 1 of 'l)
Name Intermountain Gas Companyol Utility
Exhibit No. 2
Case No. INT-G-19-06
lntermountain Gas Company
Page 3 of l0
IDAHO PUBLIC UTILITIES COMMISSIONApproved EffectiveSep++,+ef+ ee+.ffiit
Per e,N, 34154
Diane M. Hanian Secretary
Rate Schedule RS
RESIDENTIAL SERVICE
APPLICABILITY:
Applicable to any customer using natural gas for residential purposes.
RATE:
Monthly minimum charge is the Cushcmer Charge.
Customer Charge:
Per Therm Charge:
*lncludes the ficlloaing:
Cost of Gas:
$5.50 per bill
€€{€€'56r' $0.50090
1) Temporary purchased gas cost adjustment
2) Weighted aver4e cost of gas
3) Gas transportation cost
{$€€77++} ($0.05573)
$Sm+ $0.20e04{'++8eo+ $0.18087
$0.16305Distribution 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 SeMce Provisions of the Company's Tariff, of
rvhich this rate schedule is a part.
Director Regulatory Affairs
lssued by:
LP.U.C. Gas Tariff
Rate Sctedules
f+Ey+ighth Revised Fiftv-N inth Sheet No. 3 (Page 1 of 2)
Name
of Utility lntermountain Gas Company
Exhibit No. 2
Case No. INT-G-'|9-06
lntermountain Gas Gompany
Page 4 of 10
IDAHO PUBLIC UTILITIES COMMISSIONApproved EffectiveScet+,+erc €e+-{+0{+
Per e-N, 31151
Diane M. Hanian Secretary
Rate Schedule GS-l
GENERAL SERVICE
APPLICABILIW:
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 perday may be served under
this rate schedule upon execution of a one-year written service contract,
RATE:
Monthly minimum charge is the Customer Charge.
Custorner Charge:
Per Therm Charge:
$9.50 per bill
Block One:
Block Two:
Block Three:
Block Four:
Block One:
Block Two:
Block Three:
Block Four:
2(E therms per bill@
1,800 therms per bill@
8,000 therms per bill @
10,000 therms per bill @
{0#26a| $0.51348
-$'fr189{€r $0.4e000
$9'4'6€48'$0.46733
$e397921 $0.3e877
First
Next
Next
Over
'lncludes the folloa/ng:
Cost ofGas:
Distribution Cost:
1) Temporary purchased gas cost adjustment
2) Weighted average cost of gas
3) Gas transportation cost
{90€7698)- ($0.05711)
+ee27*l $0.20904
$0,17772 $0.17690
$0.18465
$0.16117
$0.13850
$0.06994
First
Nerit
Next
Over
200 therms per bill@
1,800 therms per bill @
8,000 therms per bill@
10,000 therms per bill @
tssr.red by: lntermountain Gas Company
By: lrtie#Hile€ruth Lori A. Blattner Tille: Director - Regulatory Affairs
Effaclive'€€toE€H.'.{e1+ October 1. 201 9
l.P.U.C. Gas Tariff
Rate Schedules
+iffiiglrth Revised Fiftv-Ninth Sheet No. 3 (Page 2 of 2)
Neme
ol Utility lntermountain Gas Company
Exhibit No. 2
Case No. INT-G-19-06
lntermountain Gas Company
Page 5 of 10
Rate Schedule GS-{
GENERAL SERVICE
(Continued)
For separately metered deliveries of gas utilized solely as Compressed Natural Gas Fuel in vehicular internal
combustion engines.
Customer Charge: $9.50 per bill
Per Therm Charge:
*lncludes the iclloring;
Cost of Gas:
Distribution Cost:
First 10,000 therms per bill @
Over 10,000 therms per bill @
IDAHO PUBLIC UTILITIES COMMISSIONApproved EffectiveSep+f+,+e* €s+f#{&Pct€ria#ts+
Diane M. Hanian Secretary
$0,46648. $0.46733
$ffi979r $0.39877
{$ef,7eea} ($0.05711)
st,*72f' $0.20e04$ffinz $0.176e0
$0.1 3850
$0.06994
Block One:
Block Two:
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 Tuo: Over 10,000 therms per bill
@
@
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment br 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 wtrich this rate schedule is a part.
BILLING ADJUSTMENTS:
Any GS-1 customer who leaves the GS-1 service will pay to lntermountain Gas Company, upon exiting
the GS-1 service, all gas ard transportation related costs incuned to sene the customer during the
GS-1 service period not paid by the customer during the time the customer was using GS-1 seMce.
Any GS-1 customer who leaves the GS-1 service will have refunded to them, upon exiting the GS-l
seMce, any excess gas commodity or transportation payrnents made by the customer during the tine
they were a GS-1 customer.
tssued by: lntermountaln Gas Company
By:{rlicffiHrte€,ruth Lori A. Blattner Tille: Direclor - Regulatory AfFairsEffeAive:@
1.
LP.U.C. Gas Tariff
Rate Schedules
#iftcen{lr Revised Sixteenth Sheet No. 4 (Paqe 1 of2)
Name
of Utilitv lntermountain Gas Company
Exhibit No. 2
Case No. INT-G-19-06
lntermountain Gas Company
Page 6 of 10
Rate Schedule lS-R
RESIDENTIAL I NTERRUPTIBLE S NOWiJIELT SERVIGE
APPLICABILITY
Applicable to any residential customer otheruise eligible to receive service under Rate Schedule RS who
has added natural gas snowmelt equipnent after 6111201O. The intended use of he snowmelt equipment is
to melt sno,rr and/or ice on sidewalks, drivarays or any other similar appurtenances. Any and all such
applications meeting the above criteria will be sub.iect to service under Rate Schedule tS-R and will be
separately and individually metered. All seruice hereunder is interruptible at the sole discretion of the
Company.
FACILITY REIi'IBURSEMENT CHARGE:
All new interruptible Snowmelt seMce 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.
RATEI
Monthly minimum charge is the CustomerCharge.
Customer Charge:
Per Therm Charge:
*lncludes the follolt/ng:
Cost of Gas:
$5.50 per bill
ll€5etE9* $0.49723
1) Temporary purchased gas cost adjustment
2) Weighte<l alerage cost of gas
3) Gas transportation cost
IDAHO PUBLlC UTILITIES COMMISSIONApproved EffectiveScet+,+gf+ e€t#'4+8
F€r€Elld+|54
Diane ltl. Hanian Secretary
{$€€+74{t ($0.05573)
$0J;2?2+ $0.20904
$€:t8ge+ $0.18087
Distribution Cost:$0 16305
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adfustment for cost of purchased gas as provided br in the Company's Purchased
Gas Cost Adjustment Schedule.
lssued by:lntermountain Gas Company
+rielrrc+Pjttectath Title: Director - Regulatory Affairs
Exhibit No. 2
Case No. INT-G-19-06
lntermountain Gas Company
l.P.U.C. Gas Tariff
Rate Schedules
+ifieenfh Revised Sixteenth Sheet No. 5 (Paqe 1 of 2)
Name
of Utility lntermountain Gas Company
7ollO
IDAHO PUBLIC UTILITIES COMMISSIONApproved Effectiveecet-e€#1t ect+,+t+ffi.{ttt'ttl5#
Diane M. Hanian Secretary
Rate Schedule ISC
SMALL COMMERICAL INTERRUPTIBLE SNOWMELT SERVICE
APPLICABILITY:
Applicable to any customer otheruvise eligible to receive gas service under Rate Schedule GS-1 who has
added natural gas sno/vmelt equipment after 6/12010. The intended use of the sno^/melt 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 seMce hereunder is intenuptible at the sole discretion of the
Company.
FACILITY REITIBURSE]I'ENT CHARGE :
All new interruptible Snowmelt seryice 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
*lncludes the bllowing:
Cost of Gas:
Distribution Charge:
1) Temporary purch*ed gas cost adjustment
2) Weighted average cost of gas
3) Gas transportation 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@
t0*t263* $0.51348te*8grr $0.4e000
{0i46e$, $0.46733.$€f,O7e? $0.39877
First
Next
Next
Over
First
Next
Next
Over
200 therms per bill @
1,800 therms per bill @
8,000 therms per bill @
10,000 therms per bill @
($o€769Ef ($0.0s711)
$gz?n+ $0.20e04
$e.a#+ $0.176e0
$0.1846s
$0.161 17
$0.13850
$0.06994
tssued by: lntermountain Gas Company
Tille: Direc-tor - Regulatory Affairs
l.P.U.C. Gas Tariff
Rate Schedules
Sixffiixth Rev;sed Sixty'Seventh Sheet No.7 (Paqe 1 of2)
Name
ol Utility lntermountain Gas Company
Exhibit No. 2
Case No. INT-G-19-06
lntermountain Gas Company
Page 8 of 10
IDAHO PUBLIC UTILITIES COMMISSIONApproved Effective+et+rOl& eeg#t+
ft!€lffi
Diane M. Hanian Secretary
Rate Schedule LV-l
LARGE VOLUME FIRi,I SALES SERVICE
AVAILABILITY:
Available at any mutually agreeable delivery point on the Company's distribution system to any existing
customer receiving seMce under the Company's rate schedule LV-l or any customer not previously served
under this schedule whose usage does not exceed 500,000 therms annually, upon execution of a one.year
minimum written service contract trr firm sales service in excess of 200,000 therms per year.
ITIONTHLY RATE:
Demand Charge: $0.30000 per MDFQ therm
Per Therm Charge: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 @
$ffi0729s $0.30761
lE9r894e. $0.28972
$e*f3fe, $0.22349
'lncludes the following:
Cost of Gas:'l) Temporary purchased gas cost adjustment
Block One and Trirro
Block Three
2) Weighted average cost of gas
3) Gas transportation cost (Block One and Two only)
{$Ooq€,ES}($o€{sEt}$e%
te.es58e
$0.03000
$0.01211
$0,00307
($0.02725)
$0.01 138
$0.20904
$0.09582
Distribution Cost:
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjusfrnent br cost of purchased gas as provided icr in the Company's Purchased
Gas Cost Adjustment Schedule.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the Company's
Tariff, of which this Rate Schedule is a part.
The customer shall negotiate with the Company, a mutually agreeable Maximum Daily Firm Quantity
(MDFO) amount, which will be stated in and will be in effect throughout the term of the service
contract.
ln the event the Customer requires daily usage in excess of the MDFQ, and subject to the
availability of firm interstate transportation to serve lntermountain's system, all such excess
usage will be billed under rate schedule LV-1. Additionally, all excess MDFQ above the customer's
contracted MDFQ for the month will be billed at the monthly Demand Charge rate.
lssued by:
Title: Direclor - Regulatory Affairs
October 1.2019
First
Next
Over
250,000 therms per bill @
500,000 therms per bill @
750,000 therms per bill@
2.
Exhibit No. 2
Case No. INT-G-19-06
lntermountain Gas Company
Page 9 of 10
l.P.U.C. Gas Tarifi
Rate Schedules
€ovcntecn{r Revised Eiohteenth Sheet No. 8 (Paqe 1 of 2)
lntermountain Gas CompanyName
of Utilitv
First
Next
Over
IDAHO PUBLIC UTILITIES COMMISSIONApproved EffectiveSceme,+e+8 €e+.{#48fa-*iH*16*
Diane M. Hanian Secretary
Rate Schedule T3
INTERRUPTIBLE DISTRIBUTION TRANSPORTATION SERVICE
AVAILABILITY:
Available at any point on the Company's distribution system to any customer upon execution of a one year
minimum wri$en seMce contract.
MONTHLY RATE:
Per Therm Charge: Block One:
Block Two:
Block Three:
*lncludes temporary purchased gas cost adjustment of$€€992$ $0.00018
ANNUAL ilIINIMUM 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 CGt Adjustment Schedule.
SERVICE CONDITIONS:
The Company, in its sole discretion, shall determine whether or not it has adequate capacity to
accommodate transportation of the custome/s gas supply on the Company's distribution system.
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.
lntonuptible Distribution Transportation SeMce may be made firm by a written agreement between
the parties if the customer has a dedicated line.
lf requested by the Company, the customer expressly agrees to immediately curtail or interrupt its
operations during periods of capacity constraints on the Company's distribution system.
This service does not include the cost of the custome/s gas supply or the interstate pipeline capacity.
The customer is responsible for procuring its own supply of natural gas and transportation to
lntermountiain's distribution system under this rate.
The customer understiands 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.
I 00,000 therms transported @ $OS3€#3' $0.03871
50,000 therms transported @ $€€{€8€r $0.01587
1 50,000 therms transported @ $€€e5e&' $0'00596
2.
3.
4.
5.
6.
7.
rssuecr bv: lntermountain Gas Gompanv
By:l/liehaelsk€rutF LoJi A'.Blatlnet . - titte, 6irector - Regulatory Afiairs
Eifective:€eto,berffi+& October 1. 201 9
l.P.U.C. Gas Tariff
Rate Schedules
€irft cntl.r Revised Sg!g!@dh Sheet No. 9 (Pase 1 of 2)
Name
of Utility lntermountain Gae Company
Exhibit No. 2
Case No. INT-G-19-06
lntermountain Gas Company
Page 10 of 10
IDAHO PUBLIC UTILITIES COMMISSIONApproved EffectiveSee+re# €ct#4+
ffi.11:-3{rf5*
Diane M. Hanian Secretary
Rate Schedule T-,[
FIRM DISTRIBUTION ONLY TRANSPORTATION SERVICE
AVAII.ABILITY:
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 seMce in
excess of 200,000 therms per year.
IIIONTHLY RATE:
Demand Charge:$0*8#39 per MDFQ therm' $0'28469
Per Therm Charge:
*lncludes temporary purchased gas cost adjustment of {$S€{26+} ($0.01531)
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment ficr cost of purchased gas as provided for in the Company's Purchased
Gas Cost Adjustment Schedule.
SERVICE CONDITIONS:
1. This service excludes the service and cost of firm interstate pipeline charges.
2. The customer is responsible for procuring its own supply of natural gas and interstate transportation
under this Rate Schedule. The customer understands and agrees that the Company is not
responsible to deliver gas supplies to the customer which have not been nominated, scheduled, and
delivered by the interstate pipeline to the designated city gate
3, All natural gas service hereunder is subject to the General Service Provisions of the Company's
Tariff, of which this Rate Schedule is a part.
4. The customer shall negotiate with the Company, a mutually agreeable Maximum Daily Firm Quantity
(MDFO), which will be stated in and in effect throughout the term of the service contract.
5. The monthly demand charge will be equal to the MDFQ times the demand charge rate. Demand
charge relief will be afforded to those T.4 customers when circumstances impacted by force majeure
events prevent the Company from delivering natural gas to the customer's meter.
An existing LV-1 or T-3 customer elecling this schedule may concurrently utilize Rate Schedule T.4
on the customels same or contiguous property.
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
6.
lssued by: lntermountain Gas Gompany
By:+ti€haclH+c€irth Lori A. Blattner Title: Direclor - Regulatory Affairs
Eilective:€eteber-{#t& October 1' 201 I
EXHIBIT NO.3
CASE NO. INT.G.19.O6
INTERMOUNTAIN GAS COMPANY
PROPOSED TARIFFS
(8 pages)
LP.U.C. Gas Tariff
Rate Schedules
Fifth Revised Sheet No. 1 (Page 1 of 1)
Name
of Utility lntermountain Gas Gompany
Exhibit No. 3
Case No. INT-G-19-06
lntermountain Gas Company
Page 1 of8
Rate Schedule RS
RESIDENTIAL SERVICE
APPLICABILIW:
Applicable to any customer using naturalgas for residential purposes.
RATE:
Monthly minimum charge is the Customer Charge.
Customer Charge:
Per Therm Charge:
*lncludes the following
Cost of Gas:
$5.50 per bill
$0.50090*
1) Temporary purchased gas cost adjustment
2) Weighted average cost of gas
3) Gas transportation cost
($0.05573)
$0.20904
$0.18087
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 Efflciency Charge is separately stated on customer bills.
SERVICE GONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the Company's Tariff, of
which this rate schedule is a part.
rssued by: lntermountain Gas Company
By: Lori A. Blattner Title: Director - Regulatory Affairs
Effective: October 1, 2019
l.P.U.C. Gas Tariff
Rate Schedules
Fifty-Ninth Revised Sheet No.3 (Page 1 ol 2)
Name
of Utility lntermountain Gas Company
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
1) Temporary purchased gas cost adjustment
2) Weighted average cost of gas
3) Gas transportation cost
200 therms per bill @
1,800 therms per bill @
8,000 therms per bill@
10,000 therms per bill @
200 therms per bill @
1,800 therms per bill @
8,000 therms per bill @
10,000 therms per bill @
Exhibit No. 3
Case No. INT-G-19-06
lntermountain Gas Company
Page 2 of 8
$0.51348*
$0.49000.
$0.46733.
$0.39877.
($0.0571 1)
$0.20904
$0.17690
$0.1 8465
$0.16117
$0.1 3850
$0.06994
Distribution Cost:
Block One:
Block Two:
Block Three:
Block Four:
Block One:
Block Two:
Block Three
Block Four:
First
Next
Next
Over
First
Next
Next
Over
lssued by: lntermountain Gas Gompany
By: Lori A. Blattner Title: Director - Regulatory Affairs
Effective: October 1, 2019
*lncludes the following:
Cost of Gas:
l.P.U.C. Gas Tariff
Rate Schedules
Fifty-Ninth Revised Sheet No. 3 (Page 2 of 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:
*l ncludes the following
Cost of Gas:
Distribution Cost:
First 10,000 therms per bill @
Over 10,000 therms per bill @
Exhibit No. 3
Case No. INT-G-19-06
lntermountain Gas Company
Page 3 of 8
$0.46733.
$0.39877.
($0.05711)
$0.20904
$0.1 7690
$0.1 3850
$0.06994
Block One:
Block Two:
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-1 customer who leaves the GS-1 service will pay to lntermountain Gas Company, upon exiting
the GS-1 service, all gas and transportation related costs incurred to serve the customer during the
GS-1 service period not paid by the customer during the time the customer was using GS-1 service.
Any GS-1 customer who leaves the GS-1 service will have refunded to them, upon exiting the GS-1
service, any excess gas commodity or transportation payments made by the customer during the time
they were a GS-1 customer.
lssued by: lntermountain Gas Company
By: Lori A. Blattner Title: Director - Regulatory Affairs
Effective: October 1, 2019
1.
l.P.U.C. Gas Tariff
Rate Schedules
Sixteenth Revised Sheet No. 4 (Page 1 of 2)
Name
of Utility lntermountain Gas Company
Exhibit No. 3
Case No. INT-G-19-06
lntermountain Gas Company
Page 4 of 8
Rate Schedule !S-R
RESIDENTIAL INTERRUPTIBLE SNOWMELT SERVICE
APPLICABIL!TY:
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 GHARGE:
All new interruptible Snowmelt service customers are required to pay for the cost of the Snowmelt meter set
and other related facility and equipment costs, prior to the installation of the meter set. Any request to alter
the physical location of the meter set and related facilities from Company's initial design may be granted
provided, however, the Company can reasonably accommodate said relocation and Customer agrees to
pay 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
$0.49723.
1) Temporary purchased gas cost adjustment
2) Weighted average cost of gas
3) Gas transportation cost
($0.05573)
$0.20904
$0.18087
Distribution Cost:$0.1630s
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: Lori A. Blattner Title: Director - Regulatory Affairs
Effective: October 1, 2019
l.P.U.C. Gas Tariff
Rate Schedules
Sixteenth Revised Sheet No. 5 (Paqe 1 of2)
Name
of Utility lntermountain Gas Company
1) Temporary purchased gas cost adjustment
2) Weighted average cost of gas
3) Gas transportation cost
200 therms per bill @
1,800 therms per bill @
8,000 therms per bill @
10,000 therms per bill @
200 therms per bill@
1,800 therms per bill @
8,000 therms per bill @
10,000 therms per bill @
Exhibit No. 3
Case No. INT-G-19-06
lntermountain Gas Company
Page 5 of 8
$0.51348.
$0.49000.
$0.46733.
$0.39877.
($0.0571 1)
$0.20904
$0.17690
$0.1 8465
$0.1 61 1 7
$0.1 3850
$0.06994
Rate Schedule lS-C
SMALL COMMERICAL INTERRUPTIBLE SNOWMELT SERVICE
APPLICABILITY:
Applicable to any customer otherwise eligible to receive gas service under Rate Schedule GS-1 who has
added natural gas snowmelt equipment after 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
allrelated costs.
RATE:
Monthly minimum charge is the Customer Charge
Customer Charge:
Per Therm Charge:
$9.50 per bill
Block One:
Block Two:
Block Three:
Block Four:
Block One:
Block Two:
Block Three:
Block Four:
First
Next
Next
Over
First
Next
Next
Over
lssued by: lntermountain Gas Gompany
By: Lori A. Blaftner Title: Director - Regulatory Affairs
Effective: October 1, 2019
*lncludes the following:
Cost of Gas:
Distribution Charge:
|.P.U.C. Gas Tariff
Rate Schedules
Sixty-Seventh Revised Sheet No.7 (Paqe 1 of2)
Name
of Utilitv lntermountain Gas Company
Rate Schedule LV-l
LARGE VOLUME FIRM SALES SERVICE
AVAILAB!LIW:
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-19-06
lntermountain Gas Company
Page 6 of 8
$0.30761*
$0.28972*
$0.22349.
Block One:
Block Two:
Block Three:
Block One:
Block Two:
Block Three
First
Next
Over
*lncludes the following
Cost of Gas:
Distribution Cost:
1) Temporary purchased gas cost adjustment
Block One and Two
Block Three
2) Weighted average cost of gas
3) Gas transportation cost (Block One and Two only)
($0.02725)
$0.01138
$0.20904
$0.09582
$0.03000
$0.01211
$0.00307
First
Next
Over
250,000 therms per bill @
500,000 therms per bill @
750,000 therms per bill @
1
2.
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company's Purchased
Gas Cost Adjustment Schedule.
SERVIGE 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.
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 flrm 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.
lssued by: lntermountain Gas Company
By: Lori A. Blattner Title: Director - Regulatory Affairs
Effective: October 1, 2019
l.P.U.C. Gas Tariff
Rate Schedules
Eiqhteenth Revised Sheet No.8 (Pase 1 of 2\
Name
of Utilitv lntermountain Gas Company
Exhibit No. 3
Case No. INT-G-19-06
lntermountain Gas Company
Page 7 of 8
Rate Schedule T-3
INTERRUPTIBLE DISTRIBUTION TRANSPORTATION SERVICE
AVAILABIL!TY:
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 @ $0.03871.
50,000 therms transported @ $0.01587.
150,000 therms transported @ $0.00596.
1
2
*lncludes temporary purchased gas cost adjustment of $0.00018
ANNUAL MINIMUM BILL:
The customer shall be subject to the payment of an annual minimum bill of $30,000 during each annual
contract period, unless a higher minimum is required under the service contract to cover special conditions.
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company's Purchased
Gas Cost Adjustment Schedule.
SERVICE CONDITIONS:
The Company, in its sole discretion, shall determine whether or not it has adequate capacity to
accommodate transportation of the customer's gas supply on the Company's distribution system.
All natural gas service hereunder is subject to the General Service Provisions of the Company's
Tariff, of which this Rate Schedule is a part.
lnterruptible Distribution Transportation Service may be made firm by a written agreement between
the parties if the customer has a dedicated line.
lf requested by the Company, the customer expressly agrees to immediately curtail or interrupt its
operations during periods of capacity constraints on the Company's distribution system.
This service does not include the cost of the customer's gas supply or the interstate pipeline capacity.
The customer is responsible for procuring its own supply of natural gas and transportation to
lntermountain's distribution system under this rate.
The customer understands and agrees that the Company is not responsible to deliver gas supplies
to the customer which have not been nominated and accepted for delivery by the interstate pipeline.
An existing T4 customer electing this schedule may concurrently utilize Rate Schedule T-3 on the
same or contiguous property.
tssued by: lntermountain Gas Company
By: Lori A. Blattner Title: Director - Regulatory Affairs
Effective: October 1, 201 I
3.
4.
5.
6.
7
l.P.U.C. Gas Tariff
Rate Schedules
Seventeenth Revised Sheet No.9 (Paqe 1 of 2)
Name
of Utility lntermountain Gas Company
Exhibit No. 3
Case No. INT-G-19-06
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.
IT,IONTHLY RATE
Demand Charge:$0.28469 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
3.
4.
5.
*lncludes temporary purchased gas cost adjustment of ($0.01531)
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company's Purchased
Gas Cost Adjustment Schedule.
SERVICE CONDITIONS:
1. This service excludes the service and cost of firm interstate pipeline charges.
2.The customer is responsible for procuring its own supply of natural gas and interstate transportation
under this Rate Schedule. The customer understands and agrees that the Company is not
responsible to deliver gas supplies to the customer which have not been nominated, scheduled, and
delivered by the interstate pipeline to the designated city gate.
All natural gas service hereunder is subject to the General Service Provisions of the Company's
Tariff, of which this Rate Schedule is a part.
The customer shall negotiate with the Company, a mutually agreeable Maximum Daily Firm Quantity
(MDFQ), which will be stated in and in effect throughout the term of the service contract.
The monthly demand charge will be equal to the MDFQ times the demand charge rate. Demand
charge relief will be afforded to those T-4 customers when circumstances impacted by force majeure
events prevent the Company from delivering natural gas to the customer's meter.
An existing LV-1 or T-3 customer electing this schedule may concurrently utilize Rate Schedule T4
on the customer's same or contiguous property.
tssued by: lntermountain Gas Gompany
By: Lori A. Blattner Title: Director - Regulatory Affairs
Effective: October 1, 2019
o
EXHIBIT NO.4
CASE NO. INT.G.19-06
INTERMOUNTAIN GAS COMPANY
PERTINENT EXCERPTS PERTAINING TO INTERSTATE PIPELINES AND RELATED
FACILITIES
(34 pages)
Exhibit No. 4
Case No. INT-G-19-06
lntermountain Gas Company
Page 1 of34
(7 pages)
NORTHWEST PIPELINE LLC
Exhibit No. 4
Case No. INT-G-19-06
lntermountain Gas Company
Page 2 ot 34
20180928-3073 FERC PDF (Unofflcial) 09/28/20t8
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 7-346-003
September 28, 201 8
Northwest Pipeline LLC
P.O. Box 58900
Salt Lake City, Utah 84158-0900
Attention: David J. Madsen, Director
Business Development & Regulatory Affairs
Reference: Compliance Filing to Place Phase 2 Settlement Rates Into Effect
Dear Mr. Madsen:
On August 30,2018, Northwest Pipeline LLC (Northwest) filed revised tariff
recordsr to its FERC Gas Tariff. Northwest states that on January 23,2017, it filed a
petition for approval of a Stipulation and Settlement Agreement (Settlement) for Phase I
rates to become effective January l, 2018 and Phase 2 rates to become effective October
l, 2018. Northwest states that in an order dated August 18,2017 in Docket No. RPlT-
346-000 (Settlement Order), the Commission approved the Settlement and directed
Northwest to file tariff records consistent with lhe pro forma tariff rccords included in the
Settlement. In compliance with the Settlement Order, Northwest states it filed tariff
records implementing Phase I Rates in Appendix B of the Settlement on November 28,
2017, with an order issued by the Commission on December 19,2017 approving the
November 28,2017 compliance filing. In the instant filing, Northwest states that it is
t See Appendix.
Exhibit No. 4
Case No. INT-G-19-06
lntermountain Gas Company
Page 3 of 34
20180928-3073 FERC PDF (unofficial,) 09/28/2018
Docket No. RPI 7-346-003 -2-
requesting for acceptance of tadff records proposing to implement Phase 2 Rates
consistent with those identified in Appendix C of the Settlement, to be effective October
l, 2018. The referenced tariffrecords are accepted, effective October l, 2018, as
proposed.
Public notice of the filing was issued on September 4,2018. Interventions and
protests were due as provided in section 154.210 of the Commission's regulations (18
C.F.R. $ 154.210(2018)). PursuanttoRule2l4(18 C.F.R. $385.214(2018)),alltimely
filed motions to intervene and any unopposed motion to intervene out-of-time filed
before the issuance date ofthis order are granted. Granting late intervention at this stage
of the proceeding will not disrupt the proceeding or place additional burdens on existing
parties. No protests or adverse comments were filed.
This acceptance for filing shall not be construed as a waiver of the requirements of
section 7 of the Natural Gas Act, as amended; nor shall it be construed as constituting
approval of the referenced filing or of any rate, charge, classification, or any rule,
regulation, or practice affecting such rate or service contained in your tariff, nor shall
such acceptance be deemed as recognition of any claimed contractual right or obligation
associated therewith; and such acceptance is without prejudice to any findings or orders
which have been or may hereafter be made by the Commission in any proceeding now
pending or hereafter instituted by or against your company.
This order constitutes final agency action. Requests for rehearing by the
Commission may be filed within 30 days of the date of issuance of this order, pursuant to
l8 c.F.R. $ 38s.713 (2018).
Issued by: Marsha K. Palazz| Director, Division of Pipeline Regulation
Exhibit No. 4
Case No. INT-G-19-06
lntermountain Gas Company
Page 4 of 34
Northwest Pipeline LLC
FERC Gas Teriff
Fifth Revised Volume No. I
Ninth Revised Sheet No. 5
Superseding
Eighth Revised Sheet No.5
STATEMEMT OF RATESEffective Rates AppLicable t,o
Rate Schedules TF-1, TF-2, TI-1, TFL-1 and TIL-l-(Dofl-ars per Dth)
Rate Schedule and
Type of Rat.e
Ratse Schedule TF-1 (a) (5)
Reservation(Large Customer)
System-wide
25 Year Evergreen Exp.
vol-umecric (2)
(Large Customer)
System-wide
25 Year Evergreen Exp.
(Smal-l- Customer) (6)
Scheduled overrun (2)
Rate Schedule TF-2 (a) (5)
Reservation
volumetsric
scheduled Daily overrun
Annual Overrun
Ratse Schedul-e TI-1 (2)
volumetrj-c ( 7 )
Rate Schedul-e TFL-1 (a) (5)
Reservation
volumetric (2)
Scheduled Overrun (2)
Rate schedule TrL-1 (2)
volumetric
Base
Tariff Rate(1), (3)
Minimum Maximum
00832
00832
00832 .6942'.7
00832 .39865
00000
00000
39033
32039
39033
00832
3 985s
3 9855
00832
00832
.00000
.00832
.00832
.00832
00832 .39855
Exhibit No. 4
Case No. INT-G-19-06
lntermountain Gas Company
Page 5 of 34
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. I
(4)
Seventh Revised Sheet No. 5-C
Superseding
Sixth Revised Sheet No. 5-C
STATEMENT OF RATES (Continued)
Effective Rates Applicable to
Rate Schedules TF-1, TF-2, TI-1, TFL-1 and TIL-1 (Continued)
(Dol-lars per Dth)
Footnotes (Continued)
Al-1 reservation rates are daily rates computed on the basis of 355 daysper year, except that such rates for leap years are computed on the
basis of 355 days.
For Rate Schedule TF-1, the 25-Year Evergreen Expansion reservation and
volumetric rates appfy to Shippers receiving service under Rate
Schedule TF-1 Evergreen Expansion service agreements. The System-Wide
reservation and volumetric rates apply to Shippers receivj-ng service
under all other Rate Schedule TF-1 service agreements.
For Rate schedule TF-1, the 25-Year Evergreen Expansion maximum base
tariff reservation rate is comprised of $0.31503 for transmission costs
and $0.00435 for storage cost.s. The System-wide maximum base tariff
reservation rate for RaEe Schedule TF-l- and tshe maximum base tariff
reservation rate for Rate schedul-e TF-2 are comprised of $0.38597 for
transmission costs and $0.00435 for storage costs.
For RaEe Schedule TF-1 (Large Customer), the maximum base tarj.ff
volumetric rates applicable to Shippers receiving service under Rate
Schedule TF-l- Evergreen Expansion service agreements are comprised of
$0.00806 for transmission costs and $0.00025 for storage costs. The
maximum base tariff volumetric rates for al-I other services under Ratse
Schedule TF-l- (Larqe Customer) and for servj-ces under Rate Schedule TF-
2 are comprised of $0.00805 for transmission costs and $0.00025 for
storage costs.
Exhibit No. 4
Case No. INT-G-'I9-06
lntermountain Gas Company
Page 6 of 34
20190312-3054 FERC PDF (Unofficial) 03/12/2079
FEDERAL ENERGY REGULATORY COMMISSION
WASHINGTON, DC 20426
OFFICE OF ENERGY MARKET REGULATION
In Reply Refer To:
Letter Order Pursuant to $ 375.307
Northwest Pipeline LLC
Docket No. RP I 9-705-000
March 12,2019
Northwest Pipeline LLC
P.O. Box 58900
Salt Lake City, Utah 84158-0900
Attention: David J. Madsen, Director
Business Development & Regulatory Affairs
Reference: 2019 Fuel Factor Filing
Dear Mr. Madsen:
On February 27 , 2019, Northwest Pipeline LLC filed a revised tariff recordr to
comply with sections 14.12 and 14.20 of the General Terms and Conditions in its tariff,
which requires adjustment to its fuel reimbursement factors by April I of each year. The
referenced tariffrecord is accepted effective April 1,2019, as proposed.
Public notice of the filing was issued on February 28,2019. Interventions and
protests were due as provided in section 154.210 of the Commission's regulations (18
C.F.R $ 154.210 (2018)). Pursuant to Rule 214 (18 C.F.R. $ 385.214 (2018)), all timely
filed motions to intervene and any unopposed motion to intervene out-of-time filed
before the issuance date ofthis order are granted. Granting late intervention at this stage
of the proceeding will not disrupt the proceeding or place additional burdens on existing
parties. No protests or adverse comments were filed.
This acceptance for filing shall not be construed as a waiver of the requirements of
section 7 of the Natural Gas Act, as amended; nor shall it be construed as constituting
approval of the referenced filing or of any rate, charge, classification, or any rule,
I Northwest Pipeline LLC, FERC NGA Gas Tariff, Fifth Revised Volume No. 1, Sheet
No. 14. Fuel Use Factors.24.0.0.
Exhibit No. 4
Case No. INT-G-19-06
lntermountain Gas Company
Page 7 of 34
201-90312-3054 FERC pDF (Unofficiall 03/12/20]-9
Docket No. RP 1 9-705-000 -2-
regulation, or practice affecting such rate or service contained in your tariff; nor shall
such acceptance be deemed as recognition of any claimed contractual right or obligation
associated therewith; and such acceptance is without prejudice to any findings or orders
which have been or may hereafter be made by the Commission in any proceeding now
pending or hereafter instituted by or against your company.
This order constitutes final agency action. Requests for rehearing by the
Commission may be filed within 30 days of the date of issuance of this order, pursuant to
l8 c.F.R. $ 38s.713 (2018).
Issued by: Marsha K. Palazzi, Director, Division of Pipeline Regulation
Exhibit No. 4
Case No. INT-G-19-06
lntermountain Gas Company
Page 8 of 34
Northwest Pipeline LLC
FERC Gas Trriff
Fifth Revised Volume No. I
Rate schedules TF-1,, TF-2, TI-1, and DEX-l-
Rate Schedule TF-1 - Evergreen Expansion
IncremenEal Surcharge (1)
Ratse Schedule TFL-1
Rate schedule TIL-L
Rate Schedules SGS-2F and SGS-2I
Rate schedules Ls-2F, Ls-3F and LS-2r
LiquefactionvaporizaEion
Rate Schedule LD-41
LiquefacEion
Twenty-Fourth Revised Sheet No. 14
Superseding
Twenty-Third Revised Sheet No. l4
t.642
o.r_o*
0.24,6
STATEMENT OF FUEL USE REQUIREMENTS FACTORS
FOR REIMBURSEMENT OF FUEL USE
Applicable to Transportation Service Rendered Under
Rate Schedules Cont.ained in this Tariff, Fifth Revised volume No. i.
The rates set forth on Sheet Nos. 5, 6, 7, I and 8-A are exclusive offuel use requirements. Shipper shall reimburse Transporter in-kind for itsfuel use requirements in accordance with Section 14 of the General Terms and
Conditions contained herein.
The fuel use reimbursement furnished by Shippers shall be as followsfor the applicable Rate Schedules included in this Tariff:
0.98t
0.53t
0.98t
The fuel use factors set forth above sha11 be calculated and adjusted
as explained in Section 14 of the ceneral Terms and Conditions. Fuelreimbursement quantities to be supplied by Shippers to Transporter shal1 bedetermined by applying the factors set forth above t.o the quantity of gas
nominated for receipt by Transporter from Shipper for transportation,
.fackson Prairie injection, Plymouth Liquefaction, Pl-ymouth vaporization, orfor deferred exchange, as applicabJ.e.
Footnote
(1) In addition to the Rate Schedule TF-1 fuel- use requirements factor, theEvergreen Expansion Incremental Surcharge will appl-y to the quant,ity of gas
nominated for receipt at the Sumas, SIPf or Pacific Pool receipt points under
Evergreen Expansion service agreements.
Exhibit No. 4
Case No. INT-G-19-06
lntermountain Gas Company
Page 9 of 34
NOVA GAS TRANSMISSION LTD.
(6 pages)
Exhibit No. 4
Case No. INT-G-19-06
lntermountain Gas Company
Page 10 of34
National Energy
Board
Office national
de l'6nergie
ORDER TG-002-2019
IN THE MATTER OF an application by NOVA Gas
Transmission Ltd. (NGTL) dated 3 April 2019 for approval
of the Final 2019 Rates, Tolls and Charges for the NGTL
System pursuant to Part I and Part IV of the Act, filed with
the National Energy Board (Board) under
File OF-Tolls-Group I -N08l-2019-02 01.
BEFORE the Board on24 April20l9.
WHEREAS on 3 April 2019, NGTL filed an application for an Order approving final2019
rates, tolls and charges for services on the NGTL System (Final 2019 Tolls);
AND WHEREAS NGTL advised the Board that the applied-for Final 2019 Tolls have been
determined in accordance with the 2018-2019 Revenue Requirement Settlement approved by Board
Order TG-004-2018 on 19 June 2018 and the existing rate design methodology approved in
Order TG-04-2010;
AND WHEREAS the Final 2019, Tolls include rates, tolls and charges for services on the North
Montney Mainline (NMML) facilities that have been calculated in accordance with
Order TG-003-201 8 under the Provisional Period, as defined in the MH-03 l-2017 Reasons for
Decision;
AND WHEREAS tolls on the NMML facilities are proposed to be made final through this
Application solely for the Provisional Period and final tolls on the NMML for the Post-
Provisional Phase will reflect the disposition of the Board on NGTL's proposed NMML Tolling
Methodology, as applied for in the NGTL System Rate Design and Services Application filed on
l4 March 2019;
AND WHEREAS NGTL is currently operating under interim tolls effective I January 2019
approved by the Board in Order TGI-004-201 8 on 13 November 201 8;
AND WHEREAS on 23 April2019, NGTL filed corrections to the interim tolls for eight receipt
meter stations, due to an administrative error;
.t2
C"anad?I
IN THE MATTER OF the National Energt Board Act
(the Act) and the regulations made thereunder; and
Exhibit No. 4
Case No. INT-G-19-06
lntermountain Gas Company
Page 11 of34
-2-
AND WHEREAS NGTL advised the Board that it proposes to dispose of a variance between
the revenue requirements used for Final 2019 Tolls and interim 2019 tolls through an adjustment
of the Final 2019 Tolls and that NGTL discussed this approach with the Tolls, Tariff, Facilities
and Procedures Committee (TTFP) in March 2019 and no concerns were raised;
AND WHEREAS NGTL proposes to set Final 2019 Tolls effective I May 2019, or the first day
of the month at least l0 days following Board approval of the Application (Effective Date);
AND WHEREAS no party has opposed the Application;
AND WHEREAS the Board has considered NGTL's Application and is satisfied that the
applied-for Final 2019 Tolls arejust and reasonable;
THEREFORE, IT IS ORDERED pursuant to Part I and Pan IV of the Act, that:
I . The interim tolls, as revised, authorized in Order TGI-004-201 8 for the period
I January 2019 to the day prior to the Effective Date of the Final 2019 Tolls are approved
as final;
2. The applied-for Final 2019 Tolls from the Effective Date to 3 I December 2019, with the
exception of the tolls on the NMML facilities, are approved as final;
3. The applied-for Final 2019 Tolls from the Effective Date to the last day of the
Provisional Period for tolls on the NMML facilities are approved as final.
NATIONAL ENERGY BOARD
Original signed by L. George for
Sheri Young
Secretary ofthe Board
TG-002-2019
Exhibit No. 4
Case No. INT-G-19-06
lntermountain Gas Company
Page 12 ol 34
NOVA Gas Transmission Ltd
Final 2019 Delivery Point Rates
2000
31111
31110
31112
3002
1 958
3886
6404
ALBERTA-B.C. BORDER
ALLIANCE CLAIRMONT INTERCONNECT APN
ALLIANCE EDSON INTERCONNECT APN
ALLIANCE SHELL CREEK INTERCONNECT APGC
BOUNDARY LAKE BORDER
EMPRESS BORDER
GORDONDALE BORDER
MCNEILL BORDER
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
BAY TREE SALES
BEAR CREEK COGEN SALES APGP
BEAR RIVER WEST SALES
5.48
5.48
5.48
5.48
5.48
5.79
5.48
5.79
Attachment 2
Delivery Point Rates
Page 1 of 11
0.1982
0.1 982
0.1 982
0.1982
0.1 982
0.2094
0.1982
0.2094
0.1982
0.1 982
0.1982
0.1 982
0.1 982
0.1 982
0.1 982
0.1982
0. 1 982
0.1982
0.1 982
0.1 982
0.1 982
0.1982
0.1 982
0.1982
0.1 982
0.1982
0.1982
0.1982
0.1982
0.1982
0.1982
0.1 982
0.1 982
0.1 982
0.1982
0.1982
Yes
Yes
Yes
Yes2
Yes
Yes2
Yes
31 000
3't001
3880
31 003
3't002
31 004
31 005
31 006
3214
31 007
31 008
3868
3297
3059
31 009
3562
31012
3488
3237
3662
3216
31 35
3288
3423
31 013
6112
31014
3299
5.48
s.48
5.48
5.48
5.48
5.48
5.48
5.48
5.48
5.48
5.48
5.48
5.48
5.48
5.48
5.48
5.48
5.48
5.48
5.48
5.48
5.48
5.48
5.48
5.48
5.48
5.48
5.48
Group 1
Dellvery
Point
Number
Group 1 Delivery Polnt Name
FT-D Demand Rate
Prlce Polnt "2"
($GJ/mo)
lT-D Rate
($rGJ/d)
Group 2
Delivery
Point
Number
Group 2 Oelivery Polnt Name
FT-D Demand Rate
Prlce Point "Z"
($/GJ/mo;
lT-D Rate
Subject to
ATCO
Plpelines
Franchi3e
Feesl
(s/GJ/d)
Effective: May 1, 2019 (Amended: July 1, 2019)
Exhibit No. 4
Case No. INT-G-19-06
lntermountain Gas Company
Page 13 of34
NationalEnergy
Board
Office national
de l'6nergie
File OF-Tolls-Group l-N08 l-20 l9-03 0 I
l8 June 2019
Mr. Bernard Pelletier
NOVA Gas Transmission Ltd.
Director, Regulatory Tolls and Tariffs
Canadian Gas Pipelines
450 - I't Street SW
Calgary, AB T2P 5Hl
Email: bemard [e-mail]
Dear Mr. Pelletier:
NOVA Gas Transmission Ltd. (NGTL)
Application for Approval of Revised Abandonment Surcharges
Effective I July 2019 to 3l December 2019 (Application)
The National Energy Board (Board) has received NGTL's Application dated26 April 2019. The
Application, filed pursuant to Part IV of the National Energt Board Acl, and which is in
accordance with MH-001-2013, requests an Order approving revised abandonment surcharges to
be made final effective I July 2019 to 3l December2019 (Revised Abandonment Surcharges).
NGTL also requests that the interim abandonment surcharges under Order TGI-004-2018 be
made final for the period I January 2019 to 30 June 2019.
On 26 April 2019, NGTL also a revised Statement of Investment Policy and Procedures (SIPP)
and on I May 2019, the Board issued a letter soliciting comments on it. No comments were
received.
The Board has reviewed NGTL's Application, including the revised Annual Contribution
Amount (ACA) used to calculate the Revised Abandonment Surcharges. The Board notes that
the revised ACA calculation utilizes an increased annual pre-tax retum of 5.4o%. This reflects the
expected annual pre-tax retum in the revised SIPP, which allows for a more diversified
investment portfolio for the NGTL abandonment trust such that 40 per cent of the assets will be
invested in equities, rather than the current portfolio of 100 per cent Fixed Income assets. The
overall change in the ACA is a reduction from $l10.58 million to $78.77 million.
The Board finds these adjustments made to the ACA reasonable and approves the revised ACA
of $78,766,032.
Suite 210,517 Tonlh Avonue Sw
cdgary, Alberta T2B 0A8
517, Di{om. Ayenu. S.-O,, burs6u 210
cdgary (Alb6rta) T2R 0 8
T.l€phon€/T6l6pho r*, O*OEk
Facsimilo/T6locopiour : 403-292-5503
www.neb-on6.gc,ca
Tdephone/T6l6phone : 1€0G8Sl 265
Facsimil€/T6l6coderr : 1 -87l-286-88G1C-anad?t
Exhibit No. 4
Case No. INT-G-19-06
lntermountain Gas Company
Page 14 of34
-2-
The Board also finds NGTL's revised abandonment surcharges, which are approximately 29 per
cent lower than the current abandonment surcharges, to bejust and reasonable and approves
them as filed, to be effective 1 July 2019 to 3l December 2019. Attached is a copy of Order
TG-006-2019.
The Board orders the surcharges under Order TGI-004-201 8 to be made final for the period
I January 2019 to 30 June 2019.
NGTL is directed to serve a copy of this letter on its shippers and any other interested persons to
the Application.
Yours truly,
Original signed by L. George for
Sheri Young
Secretary ofthe Board
Exhibit No. 4
Case No. INT-G-19-06
lntermountain Gas Company
Page 15 of34
NOVA Gas Transmission Ltd.Attachment 3
Table of Rates, Tolls and Charges
Page 1 of 1
l. Sflice under rate Schedules FT-D, FT-P md IT-D for delivcry stations identified in Attachment 2, md mte Schedules OS No. 201 1476092, ile subject
to the ATCO Pipelines Frmchise Fees pmuilt to pamgraph 15.13 of the General Tems md Conditions.
2. Monthly Abmdoment Suchrge applicable to Rate Schedules Ff-& FI-D, FT-P, FT-RN, FT-DW, md STFT, md the following Rate Schedules OS:
201814050r, 2018140508, 2018140509.
3. DailyAbudomentSuchrge applicabletoRateScheduleslT-R, lT-D,thefollowingRateSchedulesOS: 2011476052,2011476054,201788'1638,
2011476092.2016721799,2016759254,2003004522, md ifapplicable Over-Rw Gas.
Service Rates, Tolls and Charges
l. Rate Schedule FT-R
Refs to Attachment " 1" for applicable FT-R Demmd Rate per month based on a three-yeil tem (Price Point "8") &
Suchuge for each Receipt Point
Averagc Fim Swicc Receipt Price (AFSRP) $210.74 / l0rm3 / monrh
2. Rate Schedule FT-RN Refer to Attachment "1" for applicable FT-RN Demmd Rat€ per month & Sucharge for each Receipt Point
3. Rate Schedule FT-D I
Refs to Attachment "2" for applicable FT-D Demmd Rate per month based on a one yeil tem (Price Pont"Z') &
Suchrge for each Group I or Group 2 Delivery Point
Average FT-D Demmd Rate for Group I Delivery Points $5.67 / GJ / month
FI-D Dmmd Rate for Group 2 Delivery Points $5.48 / GJ / month
FT-D Demmd Rate for Group 3 Delivery Points 96.58 / GJ / month
4. Rate Schedule STFT STFI Bid Price: Minimm of 1009/0 ofthe applicable FT-D Demmd Rate based on a one yeil tem (Price Point "Z")
for each Group I Delivery Point
5. Rate Schedule FT-DW FT-DW Bid Price = Minimm of 125% ofthe applicable FT-D Demmd Rate based on a three yetr tem (Price Point.Y') for each Croup I Delivery Point
6. Rate Schedule FT-Pr Refer to Attachment "3" for applicable FT-P Demmd Rate per month
9. Rate Schedule IT-R Refer to Attachment "l" for applicable IT-R Rate for each Receipt Poinl
10. Rate Schedule IT-D 'Refq to Attachment "2" for applicable IT-D Rate for each Delivery Point
I l. Rate Schedule FCS Ihe FCS Chrge is detemined in accordmce with Attachment "l" to the applicable Schedule of Seruice
t2. Rate Schedule PT Ihe PT Chilge is detemined in accordmce with the applicable Schedule of Service
13. Rate Schedule OS Schedule No.
2018 I 4050 I
2018 I 40508
2018 140509
Chrse
$124.84 / l6hr/monrh
$124.84 7 161637peag1
$124.84 7 163-17rro.1,
20t1475772
2018 l5 I 74 I
$9.250.00 i month
$791.00 / month
2003004522 Applicable IT-R md lT-D Rate
2011416052 I
20fi476054
$0.1802 /cJsubjectto
s7r7 ooo oo Minimm Annul' Chuse
20 t7 887 638 I 20 I 147 6092
20 16721799 I 20 t67 59254
50.095 / GJ md
S1,000.00 / month
14. Rate Schedule CO,Tier Co, Rare ($/loh3)
2
554.23
438.53
2E4.723
15. MonthlyAbmdoment
Suchuge 2 $7.77 7193637.on15 $0.21 /GJ /rnonth
16. DailyAbmdoment
Suchuge 3 $0.26 71936376u,$0.0068 /GJ /day
Effective: July 1, 2019
Exhibit No. 4
Case No. INT-G-19-06
lntermountain Gas Company
Page 16 of34
FOOTHILLS PIPE LINES LTD.
(2 pages)
Exhibit No. 4
Case No. INT-G-19-06
lntermountain Gas Company
Page 17 of34
NationalEnergy
Board
Office national
de l'6nergie
File OF-Tolls-Groupl-Fl I 5-20 l9-0 I 0l
l8 June 2019
Mr. Bemard Pelletier
Foothills Pipe Lines Ltd.
Director, Regulatory Tolls and Tariffs
Canadian Gas Pipelines
450 - I't Street SW
Calgary, AB T2P 5Hl
Email: bernard [e-mail]
Dear Mr. Pelletier:
Foothills Pipe Lines Ltd. (Foothills)
Application for Approval of Revised Abandonment Surcharges
Effective I July 2019 to 3l December 2019 (Application)
The National Energy Board (Board) has received Foothills' filing dated 26 April2019, pursuant
to section 60(lXa) of the National Energt Board Act.
On 26 April 2019, Foothills also filed a revised Statement of Investment Policy and Procedures
(SIPP) and on I May 2019, the Board issued a letter soliciting aomments on it. No comments
were received.
The Board has reviewed Foothills' filings, including the revised Annual Contribution Amount(ACA) used to calculate the Revised Abandonment Surcharges. The Board notes that the revised
ACA calculation utilizes an increased annual pre-tax return of 5.4o%. This reflects the expected
annual pre-tax return in the revised SIPP, which allows for a more diversified investment
portfolio for the Foothills abandonment trust such that 40 per cent of the assets will be invested
in equities, rather than the current portfolio of 100 per cent Fixed Income assets. The overall
change in the ACA is a reduction from $10.84 million to $7.83 million.
The Board finds these adjustments made to the ACA reasonable and approves the revised ACA
of $7,83 1,449. The Board notes that the revised ACA results in revised abandonment surcharges
that are approximately 28 per cent lower than the current abandonment surcharges.
Foothills is directed to serve a copy ofthis letter on its shippers and any other interested persons
to the Application.
Yours truly,
Original signed by L. George for
Sheri Young
Secretary ofthe Board
Sulto 210, 517 Tenlh Av.nuo SYl,
cdg6ry, AberteT2R OA8
517, Dlxlam. Avenuc S,€., bureau 210
Calgdry (Abertsl T2R 0AB
Tel€phone/T6l6phone : 40li-292-4800
Fadimilc/Tol6copiour : 40&292-5503
m.nehno.gc.ca
Telephono/T6l€phonc : 1 -800-89!l-1 265
Facsimihr'Td6copiour : l-877-28&,8803C"anad'd
Exhibit No. 4
Case No. INT-G-19-06
lntermountain Gas Company
Page 18 of34
Foothills Pipe Lines Ltd.Page I
TABLE OF EFFECTIVE RATES
1. Rate Schedule FT, Firm Transportation Service
Demand Rate
($/GJ/Km/Month)
Zone 6 0.0053689132
ZoneT 0.0029594363
ZoneS* 0.0163193182
Zone9 0.0169980422
2. Rate Schedule C)T, Overrun Transportation Service
Commodity Rate
($/GJ/Km)
Zone 6 0.0001941634
Zone 7 0.0001070262
3. Rate Schedule IT, Interruptible Transportation Service
Commodity Rate
($/GJ/Km)
Zone 8* 0.0005901781
Zone 9 0.0006147237
4. Monthly Abandonment Surcharge**
All Zones 0.090060255 I ($/GJ/Month)
5. Daily Abandonment Surcharge***
All Zones 0.002960885 I ($/GJ/Day)
* For Zone 8, Shippers Haul Distance shall be 170.7 km.
**Monthly Abandonment Surcharge applicable to Rate Schedule Firm Transportation Service, and Short Term Firm
Transportation Service for all zones.
***Daily Abandonment Surcharge applicable to Rate Schedule Overrun Transportation Service for Zone 6 & 7,
Interruptible Transportation Service for Zone 8 & 9, and Small General Service for Zone 9.
TARIFF - PHASE I Effective Date: July l, 2019
Exhibit No. 4
Case No. INT-G-19-06
lntermountain Gas Company
Page 19 of34
GAS TRANSMISSION NORTHWEST LLC
(9 pages)
Exhibit No. 4
Case No. INT-G-19-06
lntermountain Gas Company
Page 20 of 34
201-81130-3029 FERC PDF (unofficiaj-l Ll/30/2078
165 FERC,lJ6l,l95
UNITED STATES OF AMERICA
FEDERAL ENERGY REGULATORY COMMISSION
Before Commissioners: Neil Chatterjee, Chairman;
Cheryl A. LaFleur and Richard Glick.
Gas Transmission Northwest LLC Docket No. RP I 5-904-001
ORDER APPROVING SETTLEMENT
(lssued November 30, 2018)
l. On October 16,2018, Gas Transmission Northwest LLC (GTN) submitted,
pursuant to Rule 207(a)(5),t a petition for approval of an Amended Stipulation and
Agreement of Settlement (Amended Settlement) regarding changes to GTN's
transportation service rates. GTN includedpro forma tariff sheets implementing the
revised rates and other terms of the Amended Settlement, which is uncontested. The
Amended Settlement will result in reduced rates to be effective January l, 2019. The
Commission approves GTN's Amended Settlement, as proposed.
I. Backeround and Proposal
2. On June 30,2015, the Commission approved a Stipulation and Agreement of
Settlement (2015 Settlement) filed in this proceeding.2
3. On July 18,2018, the Commission issued Order No. 849,3 a final rule adopting
procedures for determining which jurisdictional natural gas pipelines may be collecting
unjust and unreasonable rates in light of (l) the income tax reductions provided by the
Tax Cuts and Jobs Acta and (2) the Commission's Revised Policy Statements and
' l8 c.r'.R. g 38s.207(a)(s) (2018).
2 Gas Transmission Northwest LLC,151 FERC fl 61,280 (2015).
3 Interstate and Intrastate Natural Gas Pipelines; Rate Changes Relating to
Federal Income Tax Rate, Order No. 849, 83 Fed. Reg. 36,672 (July 30, 2018),
FERC Stats. & Regs. fl 31,404 (2018) (cross-referenced at 164 FERC !J61,031).
o An Act to provide for reconciliation pursuant to titles II and V of the concurrent
(continued...)
Exhibit No. 4
Case No. INT-G-I9-06
lntermountain Gas Company
Page2l ot34
2018L130-3029 FERC PDF (Unofficial) 1l-l30/2018
Docket No. RP I 5-904-00 I ,|
Opinion No. 511-C6 establishing a policy that master limited partnerships (MLPs) may
not recover an income tax allowance in response to the decision of the United States
Court of Appeals for the District of Columbia Circuit (D.C. Circuit) in United Airlines,
Inc. v. FERC.7 Order No. 849 required, pursuant to sections 10 and I 4(a) of the Natural
Gas Act (NGA), that all interstate natural gas companies with cost-based stated rates, that
filed a 2017 FERC Form No. 2 or 2-A, must file a FERC Form No. 501-G informational
filing.8 The FERC Form No. 501-G is designed to collect financial information to
evaluate the impact of the Tax Cuts and Jobs Act and United Airlines Issuances on
interstate natural gas pipelines' revenue requirements. Using the data in the pipelines'
2017 FERC Form Nos. 2 and2-A, the form estimates (l) the percentage reduction in
the pipeline's cost of service resulting from the Tax Cuts and Jobs Act and the Revised
Policy Statement and (2) the pipeline's current Return on Equity (ROE) before and after
the reduction in corporate income taxes and the elimination of income tax allowances for
MLP pipelines.
4. Order No. 849 also provided several options each interstate natural gas pipeline
may choose from to address the changes to the pipeline's revenue requirement as a result
of the income tax reductions. These included (1) a limited NGA section 4 rate reduction
filing (Option l), (2) a commitment to file a general section 4 rate case or a prepackaged
settlement in the near future (Option 2), (3) an explanation why no rate change is needed
(Option 3), and (4) no action (Option 4).
5. On September 24,2018, in Docket No. RPl8-1201-000, GTN requested an
extension of time to submit its FERC Form No. 501-G pursuant to Order No. 849. On
October 5,2018, the Commission issued a notice that GTN's request was granted, and
the deadline was extended to and including December 6,2018.
resolution on the budget for fiscal year 20 I 8, Pub. L. No. I I 5-97, I 3 I Stat. 2054 (2017)
(Tax Cuts and Jobs Act).
s Inquiry Regarding the Commission's Policy for Recovery of Income Tax Costs ,
Revised Policy Statement, 83 Fed. Reg. 12j62 (Mar. 2l ,201 8), FERC Stats & Regs.
fl 35,060 (2018), order on reh'g,164 FERC fl 61,030 (2018).
6 Strpp,2.P., Opinion No. 5l l-C,162 FERC n61,228, at P 9 (2018).
' 821 p.3d 122 (D.C. Cir. 2016). For purposes of this order, the Revised Policy
Statement, United Airlines, and Opinion No. 5l I -C will collectively be referred to as
"United Airlires Issuances."
8 The One-time Report on Rate Effect of the Tax Cuts and Jobs Act may be
referred to interchangeably as "One-time Report" or "FERC Form No. 501-G."
Exhibit No. 4
Case No. INT-G-I9-06
lntermountain Gas Company
Page 22 ot 34
20181130-3029 FERC PDF (Unofficiall lr/30/2018
Docket No. RP I 5-904-00 I -J-
6. On October 16,2018, GTN submitted the Amended Settlement in response to
Order No. 849. Also in the instant filing, GTN submittedproforma tariff records. The
Amended Settlement provides that the reduced rates shall become effective January l,
2019. Immediately after an order approving the Amended Settlement becomes final,e
GTN will file actual tariff records consistent with the pro forma tariff records included
in the Amended Settlement to be effective on the date of the initial order approving the
Amended Settlement.
7. Article II of the Amended Settlement states that, except as specifically amended in
the Amended Settlement, the terms and conditions of the 2015 Settlement, as approved
by the Commission on June 30,2015, shall continue in full force and effect.
8. Article III defines a Settling Party as (a) any party identified in Appendix A of
the Amended Sefflement or (b) any party or shipper not identified in Appendix A that
(i) expressly supports or (ii) does not oppose the Amended Settlement as a whole and/or
any of its underlying provisions. Article III also defines a Contesting Party as a party that
elects to become a Contesting Party or takes any action inconsistent with the terms of the
Amended Settlement.
9. Articles IV and V of the Amended Settlement include various miscellaneous
provisions related to, for example, the withdrawal of pending appeals, non-severability,
effective dates, and moratorium. The Amended Settlement establishes a moratorium
from January 1,2019 until December 31,2021. During the moratorium, GTN waives
and relinquishes its rights under section 4 of the NGA to advocate any changes or
adjustments that would be inconsistent with any provision of the Amended Settlement.
Also during the moratorium, each Settling Party waives and relinquishes its rights under
section 5 of the NGA to advocate individually, with others or in support of others, any
changes or adjustments that would be inconsistent with any provision of the Amended
Settlement. During the moratorium, Settling Parties shall have the right to make any
NGA section 5 filing not prohibited by the Amended Settlement.
10. Article V(AX7) of the Amended Settlement states o'To the extent that the
Commission considers any change to the terms of the Amended Settlement during the
Moratorium, the standard of review for any such proposed change shall be the most
stringent standard permissible under applicable law."
I l. Article VI of the Amended Settlement provides that:
' If no request for rehearing is filed, this date will be 30 days after the issuance of
the initial order approving the Settlement.
Exhibit No. 4
Case No. INT-G-19-06
lntermountain Gas Company
Page 23 of 34
20181130-3029 FERC PDF (unofficial) LLl30/2018
Docket No. RPI 5-904-001 -4-
a. Settlement Recourse Rates: The rates for all GTN mainline transportation
services, to be effective on January 1,2019 and through December 31,
2079, are set forth or otherwise referenced on pro forma tariff sections 4. I ,
4.2,4.3, and 4.5, attached in Appendix B-l of the Amended Settlement,
and identified as Amended Phase I Settlement Rates. Effective on
January 1,2020 and continuing until December 31,2021, the rates for all
GTN mainline transportation services are set forth or otherwise referenced
on pro forma tariff sections 4.1,4.2,4.3, and 4.5., attached in Appendix B-
2 of the Amended Settlement, and identified as Amended Phase II
Settlement Rates.
b. Negotiated Rates: Effective on January 1,2019 and continuing until
December 31,2021, GTN shall implement a five (5) percent reduction to
reservation rates for all negotiated rate contracts entered into prior to the
date of filing this Amended Settlement. The parties understand and agree
that effective on January | , 2022, this rate reduction will expire and the
rates under the affected negotiated rate contracts shall revert to the rates
stated in the contracts.
c. Interim Rate Relief: If the Commission has not issued an order on the
Amended Settlement as of December l, 2018, GTN shall make an NGA
section 4 filing for the limited purpose of placing the Amended Phase I
Settlement Rates into effect as of January 1,2019 on an interim basis.
Contesting parties shall not be entitled to Interim Rate Relief.
12. Article VII of the Amended Settlement provides that GTN will credit $10 million
to all firm shippers that are Settling Parties that also took firm service from GTN during
the ten month period ending October 31, 2018 (Rate Credit Parties). The credit for
each Rate Credit Party shall be credited to the Rate Credit Party's invoice(s) from GTN
issued and payable in December 2018. The amount to be refunded to each Rate Credit
Party will be calculated based upon each Rate Credit Party's pro rata share of the total
reservation charges paid by all Rate Credit Parties for services provided by GTN during
the ten month period ending October 31,2018. Any GTN shipper who is not a Settling
Party at the time GTN issues the credit will not receive a share of the credit.
13. Article VIII provides that during the term of the Amended Settlement, the
Amended Settlement Rates reflect, as a settled practice, zero income tax allowance
as well as elimination of accumulated deferred income tax (ADIT) and associated
regulatory liability, based on the Commission's rulings in Order No. 849 and the Revised
Policy Statement in Docket No. PLlT-l-000 (which the Amended Settlement refers
to as the Tax Allowance Policy). GTN and the Settling Parties specifically agree and
acknowledge as follows: (a) for the period January I , 2019 through December 3l , 2021,
the Amended Settlement Rates shall reflect zero income tax allowance and elimination
of ADIT, regardless of any change in the Tax Allowance Policy during that term;
Exhibit No. 4
Case No. INT-G-19-06
lntermountain Gas Company
Page 24 ot 34
20181130-3029 FERC pDF (Unofficiall tt/30/20]-8
Docket No. RPI 5-904-00 I 5
(b) after December 3l , 2021 , to the extent that there is no change in the Commission's
Tax Allowance Policy with respect to income tax allowance andlor elimination of ADIT,
or to GTN's ownership structure, GTN's treatment of these rate elements as reflected in
the Amended Settlement shall continue as a settled practice; and (c) after December 31,
202l,to the extent there is or has been any change in (i) the Commission's Tax
Allowance Policy with respect to income tax allowance and/or elimination of ADIT, or
(ii) GTN's ownership structure, GTN and the Settling Parties agree to reserve all rights
to address said changes in a subsequent proceeding following the expiration ofthe
Amended Settlement.
14. Article IX provides that GTN shall make such section 4 filings containing the
actual tariffsections at least thirty (30) calendar days before January 1,2019.
II. Notice of Filins. Interventions. and Protests
15. Public notice of the filing was issued October 22,2018. Interventions and
protests were due as provided in section 154.210 of the Commission's regulations.
l8 C.F.R. $ 154.210 (2018). Pursuant to Rule 214, all timely filed motions to intervene
and any unopposed motions to intervene filed out-of+ime before the issuance date of
this order are granted. 18 C.F.R. $ 385.214. Granting late intervention at this stage of
the proceeding will not disrupt this proceeding or place additional burdens on existing
parties. Canadian Association of Petroleum Producers filed an answer in support of the
petition. No protests or adverse comments were filed.
III. Discussion
16. The Commission finds that the Amended Settlement is fair and reasonable and
in the public interest. The Amended Settlement is either uncontested or supported by
shippers and will result in reduced rates effective January 1,2019. Accordingly, the
Commission approves the Amended Settlement.
17. Article V(AX7) of the Amended Settlement states "To the extent that the
Commission considers any change to the terms of the Amended Settlement during the
Moratorium, the standard of review for any such proposed change shall be the most
stringent standard permissible under applicable law." Because the Amended Settlement
provides that the standard of review for modifications to the Amended Settlement is "the
most stringent standard permissible under applicable law," the Commission clarifies the
framework that would apply if the Commission were required to determine the standard
of review in a later challenge to the Amended Settlement.
Exhibit No. 4
Case No. INT-G-19-06
lntermountain Gas Company
Page 25 of 34
2Ol-81130-3029 FERC pDF (Unofficial\ t7/30/20L8
Docket No. RPI 5-904-00 I -6-
18. The Mobile-Sierrq "public interest" presumption applies to an agreement only
if the agreement has certain characteristics that justify the presumption.r0 In ruling
on whether the characteristics necessary to justifu a Mobile-Sielra presumption are
present, the Commission must determine whether the agreement at issue embodies
either (l) individualized rates, terms, or conditions that apply only to sophisticated
parties who negotiated them freely at arm's length, or (2) rates, terms, or conditions that
are generally applicable or that arose in circumstances that do not provide the assurance
ofjustness and reasonableness associated with arm's-length negotiations. Unlike the
latter, the former constitute contract rates, terms, or conditions that necessarily qualify for
a Mobile-Sie,,ra presumption. In New England Power Generotors Ass'n, Inc. v. FERC,
however, the D.C. Circuit determined that the Commission is legally authorized to
impose a more rigorous application of the statutory'Just and reasonable" standard of
review on future changes to agreements that fall within the second category described
above.ll
The Commission orders:
(A) GTN's Amended Settlement filed in Docket No. RPl5-904-001 is
approved, as discussed in the body ofthis order.
(B) GTN is directed, consistent with the Amended Settlement, to make a
compliance filing of revised tariff records in eTariff format,tz to ensure the requisite
electronic tariff databases reflect the Commission's action in this order.
By the Commission. Commissioner Mclntyre is not voting on this order.
(sEAL)
Nathaniel J. Davis, Sr.,
'o United Gas Pipe Line Co. v. Mobile Gos Service Corp.,350 U.S. 332 (1956)
and Federal Power Commission v. Sierra Pacific Power Co.,350 U.S. 348 (1956)
(Mobile-Sierra).
rr Ne, England Power Generators Ass'n, Inc. v. FERC,7O7 F.3d364,370-371
(D.C. Cir. 2013).
12 See Electronic TariffFilings,Order No.7l4, FERC Stats. & Regs. 1131,276
(2008).
Exhibit No. 4
Case No. INT-G-19-06
lntermountain Gas Company
Page 26 of 34
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
DAILY
MILEAGE (a)
(Dth-MILE)
Max. Min.
BASE 0.000391 0.000000
STF (e) (e) 0.000000
EXTENSION CHARGES
MEDFORD
E-l (0 0.002483 0.000000
E-2 (h) 0.002972 0.000000
(Diamond l)
E-2 (h) 0.001166 0.000000
(Diamond 2)
COYOTE SPRINGS
E-3 (D o.ool 154 0.000000
CARTY LATERAL
E4 (p)
oVERRUN CHARGE (i)
SURCHARGES
ACA (k)
Issued: November 30, 2018
Effective: January l, 2019
PART 4.1
4.1 - Statement of Rates
FTS-1, LFS-1, and FHS Rates
v. I 8.0.0 Superseding v. I 7.0.0
STATEMENT OF EFFECTIVE RATES AND CHARGES FOR
TRANSPORTATION OF NATURAL GAS
Rate Schedules FTS-1, LFS-1, and FHS
For Rate Schedules FTS-l and LFS-l :
RESERVATION
DAILY
NON-MTLEAGE (b)
(Dth)
Max. Min.
0.030954 0.000000
(e) 0.000000
DELIVERY (c)
(Dth-MrLE)
Max. Min.
0.000016 0.000016
0.000016 0.000016
FUEL (d)
(Drh-MrLE)
Max. Min.
0.0050% 0.0000%
0.0050% 0.0000%
0.004177 0.000000 0.000026 0.000026
0.000000 0.000000
0.000000 0.000000
0.001155 0.000000 0.000000 0.000000
0.149828 0.000000 0.000000 0.000000
(k) (k)
Docket No. RP l9-370-000
Accepted: January 2, 2019
Exhibit No. 4
Case No. INT-G-19-06
lntermountain Gas Company
Page27 ol34
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. l-A
PART 4.I
4.1 - Statement of Rates
FTS-1, LFS-1, and FHS Rates
Pro Forma Amended Phase II (lll12020 - l2l3ll202l)
FUEL (d)
(Dth-MrLE)
Max. Min.
0.0050% 0.0000%
0.0050% 0.0000%
Rate Schedules FTS-1, LFS-1, and FHS
For Rate Schedules FTS-l and LFS-l:
RESERVATIONDAILY DAILY
MILEAGE (a) NON-MILEAGE (b) DELIVERY (c)(Dth-MILE) (Dth) (Drh-MrLE)
Max. Min. Max. Min. Max. Min.
BASE 0.000362 0.000000 0.028612 0.000000 0.000016 0.000016
STF (e) (e) 0.000000 (e) 0.000000 0.000016 0.000016
EXTENSION CHARGES
MEDFORD
E-l (0 0.002511 0.000000 0.004223 0.000000 0.000026 0.000026
E-2 (h) 0.002972 0.000000 0.000000 0.000000
(Diamond l)
E-2(h) 0.001166 0.000000 0.000000 0.000000
(Diamond 2)
COYOTE SPRINGS
E-3(D 0.001167 0.000000 0.001168 0.000000 0.000000 0.000000
CARTY LATERAL
E-4 (p) 0.151492 0.000000 0.000000 0.000000
OVERRUN CHARGE 0)
SURCHARGES
ACA (k)(k) (k)
Issued Docket No. Effective: Ac
STATEMENT OF EFFECTIVE RATES AND CHARGES FOR
TRANSPORTATION OF NATURAL GAS
Exhibit No. 4
Case No. INT-G-19-06
lntermountain Gas Company
Page 28 of 34
SPRINGS II
titS
3
ts
2 fils
6
7
Kamath
5
MSts
CITY MS
SALES
lone (9)
MADRAS
1)
MS REDMOND MS
BEND Tr{S
MS
Bend
co,nrv cHEmuLT
TAP
KLAI'ATH
(13)
ils
RUAY
(14)
MS
OREGON
TURQUOISE FLATS
PHOENIX / MEDFORD
CALIFORNIA
GAS TRANSMISSION NORTHWEST LLC
Q rranscanaoa
o
I
I4
A
NEVADA
Scale in Miles
Mct.r St.tion
Comp16!or gtalion
SYSTEiI iIAP
JULY 27, 2018
M.p Numbar: T_00e7_002t_01 R.v 0
0204080
ecrosse
,yote 5
ada6
MS
Exhibit No. 4
Case No. INT-G-19-06
lntermountain Gas Company
Page 29 of 34
DOMINION ENERGY QUESTAR PIPELINE, LLC
(3 pages)
Exhibit No. 4
Case No. INT-G-19-06
lntermountain Gas Company
Page 30 of 34
2or8t22o-3116 FERC PDF (unoffj.cial) 12/20/201-8
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. RPI 9-332-000
Issued: December 20, 2018
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 & Tariffs
Reference: Fuel Gas Reimbursement Percentage Filing
Dear Mr. Burton:
On November 29,2018, Dominion Energy Questar Pipeline, LLC (DEQP) filed a
tariff recordl to reflect a change in its Fuel Gas Reimbursement Percentage (FGRP).
DEQP states that its FGRP decreased from 1.87 percent to 1.57 percent. The referenced
tariffrecord is accepted, effective January 1,2019, as proposed.
Public notice of the filing was issued on November 30, 2018. Interventions and
protests were due as provided in section 154.210 of the Commission's regulations (18
C.F.R. $ 154.210 (2018). Pursuant to Rule 214 (18 C.F.R. $ 385.214 (2018)), all timely
filed motions to intervene and any unopposed motions to intervene filed out-of-time
before the issuance date ofthis 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. -
This acceptance for filing shall not be construed as constituting approval ofthe
referenced filing or ofany rate, charge, classification, or any rule, regulation, or practice
I Dominion Energy Questar Pipeline, LLC, FERC NGA Gas Tarifl Tariffs,
Statement of Rates. Statement of Rates. 14.0.0.
Exhibit No. 4
Case No. INT-G-19-06
lntermountain Gas Company
Page 31 of 34
20181220-3r15 FERC PDF (Unofficial) 72/20/2018
Docket No. RPI 9-332-000
affecting such rate or service contained in your tariff; nor shall such acceptance be
deemed as recognition of any claimed contractual right or obligation associated
therewith; and such acceptance is without prejudice to any findings or orders which have
been or any which may hereafter be made by the Commission in any proceeding now
pending or hereafter instituted by or against your company.
This order constitutes final agency action. Requests for rehearing by the
Commission may be filed within 30 days of the date of issuance of this order, pursuant to
18 C.F.R. $ 38s.713 (2018).
Issued by: Marsha K.Palazzi, Director, Division of Pipeline Regulation
2
Exhibit No. 4
Case No. INT-G-19-06
lntermountain Gas Company
Page 32 of 34
Dominion Energy Questar Pipeline, LLC
FERC Gas Tariff
Second Revised Volume No. 1
Statement of Rates
Section Version: 14.0.0
STATEMENT OF RATES
Rate Schedule/
Type of Charge
(a)
PEAKING STORAGE
Firm Peaking Storage Service - PKS
Monthly Reservation Charge
Base
Tariff
Rare ($)
(b)
..2.87375
..0.00000
.. 0.03872
..0.03872
..2.85338
..0.00000
Maximum 4/.......
Minimum....................
Usage Charge
Injection .....
Withdrawal..
CLAY BASIN STORAGE
Firm Storage Service - FSS
Monthly Reservation Charge
Deliverability
Maximum 4/ ......,,,,,,,,,,.
Minimum....,.................::::::
Capacity
Maximum
Usage Charge
Injection 1/ ..
Withdrawal....,..
Authorized Overrun Charge
Maximum
Interruptible Storage Service - ISS
Usage ChargeInventory 5/
Maximum
.......0.02378
.......0.00000
.......0.01049
..0.01781
..0.30315
..0.01781
.......0.05927
.......0.00000
.......0.01049
.......0.01781
Iniection 1/ ..
Withdrawal..
OPTIONAL VOLUMETRIC RELEASES /Peaking Storage Service - PKS
Maximum 4/ ..........,,,,,....
Minimum..........
Firm Storage Service - FSS
Maximum 4/,,,,,,.,......,..,.
Minimum
Storage Usage Charges Applica
Peaking Storage Service - PKS:
ble to volumetric Releases 6/
Service - FSS:
Withdrawal....
PARK AND LOAN SERViCE - PAL1
Daily Charge
Maximum.
Minimum..
Delivery Chargel/ ...........
FUEL REIMBURSEMENT - 2.0o/o (0.2o/o utility and 1.80/o compressor fuel) for Rate Schedule PAL1
0.00000
..0.03872
..0.03872
0.01049
0.01781
..0.30315
..0.00000
.. 0.02830
Filed On: November 29, zOLe Effective On: January 1, 2019
3.40890
0.00000
0.57068
Exhibit No. 4
Case No. INT-G-19-06
lntermountain Gas Company
Page 33 of 34
FEDERAL ENERGY REGULATORY COMMISSION
ANNUAL CHARGES UNIT CHARGE
(l pages)
Exhibit No. 4
Case No. INT-G-19-06
lntermountain Gas Company
Page 34 of 34
FEDERAL ENERGY REGULATORY COMMISSION
WASHINGTON , D.C.20426
FY 2OI9 GAS ANNUAL CHARGES
CORRECTION FOR ANNUAL CHARGES UNIT CHARGE
June 18,2019
The annual charges unit charge (ACA) to be applied to in fiscal year2020 forrecovery of
FY 2019 Current year and 2018 True-Up is $0.0013 per Dekatherm (Dth). The new ACA
surcharge will become effective October 1,2019:
The following calculations were used to determine the FY 2019 unit charge:
2019 CURRENT:
Estimated Program Cost$72,947,000 divided by 56,271,363,51I Dth : 0.0012963432
2018 TRUE-UP:
Debit/Credit Cost ($1,595,692) divided by 49,876,999J97 Ah : (0.0000319925)
TOTAL UNIT CHARGE : 0.0012643507
If you have any questions, please contact Raven A. Rodriguez at(202)502-6276 or e-mail
at [e-mail].
PUBLIC
EXHIBIT NOS. 5-13
CASE NO. INT.G.T9.O6
INTERMOUNTAIN GAS COMPANY
(10 pages)
Exhibit No. 5
Case No. INT-G-19-06
lntermountain Gas Company
Page 1 of 1
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Case No. INT-G-19-06
lntermountain Gas Company
Page 1 of 1
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Exhibit No. 7
Case No. INT-G-'l9-06
lntermountain Gas Company
Page 'l of 'l
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Case No. INT-G-19-06
lntermountain Gas Company
Page 1 of 1
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Case No. INT-G-19-06
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-19-06
lntermountain Gas Company
Page 1 of 'l
Amount
1
2
3
4
5
b
7
8
(a)
Account 1910 Variable Amounts Which Applv to RS. GS-1. and LV-l :
Account 1910 Variable Costs
Normalized Sales Volumes (111118 - 12131118)
Proposed Temporary Surcharge (Credit) - Variable Costs
Lost and Unaccounted For Gas Amounts Which Applv to RS and GS-1:
Lost and Unaccounted For Gas Amounts from INT-G-1842 (Account 1910.2120)
Lost and Unaccounted For Gas Amortization (Account 1910.2130)
(Over)/Under Collection of Lost and Unaccounted For Gas from INT-G-18-02
Lost and Unaccounted For Gas INT-G-19-06
Total Lost and Unaccounted For Gas Amounts Which Apply to RS and GS-1
Normalized Sales Volumes (111118 - 1231118)
Proposed Temporary Surcharge (Gredit) - Lost and Unaccounted For Gas Costs
Lost and Unaccounted For Gas Amounts Which Applv to LV-1. T-3, and T"4:
Lost and Unaccounted For Gas Amounts from INT-G-18-02 (Account 1910.2120)
Lost and Unaccounted For Gas Amortization (Account 1910.2140)
(Over)/Under Collection of Lost and Unaccounted For Gas from INT-G-18-02
Lost and Unacmunted For Gas INT-G-19-06
Total Lost and Unaccounted For Gas Amounts Which Apply to LV-1, T-3, and T-4
Normalized Sales Volumes (111118 - 12131118)
Proposed Temporary Surcharge (Credit) - Lost and Unaccounted For Gas Costs
Convert T4 Lost and Unaccounted For Temoorarv from a Volumetric Rate to a Demand Rate:
Proposed Temporary Surcharge (Credit) - Lost and Unaccounted For Gas Costs (Line 20)
Normalized T4 Sales Volumes (111118 - 12131118)
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 28, Column (d), plus Line 34, Column (e)
(5) See Workpaper No. 5, Page 2, Line 3, Column (c)
(6) See Workpaper No. 5, Page 2, Line 14, Column (d)
o See Workpaper No. 5, Page 2, Line 29, Column (d), plus Line 38, Column (e)
(b)
$ 4,557,004 (1)
373,309,399
$0.01221
$605,504 €)
(657,754) (3)
(52,250)
165,775 (4)
$113,525
364,51 8,838
$0.00031
$180,917 F)
(178,895) (6)
2,022
55,507 s)
$57,529
362,325,380
$0.00016
$0.00016
319,780,325
$51,165
17,418,120
$0.00294
o
10
11
12
13
14
15
16
17
18
19
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Exhibit No. 11
Case No. INT-G-19-06
lntermountain Gas Company
Page 1 of 1
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Case No. INT-G-19-06
lntermountain Gas Company
Page 1 ot 2
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Case No. INT-G-19-06
lntermountain Gas Company
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Exhibit No. 13
Case No. INT-G-19-06
lntermountain Gas Company
Page 1 of 1
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WORKPAPER NOS. 1.8
CASE NO. INT-G-19.06
INTERMOUNTAIN GAS COMPANY
(16 pages)
Workpaper No. 1
Case No. INT-G-19-06
lntermountain Gas Company
Page I of 2
INTERMOUNTAIN GAS COMPANY
Summary of Northwest Pipeline TF-l Full Rate Demand Costs
Line
No. Transportation
(a)
rNT.G.18.02
AnnualTherms
rNT.G.18.02
Prices(l)
rNT.G.18.02
Annual CostP)
TF-1 Reservation Contract #1
TF-1 Reservation Contract #2
TF-1 Reservation Contract #3
TF-1 Reservation Contract *14
TF-1 Reservation Contract #5
TF-1 Reservation Contract #6
TF-1 Reservation Contract #7
TF-1 Reservation Contract #8
TF-1 Reservation Contract #9
TF-1 Reservation Contract #10
TF-1 Reservation Contract #11
Total
(b)
412,537,600
25,550,000
73,000,000
26,429,650
32,850,000
36,500,000
87,600,000
18,250,000
104,495,850
26,462,500
51,081 750
894,757,350
rNT.G.19.06
AnnualTherms
(d)
$16,499,624
1,264,739
2,849,412
1,031,629
1,282,233
1,424,702
3,419,296
712,353
4,078,784
1,032,914
1,993,876
$ 35,589,562
tNT.G.19.06
Annual Cost€)
(c)
1
2
1
4
E
o
7
B
0
10
11
12
$0.039995
0.049501
0.039033
0.039033
0.039033
0.039033
0.039033
0.039033
0.039033
0.039033
0.039033
Line
No. Transportation
(a)
tNT.G.19.06
Prices(1)
Contract #1
Contract #2
Contract #3
Contract #4
Contract #5
Contract #6
Contract #7
Contract #8
Contract #9
Contract #10
Contract #11
(b)
413,667,840
25,620,000
73,200,000
26,502,060
32,940,000
36,600,000
87,840,000
18,300,000
104,782,140
26,535,000
51,221,700
(d)
$16,504,633
1,251,113
2,851,352
1,032,334
1 ,283,1 1 0
1,425,677
3,421,621
712,837
4,081,569
1,033,615
1,995,237
$ 35,593,098
(c)
13
14
15
16
17
18
19
20
21
22
23
24
25
TF-1 Reservation
TF-1 Reservation
TF-'1 Reservation
TF-1 Reservation
TF-1 Reservation
TF-1 Reservation
TF-1 Reservation
TF-1 Reservation
TF-1 Reservation
TF-1 Reservation
TF-1 Reservation
Total
a 0.039898
0.048833
0.038953
0.038953
0.038953
0.038953
0.038953
0.038953
0.038953
0.038953
0.038953
897,208,740
TotalAnnual Cost Difference (Line 24 minus Line 12)
(') Column (d) divided by Column (b), rounded to 6 decimal places
(2) Sum of the calculated monthly costs
(3) See Exhibit No, 5, Line 3, Column (h)
$3,536 (3)
Workpaper No. 't
Case No. INT-G-19-06
lntermountain Gas Company
Page 2 of 2
INTERMOUNTAIN GAS COMPANY
Summary of Northwest Pipeline TF-l Discounted Demand Costs
Line
No.Transportation
tNT.G.18.02
AnnualTherms
tNT.G-18.02
Prices(1)
tNT.G.18-02
Annual Cost€)
TF-1 Reservation
TF-'l Reservation
TF-1 Reservation
TF-1 Reservation
TF-1 Reservation
TF-1 Reservation
TF-1 Reservation
TF-1 Reservation
TF-1 Reservation
Total
(a)
Contract #1
Contract #2
Contract #3
Contract *14
Contract #5
Contract #6
Contract #7
Contract #8
Contract #9
(b)
18,250,000
29,404,400
58,400,000
36,500,000
32,850,000
1'1,497,500
4,530,000
0.025372
0.02u20
0.024396
0.026il2
0.008500
0.035130
0.031227
(d)
$463,030
688,648
1,424/02
968,801
279,225
403,904
141,457
$+369,767
tNT.G.19.06
Annual CostG)
(c)
1
2
3
4
5
6
7
8
I
10
$
191 ,431 ,900
Line
No.Transportation
tNT.G.t9.06
AnnualTherms
tNT-G-19.06
Prices(1)
TF-1 Reservation
TF-1 Reservation
TF-1 Reservation
TF-1 Reservation
TF-1 Reservation
TF-1 Reservation
TF-1 Reservation
TF-1 Reservation
TF-1 Reservation
Total
(a)
Contract #'1
Contract #2
Contract #3
Contract fl4
Contract #5
Contract #6
Contract #7
Contract #8
Contract #9
(b)
18,300,000
19,656,640
58,560,000
36,600,000
32,940,000
11,529,000
4,560,000
47,810,260
59,676,300
(d)
$463,346
459,568
1,425,677
969,460
279,990
4M,180
142,159
465,266 (3)
813 5gg (3)
$ 5,423,244
$ 1,053,477 $l
(c)
11
12
13
14
15
16
17
18
19
20
$0.025319
0.023380
0.024346
0 026488
0.008500
0.035058
0.031 175
0.009732
0.013634
289,632,200
21 Total Annual Cost Difference (Line 20 minus Line 10)
(1) Column (d) divided by Column (b), rounded to 6 decimal places
(') Sm of the calculated monthly costs
(3) Additional capacity to replace future expiring contracts
(') See Exhibit No. 5, Line 4, Column (h)
INTERMOUNTAIN GAS COMPANY
Summary of Upstream Capacity Full Rate Demand Costs
Workpaper No. 2
Case No. INT-G-19-06
lntermountain Gas Company
Pagel ot2
INT-G-18-02
Annuat CostB)
Line
No.Transportation
tNT-G.18.02
AnnualTherms
tNT-G.18-02
Prices(1)
(a)
Upstream Agreement #1
Upstream Agreement #2
Upstream Agreement #3
Upstream Agreement fl4
Upstream Agreement#5
Upstream Agreement #6
Upstream Agreement #7
Upstream Agreement iE
Upstream Agreement *i9
Total
Estimated Upstream Capacity Release Credits
TotalAnnual Cost lncluding Capacity Release Credits
Upstream Agreement #1
Upstream Agreement #2
Upstream Agreement #3
Upstream Agreement il4
Upstream Agreement #5
Upstream Agreement #6
Upstream Agreement #7
Upstream Agreement lE
Upstream Agreement lS
Total
Estimated Upstream Capacity Release Credits
TotalAnnual Gost lncluding Capacity Release Credits
TotalAnnual Cost Difference (Line 24 minus Line 12)
(') Colrr, (d) divided by Column (b), rounded to 6 decimal places
(2) Sum of the calculated monthly costs
(3) See Exhibit No. 5, Line 5, Column (h)
(b)
25,933,250
351,503,260
26,962,550
37,244,600
26J26,700
128,898,520
54,750,000
62,050,000
133,590,000
$ 0.008033
0.008038
0.008033
0.008033
0.016051
0.016051
0.016051
0.0'16051
0.016051
(d)
$208,320
2,825,484
216,588
299,1 84
419,372
2,068,974
878,801
995,977
2,144,283
10,056,983
(500,000)
$ 9,556,983
tNT.G.19-06
Annual Cost(2)
(c)
1
2
3
4
5
6
7
8
o
10
11
12
Line
No.
847,058,880
rNT.G.19.06
AnnualTherms
INT.G.I946
Prices(l)
(c)(a)(b)
26,004,300
352,589,060
27,036,420
37,346,640
26,'198,280
'129,355,380
54,900,000
62,220,000
133,956,000
$ 0.009948
0.009951
0.009948
0.009948
0.013737
0.013813
0.013737
0.013737
0.013737
(d)
$258,684
3,508,545
268,956
371,520
359,891
1,786,849
754,164
854,721
1,840,167
10,003,497
(500,000)
$ 9,503,497
13
14
15
16
17
18
19
20
21
22
23
24
25
849,606,080
$ (53,486) (3)
Workpaper No. 2
Gase No. INT-G-19-06
lntermountain Gas Company
Page 2 ol 2
INTERMOUNTAIN GAS COMPANY
Summary of Upstream Capacity Discounted Demand Costs
Line
No.Transportation
tNT-G-18-02
AnnualTherms
!NT-G.18-02
Prices(1)
rNT.G-18-02
AnnualCost(2)
(a)
Upstream Agreement #1
Upstream Agreement #2
Upstream Agreement #3
Total
(b)
36,974,500 $
452,311,650
37,657,050
526,943,200
(d)
$524,818
7,490,004
623,1 96
$ 8,638,018
rNT-G-19-06
Annual CostP)
(c)
1
2
3
4
0.014194
0.016559
0.016549
Line
No.Transportation
tNT.G.19.06
AnnualTherms
1NT.G.19.06
Prices(1)
5
b
7
8
(a)
Upstream Agreement #1
Upstream Agreement #2
Upstream Agreement #3
Total
(b)
37,075,800 $
453,550,860
37,760,220
(d)
$450,749
8,072,076
671,652
$ 9,194,477
$556,459 (3)
(c)
0.012157
0,017798
0.017787
528,386,880
9 Total Annual Cost Difference (Line 8 minus Line 4)
(') Colrrn (d) divided by Column (b), rounded to 6 decimal places
12)Sum of the calculated monthly costs
See Exhibit No. 5, Line 6, Column (h)(3)
Line
Irlo.Storage Facilities
tilT-G-18.02
Monthly
Billing Determinant
rNT-G.18.02
Prices
tNT-G.18.02
Monthly Cost
INTERMOU NTAIN GAS COMPANY
Summary of Other Storage Facilig Costs
Workpaper No. 3
Case No. INT-G-19-06
lntermountain Gas Company
Page 1 of 1
tNT-G-18-02
Annual Gost
(a)
Clay Basin Costs:
Clay Basin I Reservation
Clay Basin ll Reservation
Clay Basin lll Reservation
Clay Basin I Capacity
Clay Basin ll Capacity
Clay Basin lll Capacity
Total Clay Basin Costs
Rexburo LNG Facility:
Transportation Reservation
Variable Transportation
Total Rexburg LNG Facility Costs
Storage Demand Charge Credit
Total Costs lncluding Storage Credit
Storage Facilities
(b)
266,250
221,880
213,010
31,950,000
26,625,000
25,560,000
rNT.G-19-06
Monthly
Billing Determinant
(b)
266,250
221,880
213,010
31,950,000
26,625,000
25,560,000
$ 400,13s $
$
$
4,801,620
66,000
22,800
88,800
$ (1,810,000)
$3,080,420
rNT-G-19-06
Annual Cost
(c)(d)(e)
I
2
3
4
5
b
7
I
9
10
11
12
13
14
o) $
(1)
(1)
(2)
QI
QI
0.285338
0.285338
0.285338
0.002378
0.002378
0.002378
0 7s,971 $
63,311
60,780
75,977
63,314
60,782
91 1,652
759,732
729,360
911,724
759,768
729,3U
Line
No.
rNT.G.19-06
Prices
tNT.G.t9.06
Monthly Cost
(a)
Clav Basin Costs:
Clay Basin I Reservation
Clay Basin ll Reservation
Clay Basin lll Reservation
Clay Basin I Capacity
Clay Basin ll Capacity
Clay Basin lll Capacity
Clay Basin Line of Credit
Total Clay Basin Costs
0.285338 $
0.285338
0.285338
0.002378
0.002378
0.002378
(c)(d)(e)
15
16
17
18
't9
20
21
22
23
24
25
26
27
28
29
30
rr) $
(1)
(1'
(2\
(2t
(2)
75,971 $
63,311
60,780
75,977
63,314
60,782
91 1,652
759,732
729,360
911,724
7s9,768
729,3U
14,000167
Rexburq LNG Facility:
Transportation Reservation
Variable Transportation
Total Rexburg LNG Facility Costs
Estimated Storage Demand Charge Credit
Total Costs lncluding Storage Credit
Total Annual Cost Difference (Line 29 minus Line 14)
(') Charge Based on Maximum Daily Withdrawal
(2) Charge Based on Maximum Contrac{ual Capacity
(3) See Exhibit No. 5, Line 20, Column (h)
$ 401,302 $4,815,620
$66,000
19,000
$85,000
$ (1,810,000)
$3,090,620
$10,200 (3)
Workpaper No. 4
Case No. INT-G-19-06
lntermountain Gas Company
Page 1 of 1
INTERMOUNTAIN GAS COMPANY
Allocation Factors
Peak Demand
t-4
Line
No.
(f)(a)
INT-G-I9-06 Cost of Gas Allocators:
Peak Demand Per Customer
January 2019 Actual Customers
INT-G19-06 Peak Demand Therms (Line 2 times Line 3)
Percent of Total
INT-G-19-06 LNG Sales credit Demand Allocator3:
Peak Demand Per Customer
January 2019 Actual Customers
INT-G19-06 Peak Demand Therms (Line 7 times Line 8)
Percent of Total
RS GS.r LV.1rb-i-lcl- (d)
Description T-3
(e)
Total
(s)
1
2
3
4
5
7.89
332,235
2,621,3U
60t283%
7.89
332,235
2,621,3U
400100%
$ 57,675,297
64rit10%
37.96
33,454
1,269,914
3222W%
37.96
33,454
1,269,91 4
23-5532%
$ 22,067,934 $
24.!910%
48,930 (1)
12413%
48,930 (1)
0-9025%
339,403
93I3I]4
N/A
N/A
$ 532,754
a$fl%
N/A
1,45'1,510 (1)
ngzi%
3,940,1 78
100.0q4
5,391,688
CIq!CI!
$ 89,376,264
I}!.!AZg
6
7
8
0
10
11
12
IJ
order No. 33757 Allocation of Base Rate Revenues:
Approved Base Rate Revenues
Percent of Total
14 Allocation of Base Rate Revenues to RS and GS.l Rde Classes:
15 Order No. 33757 Approved Base Rate Revenues
16 Percent of Total
$ 8,760,876
9-N22%
$ 57,675,297
12329iy4
$ 22,067,934
2L9I31b
(1)Contract Demand
$ 79,743,231
10q!!%
Workpaper No. 5
Case No. INT-G-19-06
lntermountain Gas Company
Page 1 of7
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INTERMOUNTAIN GAS COI'PAI{Y
Analyris of LV.l Tarifi Block 1, Block 2, and Block 3 Adjustmenb
Workpaper No. 6
Case No. INT-G-19-06
lntermountain Gas Company
Page 1 of 1
Total
Line
No.
Block 1
Therm Sales
Block 2
Therm Sales
Block 3
Therm Sales
(b)
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8,790,s61
100.000%
(c)(d)(e)
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8,790,561
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0.01852 (1)
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1
2
3
4
5
b
7
8
9
10
11
12
13
14
15
16
17
LV-1 Therm Sales (1/1/18 -12131118)
Blocks 1 and 2 Therm Sales
Percent Therm Sales between Blocks 'l and 2
0
0
0
0
0.000%0.000%
Proposed Adjustment to LV-1 Tariff
LV-1 Therm Sales (1/1/'18 - 12131118)
Annualized Adjustment (Line 4 times Line 5)
Annualized Adjustment (Line 6)
PercentAnnualized Sales included in Block 1 and Block 2
Adiustment to Block 1 and 2 (Line 7 times Line 8)
Blockland2Therms
Price AdjustmenUTherm Block 1 and 2 (Line 9 divided by Line 1 0)
WACOG Commodity Charge Change
Total Price AdjustmenUTherm Block I and Block 2
Price Adjustment/Therm Block 3
WACOG Commodity Charge Change
Eliminate INT-G-1 8-02 Variable Temporary
Total Price AdjustmenUTherm Block 3
See Exhibit No. 5, Line 31, Column (k) minus the difference of Line 22, Column (f) minus Column (c)
See Exhibit No. 5,Line22, Column (Q minus Column (c)
See Exhibit No. 7, sum of Lines 3 - 7, Column (d)
See Workpaper No. 8, Footnote 5
$
$
$
$
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100.000%
1 62,801
8,790,561
u 0.01852
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$
$
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0.01139 (3)
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0.01521 (4)
$0.00839
(1)
t2)
(3)
(4)
Description
(a)
INTERMOUNTAIN GAS COMPANY
Lost and Unaccounted for Gas
(Volumes in Therms)
Line
No.De3cription Oct 20,15 . Sept 20i6 Ocl 2016 . Sept 2017 Oct 2017 . Sept 2018
$
$
1
2
4
E
b
7
8
I
10
11
12
13
14
15
'16
17
18
10
20
21
22
(a)
Core Customer Purchased Gas
Transportation Customer Gas
LNG Storage Withdrawals
Under Deliveries of Gas from Pipeline (Draft)
Total Deliveries to System
Core Customer Billed Gas
Unbilled Adjustment
Transportation Customer Billed Gas
Company Use Gas
LNG Storage lnjections
Line Breaks - Found Gas
Over Deliveries of Gas from Pipeline (Pack)
Total Deliveries to customers
Losu(Found) Gas (Line 5 minus 13)
Average Purchase WACOG
Cost of Losu(Found) Gas (Line 14 times Line 15)
Lort Gas $ffherm (Line 16 divided by Line 5)
Losu(Found) Gas (Line 14)
LosU(Found) Gas Therms Deferred
Losu(Found) Gas Adjustment (Line 18 minus Line 19)
Actual Lost Gas Rate (Line 14 divided by Line 5)
3-Year Average Lost Gr3 Rate
(b)
339,592,192
345,348,399
1,795,842
(c)
373,355,527
354,152,074
1,292,372
s23,910
(d)
360,550,036
350,401,998
1,227,027
686,736,433
324,902,426
81 5,526
345,348,399
529,408
1 1,370,008
2,026,730
729,323,883
369,1 57,907
3,800,799
354,152,074
297,147
1,190,801
231,195
712,179,061
361,1 56,1 82
(1,622,037\
350,401,998
390,755
1,428,508
71,663
129,490
684,992,497 728,829,923 71 '1,956,559
1,743,936 493,960 222,502
$0,28657 $0.28349 $0.23349
499,763
0.00073
1,743,936
'1,033,736
$
$
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0.00007
222,s02
(539,393)
0.03120/"
140,033 $
0.00019 $
493,960
'1,617,866 761,896
710,200
g.253go7o (t)
(1,123,906)
0.0677y0
0.1172% t2)0.1 176% (3)
{') See Case No. INT-G17-05la See Case No. INT-G18-02{3) Cunent PGA Year Lost Gas Rate
Workpaper No. 7
Case No. INT-G-19-06
lntermountain Gas Company
Page 1 of 1
Workpaper No. I
Case No. INT-G-19-06
lntermountain Gas Company
Page 1 of 1
Exhibit No.2
Case No. INT-G-18-02
lnlermountain Gas Company
Page 2 of 10
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