20250807APPLICATION.pdf

RECEIVED
INTERMOUNTAIN° August'' 2025
IDAHO PUBLIC
GAS COMPANY UTILITIES COMMISSION
A Subsidiary of MDU Resources Group,Inc.
In the Community to Serve®
August 7, 2025
Ms. Monica Barrios-Sanchez
Commission Secretary
Idaho Public Utilities Commission
P.O. Box 83720
Boise, ID 83720-0074
RE: Case No. INT-G-25-04
Dear Ms. Barrios-Sanchez:
Attached for consideration by this Commission is an electronic submission of Intermountain Gas
Company's Purchased Gas Cost Adjustment Filing with prices proposed to be effective on October
1, 2025.
If you should have any questions regarding the attached,please don't hesitate to contact me at(208)
377-6015.
Sincerely,
Is/Lori A. Blattner
Lori A. Blattner
Director, Regulatory Affairs
Intermountain Gas Company
Enclosure
cc: Preston Carter

INTERMOUNTAIN GAS COMPANY
CASE NO. INT-G-25-04
APPLICATION,
EXHIBITS,
AND
WORKPAPERS
In the Matter of the Application of INTERMOUNTAIN GAS COMPANY
For Authority to Change its Prices on October 1, 2025
(October 1, 2025 Purchased Gas Cost Adjustment Filing)

Preston N. Carter, ISB No. 8462
Megann E. Meier, ISB No. 11948
Givens Pursley LLP
601 W. Bannock St.
Boise, Idaho 83702
Telephone: [phone]
Attorneys for Intermountain Gas Company
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
In the Matter of the Application of Case No.INT-G-25-04
INTERMOUNTAIN GAS COMPANY
for Authority to Change its Prices 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"),requests
authority,pursuant to Idaho Code Sections 61-307 and 61-622,to place into effect October 1,2025
new rate schedules which will increase its annualized revenues by$303,638. 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. 1 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, Idaho 83707
Lori.Blattner&int a
INTERMOUNTAIN GAS COMPANY's APPLICATION-2

IGCRe-ul�atorygint-ag s.com
and
Preston N. Carter
Megann E. Meier
Givens Pursley LLP
601 W. Bannock St.
Boise, Idaho 83702
prestoncarter(&,givenspursley.com
memggivenspursle.
stephaniew(d), ig venspursley.com
In support of this Application, Intermountain alleges and states as follows:
I.
Intermountain is a gas utility, subject to the jurisdiction of the Commission, engaged in the
sale of and distribution of natural gas within the State of Idaho under authority of Commission
Certificate No. 219, issued December 2, 1955, as amended and supplemented by Order No. 6564,
dated October 3, 1962.
Intermountain provides natural gas service to the following Idaho communities and counties
and adjoining areas:
Ada County-Boise,Eagle,Garden City,Kuna,Meridian,and Star;
Bannock County-Arimo,Chubbuck,Inkom,Lava Hot Springs,McCammon,and Pocatello;
Bear Lake County-Georgetown, and Montpelier;
Bingham County-Aberdeen,Basalt,Blackfoot,Firth,Fort Hall,Moreland/Riverside,and Shelley;
Blaine County-Bellevue,Hailey,Ketchum,and Sun Valley;
Bonneville County-Ammon,Idaho Falls,Iona,and Ucon;
Canyon County-Caldwell,Greenleaf,Middleton,Nampa,Parma, and Wilder;
Caribou County-Bancroft,Grace,and Soda Springs;
Cassia County-Burley,Declo,Malta, and Raft River;
Elmore County-Glenns Ferry,Hammett,and Mountain Home;
Fremont County-Parker and St.Anthony;
Gem County-Emmett;
Gooding County-Gooding and Wendell;
Jefferson County-Lewisville,Menan,Rigby,and Ririe;
Jerome County-Jerome;
Lincoln County- Shoshone;
Madison County-Rexburg and Sugar City;
Minidoka County-Heyburn,Paul,and Rupert;
Owyhee County-Bruneau and Homedale;
Payette County-Fruitland,New Plymouth,and Payette;
INTERMOUNTAIN GAS COMPANY's APPLICATION-3

Power County-American Falls;
Twin Falls County-Buhl,Filer,Hansen,Kimberly,Murtaugh, and Twin Falls;
Washington County-Weiser.
Intermountain's properties in these locations consist of transmission pipelines,liquefied
natural gas storage facilities, compressor stations,distribution mains, services,meters and
regulators, and general plant and equipment.
II.
With this Application,Intermountain seeks to pass through to each of its customer classes
changes in gas related costs resulting from: 1) costs billed to Intermountain from firm transportation
providers including Northwest Pipeline LLC ("Northwest"or"Northwest Pipeline"), 2)an increase
in Intermountain's Weighted Average Cost of Gas ("WACOG"), 3) an updated customer allocation
of gas related costs pursuant to the Company's Purchased Gas Cost Adjustment("PGA")provision,
4)the inclusion of temporary surcharges and credits for one year relating to natural gas purchases
and interstate transportation costs from Intermountain's deferred gas cost accounts, 5)benefits
resulting from Intermountain's management of its storage and firm capacity rights on various
pipeline systems,and 6)benefits associated with the sale of liquefied natural gas from the
Company's Nampa, Idaho facility. Intermountain also seeks to eliminate the temporary surcharges
and credits included in its current prices during the past 12 months,pursuant to Case No. INT-G-24-
04. If approved,these changes would result in a price decrease to the Company's RS, GS-1, IS-R,
and IS-C customer classes and an increase to the Company's LV-1,T-3, and T-4 customer classes.
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. INT-G-95-1, and additionally approved through subsequent proceedings.
INTERMOUNTAIN GAS COMPANY's APPLICATION-4

III.
The Commission approved the current temporary prices, and prices related to the cost of
gas, in Order No. 36338,Case No. INT-G-24-04.
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 which have
occurred since Intermountain's PGA filing in Case No. INT-G-24-04. Exhibit No. 4, which
contains pertinent excerpts from applicable pipeline tariffs, is attached and incorporated by
reference.
The current filing includes an increase in Intermountain's firm transportation cost on the
upstream pipeline facilities of NOVA Gas Transmission Ltd. ("NOVA"), Foothills Pipe Lines
Ltd. ("Foothills"), and Gas Transmission Northwest LLC ("GTN"). The transportation cost
increase is driven by 1) the annualization of the full amount of GTN's pipeline expansion which
was introduced and discussed in the prior PGA, and 2) increases in the transportation rates of
NOVA,partially offset by decreases in the Foothills and GTN transportation rates. The total
firm transportation cost increase resulting from these changes is $653,449.
In addition to the changes described above, the transportation costs related to Northwest
Pipeline have increased due to 1) a general increase in transportation rates and 2) several
contracts with negotiated transportation rates increasing to full-rate as outlined in the contract
terms,partially offset by other contracts that are expiring during the PGA year. The net price
increase resulting from these changes and the changes above is $2,989,323 and is included on
Exhibit No. 5,Lines 3-6. Exhibit No. 5 is attached and incorporated by reference.
INTERMOUNTAIN GAS COMPANY's APPLICATION-5

V.
Intermountain continues to contract a variety of natural gas storage assets on Northwest
Pipeline's system as well as with MountainWest Pipeline, LLC ("MountainWest"). In addition to
providing operational reliability, these storage contracts can provide significant price stability to
customers.
Furthermore, Intermountain continues to effectively manage its natural gas storage assets
at Northwest's Jackson Prairie and MountainWest's Clay Basin storage facilities. Supporting
documents to Line 20 of Exhibit No. 5 show Intermountain's management of these storage assets
will result in$7.8 million in savings for customers.
Overall, Intermountain is including a decrease to the costs of its storage assets due to an
increase in the storage demand credit from the Company's management of its Jackson Prairie
and Clay Basin storage facilities, partially offset by Northwest Pipeline reservation rate
increases. As seen on Exhibit No. 5, Lines 7 through 20, the total decrease to Intermountain's
prices is $5,417,085.
VI.
The WACOG reflected in Intermountain's proposed prices is $0.28734 per therm, as shown
on Exhibit No. 5,Line 22, Col. (f). This compares to $0.26839 per therm currently included in the
Company's tariffs. This represents an increase of approximately$8.7 million as seen on Exhibit
No. 5,Line 22, Col. (h).
The increase in the proposed WACOG can be attributed to two main factors. First, after the
winter of 2024-2025, there was concern within the industry regarding stagnant production in some
areas as well as speculation that national storage levels would be well below historical levels by
November 1, 2025, thus causing futures prices to increase significantly versus past experience.
INTERMOUNTAIN GAS COMPANY'S APPLICATION-6

Second, existing liquefied natural gas ("LNG") exports together with two expected LNG export
facilities planned for Western Canada were also putting a perceived upward pressure on prices.
To help offset some of the volatility in the market,the proposed WACOG includes benefits
to Intermountain's customers generated by the Company's management of its significant natural gas
storage assets. Because gas added to storage is procured during the summer season when prices are
traditionally lower than during the winter,the cost of Intermountain's storage gas is normally less
than what could be obtained on the open market in winter months.Additionally,in an effort to
further stabilize the prices paid by our customers during the upcoming winter period, Intermountain
has entered into various fixed price agreements to lock-in the price for portions of its underground
storage and other winter"flowing" supplies thus stabilizing a portion of the supply price and
insulating it from the significant volatility seen in the futures market.
Intermountain believes that the WACOG proposed in this Application, subject to the effect
of actual supply and demand and based on current market conditions,provides today's most
reasonable forecast of gas costs for the 2025 -2026 PGA period. Intermountain will employ,in
addition to those fixed price agreements already in place, cost effective price arrangements to
further secure the price of flowing gas embedded within this Application when, and if,those pricing
opportunities materialize in the marketplace.
Intermountain believes that timely natural gas price signals enhance its customers' ability to
make informed and appropriate energy use decisions. The Company is committed to alert
customers to any significant impending price changes before their winter natural gas usage occurs.
By employing the Company's Energy Efficiency programs, customer mailings,the Company's
website, and various media resources,Intermountain will continue to educate its customers
regarding the wise and efficient use of natural gas,billing options available to help manage their
INTERMOUNTAIN GAS COMPANY'S APPLICATION-7

energy budget, and any pending natural gas price changes.
VII.
Pursuant to the Commission's Order in Case No. INT-G-24-04,Intermountain included
temporary credits in its October 1,2024 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)net adjustments to temporary
surcharges or credits flowing through to Intermountain's customers.
VIII.
Under the Company'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 gas transportation cost adjustment pursuant to these PGA provisions, as outlined on
Exhibit No. 6,Line 25. The price impact of this adjustment is included on Exhibit No. 5,Line 28.
The Gas Transportation Cost resulting from the adjustment plus the annual difference in demand
charges from Exhibit No. 5,Lines 1 —20, Col. (h) is shown on Exhibit No. 6,Line 29. Exhibit No. 6
is attached and incorporated by reference.
IX.
Intermountain proposes to pass through to its customers the benefits that will be generated
from the management of its transportation capacity,totaling approximately$17.5 million as
outlined on Exhibit No. 8. These benefits include credits generated through releases of a portion of
Intermountain's firm capacity rights on Northwest Pipeline and its upstream pipelines, as well as
credits generated from a release of a portion of Intermountain's Clay Basin storage capacity.
INTERMOUNTAIN GAS COMPANY'S APPLICATION-8

Intermountain proposes to pass back these credit amounts via the per therm credits, as detailed on
Exhibit No. 8 and included on Exhibit No. 7,Line 1. Exhibit Nos. 7 and 8 are attached and
incorporated by reference.
X.
Intermountain proposes to allocate deferred gas costs from its Account No. 191 balance to
its customers through temporary price adjustments to be effective during the 12-month period from
October 1,2025 to September 30,2026, as follows:
1) Intermountain has deferred fixed gas costs in its Account No. 191. The credit amount
shown on Exhibit No. 9, Line 7, Col. (b)of$24.7 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 credits, as detailed on Exhibit No. 9 and included on Exhibit No. 7,Line 2. Exhibit No. 9 is
attached and incorporated by reference.
2) Intermountain has also deferred in its Account No. 191 a variable gas cost debit of$5.1
million, as shown on Exhibit No. 10,Line 2,Col. (b). This deferred debit is attributable to
Intermountain's variable gas costs since October 1,2024. Intermountain proposes to collect this
balance via a per therm debit, as shown on Exhibit No. 10,Line 4, Col. (b) and included on Exhibit
No. 7,Line 3.
3) Finally,Intermountain has deferred in its Account No. 191 deferred gas costs related to
Lost and Unaccounted for Gas as shown on Exhibit No. 10,Lines 5 through 26, Col. (b). This
deferral results in a per therm decrease to Intermountain's customers, as illustrated on Exhibit No.
INTERMOUNTAIN GAS COMPANY'S APPLICATION-9

10. This per therm decrease is included on Exhibit No. 7,Line 3. Exhibit No. 10 is attached and
incorporated by reference.
XI.
Pursuant to Commission Order No. 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 approximately$1.1 million sales
credit as outlined on Exhibit No. 11, Line 7 and shown on Exhibit No. 7,Line 4. Exhibit No. 11 is
attached and incorporated by reference.
XII.
As outlined on Exhibit No. 2,Page 1,Lines 21 through 29,the T-3 and T-4 tariffs include
the following adjustments: a)the removal of existing temporary price changes, and b)the inclusion
of proposed temporary price changes from Exhibit No. 7. The net change from these
aforementioned adjustments results in a rate increase for the Company's T-3 and T-4 customers.
XHL
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.
XIV.
This Application has been brought to the attention of Intermountain's customers through a
Customer Notice and by a Press Release sent to daily and weekly newspapers, and major radio and
television stations in Intermountain's service area. The Press Release and Customer Notice are
attached 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.
INTERMOUNTAIN GAS COMPANY'S APPLICATION- 10

XV.
Intermountain requests that this matter be handled under modified procedure pursuant to
Rules 201-204 of the Commission's Rules of Procedure. Intermountain stands ready for immediate
consideration of this matter.
INTERMOUNTAIN GAS COMPANY'S APPLICATION- 11

XVI.
Intermountain respectfully petitions the Idaho Public Utilities Commission as follows:
a. That the proposed rate schedules submitted as Exhibit No. 3 be approved without
suspension and made effective as of October 1, 2025 in the manner shown on Exhibit
No. 3;
b. That the filing requirement for the Deferred Gas Cost Balance,LNG Sales Cost Benefit
Analysis, and Weighted Average Cost of Gas reports be maintained at quarterly
frequency;
c. That this Application be heard and acted upon without hearing under modified procedure;
and
d. For such other relief as this Commission may determine proper.
DATED: August 7, 2025.
INTERMOUNTAIN GAS COMPANY GIVENS PURSLEY LLP
By By
Lori A. Blattner Preston N. Carter
Director—Regulatory Affairs Attorney for Intermountain Gas Company
INTERMOUNTAIN GAS COMPANY'S APPLICATION- 12

CERTIFICATE OF SERVICE
I certify that on August 7,2025,a true and correct copy of the foregoing Case No. INT-G-25-
04 was served upon the following parties via the manner indicated below:
Ed Finklea Electronic Mail
Alliance of Western Energy Consumers
545 Grandview Drive
Ashland, OR 97520
[e-mail]
Michael Hale Electronic Mail
J. R. Simplot Company
1099 W. Front St.
Boise, ID 83702
[e-mail]
/s/Jacob Betterbed
Jacob Betterbed—Regulatory Analyst
INTERMOUNTAIN GAS COMPANY'S APPLICATION- 13

EXHIBIT NO. 1
CASE NO. INT-G-25-04
INTERMOUNTAIN GAS COMPANY
SUMMARY OF PRICE CHANGES
(2 pages)

Exhibit No. 1
Case No. INT-G-25-04
Intermountain Gas Company
Page 1 of 2
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Exhibit No. 1
Case No. INT-G-25-04
Intermountain Gas Company
Page 2 of 2
INTERMOUNTAIN GAS COMPANY
ANALYSIS OF INT-G-25-04 PRICE CHANGE
Line No. Description Amount Total
(a) (b) (c)
1 Deferrals:
2 INT-G-24-04 Temporaries Reversed $ 33,578,952 (')
3 Add INT-G-25-04 Temporaries:
4 Fixed Deferred Gas Costs $ (42,148,285)(2)
5 Variable Deferred Gas Costs 5,140,012 (3)
6 Lost and Unaccounted For Gas Costs (1,193,817)(4)
7 LNG Sales Credit (1,086,693)(5)
8 Total Temporaries Added (39,288,783)
9 Total Deferrals $ (5,709,831)
10 Base Rate Price Change:
11 Fixed Cost Changes:
12 NWP TF-1 Reservation(Full Rate) $ (2,459,114)(e)
13 NWP TF-1 Reservation(Discounted) 4,794,988 (7)
14 Upstream Capacity(Full Rate) (10,450,391)(8)
15 Upstream Capacity(Discounted) 11,103,840 (9)
16 SGS-2F and LS-2F 57,915 (10)
17 Other Storage Facility (5,475,000)
18 Total Fixed Cost Change (2,427,762)
19 Changes in WACOG 8,662,228 (12)
20 Reallocation of Fixed Costs (218,538)('3)
21 Total Base Rate Price Changes 6,015,928
22 Total Annual Price Change $ 306,097
23 Annual Price Change per Exhibit No.1,Page 1 $ 303,638 (14)
24 Difference Due to Rounding $ 2,459
(') Temporary prices from INT-G-24-04 times Exhibit No.1,Page 1,Lines 2-4,7 and 9,Column(b)
(2) See Exhibit No.8,Line 4,Column(b),plus Exhibit No.9,Line 7,Column(b)
(3) See Exhibit No.10,Line 2,Column(b)
(4) See Exhibit No.10,Line 10 plus Line 18,Column(b)
(5) See Exhibit No.11,Line 5,Column(b)
(6) See Exhibit No.5,Line 3,Column(h)
(7) See Exhibit No.5,Line 4,Column(h)
(8) See Exhibit No.5,Line 5,Column(h)
(9) See Exhibit No.5,Line 6,Column(h)
(10) See Exhibit No.5,sum of Lines 9-19,Column(h)
(") See Exhibit No.5,Line 20,Column(h)
(12) See Exhibit No.5,Line 22,Column(h)
(13) See Exhibit No.5,Line 28,Columns(i)-(k),times Line 24,Columns(i)-(k)
(") See Exhibit No.1,Page 1,Line 11,Column(e)

EXHIBIT NO. 2
CASE NO. INT-G-25-04
INTERMOUNTAIN GAS COMPANY
CURRENT TARIFFS
Showing Proposed Price Changes
(10 pages)

Exhibit No.2
Case No. INT-G-25-04
Intermountain Gas Company
Page 1 of 2
INTERMOUNTAIN GAS COMPANY
Comparison of Proposed October 1,2025 Prices
To Currently Approved Prices
Currently Proposed
Line Approved Proposed October 1,2025
No. Rate Class Prices Adjustment Prices
(a) (b) (c) (d)
1 RS $ 0.54808 $ (0.00189) $ 0.54619
2 GS-1
3 Block 1 0.55500 (0.00017) 0.55483
4 Block 2 0.53353 (0.00017) 0.53336
5 Block 3 0.51280 (0.00017) 0.51263
6 Block 4 0.45011 (0.00017) 0.44994
7 CNG Fuel
8 Block 1 0.51280 (0.00017) 0.51263
9 Block 2 0.45011 (0.00017) 0.44994
10 IS-R t�l 0.53659 (0.00189) 0.53470
11 IS-C I21
12 Block 1 0.55500 (0.00017) 0.55483
13 Block 2 0.53353 (0.00017) 0.53336
14 Block 3 0.51280 (0.00017) 0.51263
15 Block 4 0.45011 (0.00017) 0.44994
16 LV-1
17 Demand Charge 0.32000 - 0.32000
18 Block 1 0.35435 0.01891 0.37326
19 Block 2 0.33622 0.01891 0.35513
20 Block 3 0.33170 0.01891 0.35061
21 T-3
22 Block 1 0.03489 0.00136 (3) 0.03625
23 Block 2 0.01299 0.00136 (3) 0.01435
24 Block 3 0.00349 0.00136 (3) 0.00485
25 T-4
26 Demand Charge 0.26414 0.02984 c41 0.29398
27 Block 1 0.02172 - 0.02172
28 Block 2 0.00768 0.00768
29 Block 3 0.00236 0.00236
(1)The IS-R price is based on the IRS price and receives the same PGA adjustments
(2)The IS-C price is based on the GS-1 price and receives the same PGA adjustments
Remove INT-G-24-04 temporary,($0.00205),and add temporary from Exhibit No.7
(3)Line 5,Column(a)
(4)Remove INT-G-24-04 temporary,($0.05586),and add temporary from Exhibit No.7
Line 5,Column(f)

Exhibit No.2
Case No. INT-G-25-04
Intermountain Gas Company
Page 2 of 2
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I.P.U.C. Gas Tariff IDAHO PUBLIC UTILITIES COMMISSION
Rate Schedules
Fourteenth Fifteenth Revised Sheet No. 1 (Page 1 of 1) Approved Effective
Name Sept. 30, 2024 Oct. 1, 2024
of Utility Intermountain Gas Company Per O.N. 36338
Monica Barrios-Sanchez Secretary
Rate Schedule RS
RESIDENTIAL SERVICE
APPLICABILITY:
Applicable to any customer using natural gas for residential purposes.
RATE:
Monthly minimum charge is the Customer Charge.
Customer Charge: $8.00 per bill
Per Therm Charge: $0.548080.54619*
*Includes the following:
Cost of Gas: 1)Temporary purchased gas cost adjustment ($0.0 7 2190.08953)
2)Weighted average cost of gas $0.268390.28734
3)Gas transportation cost $0.207370.20388
Distribution Cost: $0.13301
EE Charge: $0.01149
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for the cost of purchased gas as provided for in Rate Schedule PGA.
This adjustment is incorporated into the calculation of the Cost of Gas stated on customer bills.
ENERGY EFFICIENCY CHARGE ADJUSTMENT:
This tariff is subject to an adjustment for costs related to the Company's Energy Efficiency program as
provided for in Rate Schedule EEC-RS. The Energy Efficiency Charge is separately stated on customer bills.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the Company's Tariff, of
which this rate schedule is a part.
issued by: Intermountain Gas Company
By: Lori A. Blattner Title: Director—Regulatory Affairs

I.P.U.C. Gas Tariff IDAHO PUBLIC UTILITIES COMMISSION
Rate Schedules
Sixty-"'Nint"Seventieth Revised Sheet No. 3 (Page 1 of 2) Approved Effective
Name Sept. 30, 2024 Oct. 1, 2024
of Utility Intermountain Gas Company Per O.N. 36338
Monica Barrios-Sanchez Secretary
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 allowed at
the Company's discretion.
RATE:
Monthly minimum charge is the Customer Charge.
Customer Charge: $15.00 per bill
Per Therm Charge: Block One: First 200 therms per bill @ $0.555000.55483"
Block Two: Next 1,800 therms per bill @ $0333530.53336*
Block Three: Next 8,000 therms per bill @ $0312800.51263*
Block Four: Over 10,000 therms per bill @ $0.^o 450110.44994*
*Includes the following:
Cost of Gas: 1)Temporary purchased gas cost adjustment ($0.071130.07969)
2)Weighted average cost of gas $0.268390.28734
3)Gas transportation cost $0.188890.17833
Distribution Cost: Block One: First 200 therms per bill @ $0.16885
Block Two: Next 1,800 therms per bill @ $0.14738
Block Three: Next 8,000 therms per bill @ $0.12665
Block Four: Over 10,000 therms per bill @ $0.06396
EE Charge: $0.00000
Issued by: Intermountain Gas Company
By: Lori A. Blattner Title: Director-Regulatory Affairs

I.P.U.C. Gas Tariff IDAHO PUBLIC UTILITIES COMMISSION
Rate Schedules Approved Effective
Sixty-"'Nint"Seventieth Revised Sheet No. 3 (Page 2 of 2) Sept. 30, 2024 Oct. 1, 2024
Name of Utility an Intermountain Gas Company Per O.N. 36338
Monica Barrios-Sanchez Secretary
Rate Schedule GS-1
GENERAL SERVICE
(Continued)
For separately metered deliveries of gas utilized solely as Compressed Natural Gas Fuel in vehicular internal
combustion engines.
Customer Charge: $15.00 per bill
Per Therm Charge: Block One: First 10,000 therms per bill @ $0.512800.51263*
Block Two: Over 10,000 therms per bill @ $0.400110.44994"
*Includes the following:
Cost of Gas: 1)Temporary purchased gas cost adjustment ($0.071130.07969)
2)Weighted average cost of gas $0.268390.28734
3) Gas transportation cost $9-�O.17833
Distribution Cost: Block One: First 10,000 therms per bill @ $0.12665
Block Two: Over 10,000 therms per bill @ $0.06396
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for the cost of purchased gas as provided for in Rate Schedule PGA.
This adjustment is incorporated into the calculation of the Cost of Gas stated on customer bills.
ENERGY EFFICIENCY CHARGE ADJUSTMENT:
This tariff is subject to an adjustment for costs related to the Company's Energy Efficiency program as
provided for in Rate Schedule EEC-GS. The Energy Efficiency Charge is not applicable to gas utilized solely
as Compressed Natural Gas Fuel in vehicular internal combustion engines. The Energy Efficiency Charge is
separately stated on customer bills.
SERVICE CONDITIONS:
1. All natural gas service hereunder is subject to the General Service Provisions of the Company's Tariff,
of which this rate schedule is a part.
Issued by: Intermountain Gas Company
By: Lori A. Blattner Title: Director-Regulatory Affairs

I.P.U.C. Gas Tariff IDAHO PUBLIC UTILITIES COMMISSION
Rate Schedules
Twenty-FA-4-Sixth Revised Sheet No. 4 (Page 1 of 2 Approved Effgctive
Name Intermountain Gas Company Sept. 30. 2024 Oct. 1. 2024
of Utility pan y Per O.N. 36338
Monica Barrios-Sanchez Secretary
Rate Schedule IS-R
RESIDENTIAL INTERRUPTIBLE SNOWMELT SERVICE
APPLICABILITY:
Applicable to any residential customer otherwise eligible to receive service under Rate Schedule IRS who
has added natural gas snowmelt equipment after 6/1/2010. 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 IS-R and will be
separately and individually metered. All service hereunder is interruptible at the sole discretion of the
Company.
FACILITY REIMBURSEMENT CHARGE:
All new interruptible Snowmelt service customers are required to pay for the cost of the Snowmelt meter set
and other related facility and equipment costs, prior to the installation of the meter set. Any request to alter
the physical location of the meter set and related facilities from Company's initial design may be granted
provided, however, the Company can reasonably accommodate said relocation and Customer agrees to
pay all related costs.
RATE:
Monthly minimum charge is the Customer Charge.
Customer Charge: $8.00 per bill
Per Therm Charge: $9-536590.53470*
*Includes the following:
Cost of Gas: 1)Temporary purchased gas cost adjustment ($0.072190.08953)
2)Weighted average cost of gas $0.268390.28734
3)Gas transportation cost $070.20388
Distribution Cost: $0.13301
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.
Issued by: Intermountain Gas Company
By: Lori A. Blattner Title: Director—Regulatory Affairs

I.P.U.C. Gas Tariff IDAHO PUBLIC UTILITIES COMMISSION
Rate Schedules Approved Effective
Twent -Fiftheuth Revised Sheet No. 5 (Page 1 of 2 Sept. 30, 2024 Oct. 1, 2624
Name Intermountain Gas Company Per O.N. 36338
of Utility P Y
Monica Barrios-Sanchez Secretary
Rate Schedule IS-C
SMALL COMMERICAL INTERRUPTIBLE SNOWMELT SERVICE
APPLICABILITY:
Applicable to any customer otherwise eligible to receive gas service under Rate Schedule GS-1 who has
added natural gas snowmelt equipment after 6/1/2010. 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 IS-C and will be
separately and individually metered. All service hereunder is interruptible at the sole discretion of the
Company.
FACILITY REIMBURSEMENT CHARGE:
All new interruptible Snowmelt service customers are required to pay for the cost of the Snowmelt meter set
and other related facility and equipment costs, prior to the installation of the meter set. Any request to alter
the physical location of the meter set and related facilities from Company's initial design may be granted
provided, however, the Company can reasonably accommodate said relocation and Customer agrees to pay
all related costs.
RATE:
Monthly minimum charge is the Customer Charge.
Customer Charge: $12.50 per bill
Per Therm Charge: Block One: First 200 therms per bill @ $0.555000.55483"
Block Two: Next 1,800 therms per bill @ $0333530.53336*
Block Three: Next 8,000 therms per bill @ $0.512800.51263*
Block Four: Over 10,000 therms per bill @ $0.450110.44994*
*Includes the following:
Cost of Gas: 1)Temporary purchased gas cost adjustment ($0.071130.07969)
2)Weighted average cost of gas $0.269390.28734
3) Gas transportation cost $0.188890.17833
Distribution Charge: Block One: First 200 therms per bill @ $0.16885
Block Two: Next 1,800 therms per bill @ $0.14738
Block Three: Next 8,000 therms per bill @ $0.12665
Block Four: Over 10,000 therms per bill @ $0.06396
Issued by: Intermountain Gas Company
By: Lori A. Blattner Title: Director—Regulatory Affairs

I.P.U.C. Gas Tariff IDAHO PUBLIC UTILITIES COMMISSION
Rate Schedules
Sevent - Seventh Revised Sheet No. 7 (Page 1 of 2 Approved Effective
Name Intermountain Gas Company Sept. 30, 2024 Oct. 1. 2024
of Utility pan y Per O.N. 36338
Monica Barrios-Sanchez Secretary
Rate Schedule LV-1
LARGE VOLUME FIRM SALES SERVICE
AVAILABILITY:
Available at any mutually agreeable delivery point on the Company's distribution system to any existing
customer receiving service under the Company's rate schedule LV-1 or any customer not previously served
under this schedule whose usage does not exceed 500,000 therms annually, upon execution of a one-year
minimum written service contract for firm sales service in excess of 200,000 therms per year.
MONTHLY RATE:
Customer Charge: $150.00 per bill
Demand Charge: $0.32000 per MDFQ therm
Per Therm Charge: Block One: First 35,000 therms per bill @ $9354300.37326*
Block Two: Next 35,000 therms per bill @ $9.336220.35513*
Block Three: Over 70,000 therms per bill @ $9.331700.35061*
*Includes the following:
Cost of Gas: 1)Temporary purchased gas cost adjustment ($9.04997-)0.04321)
2)Weighted average cost of gas $090.28734
3) Gas transportation cost $0.104030.09913
Distribution Cost: Block One: First 35,000 therms per bill @ $0.03000
Block Two: Next 35,000 therms per bill @ $0.01187
Block Three: Over 70,000 therms per bill @ $0.00735
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for the cost of purchased gas as provided for in Rate Schedule PGA.
This adjustment is incorporated into the calculation of the Cost of Gas stated on customer bills.
SERVICE CONDITIONS:
1. All natural gas service hereunder is subject to the General Service Provisions of the Company's
Tariff, of which this Rate Schedule is a part.
2. The customer shall negotiate with the Company,a mutually agreeable Maximum Daily Firm Quantity
(MDFQ), which will be stated in and in effect throughout the term of the service contract.
3. The monthly Demand Charge will be equal to the MDFQ times the Demand Charge rate. Demand
Charge relief will be afforded to those LV-1 customers when circumstances impacted by force
majeure events prevent the Company from delivering natural gas to the customer's meter.
Issued by: Intermountain Gas Company
By: Lori A. Blattner Title: Director—Regulatory Affairs

I.P.U.C. Gas Tariff IDAHO PUBLIC UTILITIES COMMISSION
Rate Schedules Approved Eff ctive
Twent -Seventhixth Revised Sheet No. 8 (Page 1 of 1
Sept. 30, 2024 Oct. 1, 1024
Name
of Utility Intermountain Gas Company Per O.N. 36338
Monica Barrios-Sanchez Secretary
Rate Schedule T-3
INTERRUPTIBLE DISTRIBUTION 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 interruptible transportation service.
MONTHLY RATE:
Customer Charge: $300.00 per bill
Per Therm Charge: Block One: First 100,000 therms transported @ $ 90.03625*
Block Two: Next 50,000 therms transported @$0.01-2990.01435*
Block Three: Over 150,000 therms transported @ $0.003490.00485*
*Includes temporary purchased gas cost adjustment of($9.092050.00069)
ANNUAL MINIMUM BILL:
The customer shall be subject to the payment of an annual minimum bill based on annual usage of 200,000
therms. The deficit usage below 200,000 therms shall be billed at the T-3 Block 1 rate. An annual minimum
bill will not apply if the customer is a renewable natural gas production facility.
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for the cost of purchased gas as provided for in Rate Schedule PGA.
This adjustment is incorporated into the calculation of the Cost of Gas stated on customer bills.
SERVICE CONDITIONS:
1. All natural gas service hereunder is subject to the General Service Provisions of the Company's
Tariff, of which this Rate Schedule is a part.
2. This service does not include the cost of the customer's gas supply or the interstate pipeline capacity.
The customer is responsible for procuring its own supply of natural gas and transportation to
Intermountain's distribution system under this Rate Schedule.
3. The customer understands and agrees that the Company is not responsible to deliver gas supplies
to the customer which have not been nominated, scheduled, and delivered by the interstate pipeline
to the designated city gate.
4. The 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.
5. If 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.
Issued by: Intermountain Gas Company
By: Lori A. Blattner Title: Director—Regulatory Affairs

I.P.U.C. Gas Tariff IDAHO PUBLIC UTILITIES COMMISSION
Rate Schedules Approved Effective
Twent -Fo�Fifth Revised Sheet No. 9 (Page 1 of 2 Sept. 30, 2024 Oct. 1. 2024
Name Intermountain Gas Company Per O.N. 36338
of Utility p y Monica Barrios-Sanchez Secretary
Rate Schedule T-4
FIRM DISTRIBUTION ONLY TRANSPORTATION SERVICE
AVAILABILITY:
Available at any mutually agreeable delivery point on the Company's distribution system to any customer
upon execution of a one year minimum written service contract for firm distribution transportation service in
excess of 200,000 therms per year.
MONTHLY RATE:
Customer Charge: $150.00 per bill
Demand Charge: $0 26414 0.29398 per MDFQ therm*
Per Therm Charge: Block One: First 250,000 therms transported @ $0.02172
Block Two: Next 500,000 therms transported @ $0.00768
Block Three: Over 750,000 therms transported @ $0.00236
*Includes temporary purchased gas cost adjustment of($8.055660.02602)
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for the cost of purchased gas as provided for in Rate Schedule PGA.
This adjustment is incorporated into the calculation of the Cost of Gas stated on customer bills.
SERVICE CONDITIONS:
1. All natural gas service hereunder is subject to the General Service Provisions of the Company's
Tariff, of which this Rate Schedule is a part.
2. This service does not include the cost of the customer's gas supply of the interstate pipeline capacity.
The customer is responsible for procuring its own supply of natural gas and transportation to
Intermountain's distribution system under this Rate Schedule.
3. The customer understands and agrees that the Company is not responsible to deliver gas supplies
to the customer which have not been nominated, scheduled, and delivered by the interstate pipeline
to the designated city gate.
4. The 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.
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.
Issued by: Intermountain Gas Company
By: Lori A. Blattner Title: Director—Regulatory Affairs

EXHIBIT NO. 3
CASE NO. INT-G-25-04
INTERMOUNTAIN GAS COMPANY
PROPOSED TARIFFS
(8 pages)

I.P.U.C. Gas Tariff
Rate Schedules
Fifteenth Revised Sheet No. 1 (Page 1 of 1)
Name Intermountain Gas Company
of Utility
Rate Schedule RS
RESIDENTIAL SERVICE
APPLICABILITY:
Applicable to any customer using natural gas for residential purposes.
RATE:
Monthly minimum charge is the Customer Charge.
Customer Charge: $8.00 per bill
Per Therm Charge: $0.54619*
*Includes the following:
Cost of Gas: 1)Temporary purchased gas cost adjustment ($0.08953)
2)Weighted average cost of gas $0.28734
3)Gas transportation cost $0.20388
Distribution Cost: $0.13301
EE Charge: $0.01149
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for the cost of purchased gas as provided for in Rate Schedule PGA.
This adjustment is incorporated into the calculation of the Cost of Gas stated on customer bills.
ENERGY EFFICIENCY CHARGE ADJUSTMENT:
This tariff is subject to an adjustment for costs related to the Company's Energy Efficiency program as
provided for in Rate Schedule EEC-RS. The Energy Efficiency Charge is separately stated on customer bills.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the Company's Tariff, of
which this rate schedule is a part.
issued by: Intermountain Gas Company
By: Lori A. Blattner Title: Director—Regulatory Affairs

I.P.U.C. Gas Tariff
Rate Schedules
Seventieth Revised Sheet No. 3 (Page 1 of 2)
Name Intermountain Gas Company
of Utility
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 allowed at
the Company's discretion.
RATE:
Monthly minimum charge is the Customer Charge.
Customer Charge: $15.00 per bill
Per Therm Charge: Block One: First 200 therms per bill @ $0.55483"
Block Two: Next 1,800 therms per bill @ $0.53336*
Block Three: Next 8,000 therms per bill @ $0.51263*
Block Four: Over 10,000 therms per bill @ $0.44994*
*Includes the following:
Cost of Gas: 1)Temporary purchased gas cost adjustment ($0.07969)
2)Weighted average cost of gas $0.28734
3)Gas transportation cost $0.17833
Distribution Cost: Block One: First 200 therms per bill @ $0.16885
Block Two: Next 1,800 therms per bill @ $0.14738
Block Three: Next 8,000 therms per bill @ $0.12665
Block Four: Over 10,000 therms per bill @ $0.06396
EE Charge: $0.00000
Issued by: Intermountain Gas Company
By: Lori A. Blattner Title: Director—Regulatory Affairs

I.P.U.C. Gas Tariff
Rate Schedules
Seventieth Revised Sheet No. 3 (Page 2 of 2)
Name Intermountain Gas Company
of Utility
Rate Schedule GS-1
GENERAL SERVICE
(Continued)
For separately metered deliveries of gas utilized solely as Compressed Natural Gas Fuel in vehicular internal
combustion engines.
Customer Charge: $15.00 per bill
Per Therm Charge: Block One: First 10,000 therms per bill @ $0.51263*
Block Two: Over 10,000 therms per bill @ $0.44994"
*Includes the following:
Cost of Gas: 1)Temporary purchased gas cost adjustment ($0.07969)
2)Weighted average cost of gas $0.28734
3) Gas transportation cost $0.17833
Distribution Cost: Block One: First 10,000 therms per bill @ $0.12665
Block Two: Over 10,000 therms per bill @ $0.06396
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for the cost of purchased gas as provided for in Rate Schedule PGA.
This adjustment is incorporated into the calculation of the Cost of Gas stated on customer bills.
ENERGY EFFICIENCY CHARGE ADJUSTMENT:
This tariff is subject to an adjustment for costs related to the Company's Energy Efficiency program as
provided for in Rate Schedule EEC-GS. The Energy Efficiency Charge is not applicable to gas utilized solely
as Compressed Natural Gas Fuel in vehicular internal combustion engines. The Energy Efficiency Charge is
separately stated on customer bills.
SERVICE CONDITIONS:
1. All natural gas service hereunder is subject to the General Service Provisions of the Company's Tariff,
of which this rate schedule is a part.
Issued by: Intermountain Gas Company
By: Lori A. Blattner Title: Director—Regulatory Affairs

I.P.U.C. Gas Tariff
Rate Schedules
Twenty-Sixth Revised Sheet No.4 (Page 1 of 2
Name Intermountain Gas Company
of usrt p Y
Rate Schedule IS-R
RESIDENTIAL INTERRUPTIBLE SNOWMELT SERVICE
APPLICABILITY:
Applicable to any residential customer otherwise eligible to receive service under Rate Schedule RS who
has added natural gas snowmelt equipment after 6/1/2010. 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 IS-R and will be
separately and individually metered. All service hereunder is interruptible at the sole discretion of the
Company.
FACILITY REIMBURSEMENT CHARGE:
All new interruptible Snowmelt service customers are required to pay for the cost of the Snowmelt meter set
and other related facility and equipment costs, prior to the installation of the meter set. Any request to alter
the physical location of the meter set and related facilities from Company's initial design may be granted
provided, however, the Company can reasonably accommodate said relocation and Customer agrees to
pay all related costs.
RATE:
Monthly minimum charge is the Customer Charge.
Customer Charge: $8.00 per bill
Per Therm Charge: $0.53470*
*Includes the following:
Cost of Gas: 1)Temporary purchased gas cost adjustment ($0.08953)
2)Weighted average cost of gas $0.28734
3)Gas transportation cost $0.20388
Distribution Cost: $0.13301
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.
Issued by: Intermountain Gas Company
By: Lori A. Blattner Title: Director—Regulatory Affairs

I.P.U.C. Gas Tariff
Rate Schedules
Twenty-Fifth Revised Sheet No. 5 (Page 1 of 2
Name Intermountain Gas Company
of usrt P Y
Rate Schedule IS-C
SMALL COMMERICAL INTERRUPTIBLE SNOWMELT SERVICE
APPLICABILITY:
Applicable to any customer otherwise eligible to receive gas service under Rate Schedule GS-1 who has
added natural gas snowmelt equipment after 6/1/2010. 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 IS-C and will be
separately and individually metered. All service hereunder is interruptible at the sole discretion of the
Company.
FACILITY REIMBURSEMENT CHARGE:
All new interruptible Snowmelt service customers are required to pay for the cost of the Snowmelt meter set
and other related facility and equipment costs, prior to the installation of the meter set. Any request to alter
the physical location of the meter set and related facilities from Company's initial design may be granted
provided, however, the Company can reasonably accommodate said relocation and Customer agrees to pay
all related costs.
RATE:
Monthly minimum charge is the Customer Charge.
Customer Charge: $12.50 per bill
Per Therm Charge: Block One: First 200 therms per bill @ $0.55483"
Block Two: Next 1,800 therms per bill @ $0.53336*
Block Three: Next 8,000 therms per bill @ $0.51263*
Block Four: Over 10,000 therms per bill @ $0.44994*
*Includes the following:
Cost of Gas: 1)Temporary purchased gas cost adjustment ($0.07969)
2)Weighted average cost of gas $0.28734
3)Gas transportation cost $0.17833
Distribution Charge: Block One: First 200 therms per bill @ $0.16885
Block Two: Next 1,800 therms per bill @ $0.14738
Block Three: Next 8,000 therms per bill @ $0.12665
Block Four: Over 10,000 therms per bill @ $0.06396
Issued by: Intermountain Gas Company
By: Lori A. Blattner Title: Director—Regulatory Affairs

I.P.U.C. Gas Tariff
Rate Schedules
Seventy-Seventh Revised Sheet No. 7 (Page 1 of 2
Name Intermountain Gas Company
of Utility p Y
Rate Schedule LV-1
LARGE VOLUME FIRM SALES SERVICE
AVAILABILITY:
Available at any mutually agreeable delivery point on the Company's distribution system to any existing
customer receiving service under the Company's rate schedule LV-1 or any customer not previously served
under this schedule whose usage does not exceed 500,000 therms annually, upon execution of a one-year
minimum written service contract for firm sales service in excess of 200,000 therms per year.
MONTHLY RATE:
Customer Charge: $150.00 per bill
Demand Charge: $0.32000 per MDFQ therm
Per Therm Charge: Block One: First 35,000 therms per bill @ $0.37326*
Block Two: Next 35,000 therms per bill @ $0.35513*
Block Three: Over 70,000 therms per bill @ $0.35061
*Includes the following:
Cost of Gas: 1)Temporary purchased gas cost adjustment ($0.04321)
2)Weighted average cost of gas $0.28734
3) Gas transportation cost $0.09913
Distribution Cost: Block One: First 35,000 therms per bill @ $0.03000
Block Two: Next 35,000 therms per bill @ $0.01187
Block Three: Over 70,000 therms per bill @ $0.00735
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for the cost of purchased gas as provided for in Rate Schedule PGA.
This adjustment is incorporated into the calculation of the Cost of Gas stated on customer bills.
SERVICE CONDITIONS:
1. All natural gas service hereunder is subject to the General Service Provisions of the Company's
Tariff, of which this Rate Schedule is a part.
2. The customer shall negotiate with the Company,a mutually agreeable Maximum Daily Firm Quantity
(MDFQ), which will be stated in and in effect throughout the term of the service contract.
3. The monthly Demand Charge will be equal to the MDFQ times the Demand Charge rate. Demand
Charge relief will be afforded to those LV-1 customers when circumstances impacted by force
majeure events prevent the Company from delivering natural gas to the customer's meter.
Issued by: Intermountain Gas Company
By: Lori A. Blattner Title: Director—Regulatory Affairs

I.P.U.C. Gas Tariff
Rate Schedules
Twenty-Seventh Revised Sheet No. 8 (Page 1 of 1
Name Intermountain Gas Company
of Utility p Y
Rate Schedule T-3
INTERRUPTIBLE DISTRIBUTION 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 interruptible transportation service.
MONTHLY RATE:
Customer Charge: $300.00 per bill
Per Therm Charge: Block One: First 100,000 therms transported @ $0.03625*
Block Two: Next 50,000 therms transported @ $0.01435*
Block Three: Over 150,000 therms transported @ $0.00485*
*Includes temporary purchased gas cost adjustment of($0.00069)
ANNUAL MINIMUM BILL:
The customer shall be subject to the payment of an annual minimum bill based on annual usage of 200,000
therms. The deficit usage below 200,000 therms shall be billed at the T-3 Block 1 rate. An annual minimum
bill will not apply if the customer is a renewable natural gas production facility.
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for the cost of purchased gas as provided for in Rate Schedule PGA.
This adjustment is incorporated into the calculation of the Cost of Gas stated on customer bills.
SERVICE CONDITIONS:
1. All natural gas service hereunder is subject to the General Service Provisions of the Company's
Tariff, of which this Rate Schedule is a part.
2. This service does not include the cost of the customer's gas supply or the interstate pipeline capacity.
The customer is responsible for procuring its own supply of natural gas and transportation to
Intermountain's distribution system under this Rate Schedule.
3. The customer understands and agrees that the Company is not responsible to deliver gas supplies
to the customer which have not been nominated, scheduled, and delivered by the interstate pipeline
to the designated city gate.
4. The 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.
5. If 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.
Issued by: Intermountain Gas Company
By: Lori A. Blattner Title: Director—Regulatory Affairs

I.P.U.C. Gas Tariff
Rate Schedules
Twenty-Fifth Revised Sheet No. 9 (Page 1 of 2
Name Intermountain Gas Company
of usrt p Y
Rate Schedule T-4
FIRM DISTRIBUTION ONLY TRANSPORTATION SERVICE
AVAILABILITY:
Available at any mutually agreeable delivery point on the Company's distribution system to any customer
upon execution of a one year minimum written service contract for firm distribution transportation service in
excess of 200,000 therms per year.
MONTHLY RATE:
Customer Charge: $150.00 per bill
Demand Charge: $0.29398 per MDFQ therm*
Per Therm Charge: Block One: First 250,000 therms transported @ $0.02172
Block Two: Next 500,000 therms transported @ $0.00768
Block Three: Over 750,000 therms transported @ $0.00236
*Includes temporary purchased gas cost adjustment of($0.02602)
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for the cost of purchased gas as provided for in Rate Schedule PGA.
This adjustment is incorporated into the calculation of the Cost of Gas stated on customer bills.
SERVICE CONDITIONS:
1. All natural gas service hereunder is subject to the General Service Provisions of the Company's
Tariff, of which this Rate Schedule is a part.
2. This service does not include the cost of the customer's gas supply of the interstate pipeline capacity.
The customer is responsible for procuring its own supply of natural gas and transportation to
Intermountain's distribution system under this Rate Schedule.
3. The customer understands and agrees that the Company is not responsible to deliver gas supplies
to the customer which have not been nominated, scheduled, and delivered by the interstate pipeline
to the designated city gate.
4. The 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.
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.
Issued by: Intermountain Gas Company
By: Lori A. Blattner Title: Director—Regulatory Affairs

EXHIBIT NO. 4
CASE NO. INT-G-25-04
INTERMOUNTAIN GAS COMPANY
PERTINENT EXCERPTS PERTAINING TO INTERSTATE PIPELINES AND RELATED
FACILITIES
(29 pages)

Exhibit No.4
Case No. INT-G-25-04
Intermountain Gas Company
Page 1 of 29
NORTHWEST PIPELINE LLC
(7 pages)

Exhibit No.4
Case No. INT-G-25-04
Intermountain Gas Company
Page 2 of 29
FEDERAL ENERGY REGULATORY COMMISSION
WASHINGTON,DC 20426
OFFICE OF ENERGY MARKET REGULATION
Northwest Pipeline LLC
Docket No. RP22-1155-001
Issued: December 21, 2022
On November 30, 2022,Northwest Pipeline LLC filed tariff records'to implement
the rates provided in the Stipulation and Agreement(Settlement)filed in Docket No.
RP22-1155-000,which was approved by the Commission on November 15,2022.Z
Specifically,the tariff records place the Settlement rates into effect. Pursuant to authority
delegated to the Director,Division of Pipeline Regulation,under 18 C.F.R. § 375.307,the
tariff records are accepted, effective January 1,2023,as requested.
The filing was publicly noticed. No protests or adverse comments were filed.
Pursuant to Rule 214 of the Commission's regulations(18 C.F.R. § 385.214),notices of
intervention,timely-filed motions to intervene, and any unopposed motions to intervene
out-of-time filed before the issuance date of this order are granted.
This action shall not be construed as a waiver of the requirements of section 7 of
the Natural Gas Act, as amended; nor shall it be 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 the applicant's tariff,nor shall such acceptance
be deemed as recognition of any claimed contractual right or obligation associated
therewith; and such acceptance is without prejudice to any findings or orders which have
been or may hereafter be made by the Commission in any proceeding now pending or
hereafter instituted by or against the applicant.
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. § 385.713.
Issued by: Marsha K. Palazzi,Director,Division of Pipeline Regulation
'See Appendix.
'Northwest Pipeline LLC., 181 FERC¶61,118 (2022).

Exhibit No.4
Case No. INT-G-25-04
Intermountain Gas Company
Page 3 of 29
Document Accession #: 20221130-5273 Filed Date: 11/30/2022
Northwest Pipeline LLC
FERC Gas Tariff Twelfth Revised Sheet No.5
Fifth Revised Volume No.1 Superseding
Eleventh Revised Sheet No.5
STATEMENT OF RATES
Effective Rates Applicable to
Rate Schedules TF-1, TF-2, TI-1, TFL-1 and TIL-1
(Dollars per Dth)
Base
Rate Schedule and Tariff Rate (1) , (3)
Type of Rate Minimum Maximum
Rate Schedule TF-1 (4) (5)
Reservation
(Large Customer)
System-Wide .00000 .37250
25 Year Evergreen Exp. .00000 .27082
Volumetric (2)
(Large Customer)
System-Wide .00935 .00935
25 Year Evergreen Exp. .00935 .00935
(Small Customer) (6) .00935 .66230
Scheduled Overrun (2) .00935 .38185
Rate Schedule TF-2 (4) (5)
Reservation .00000 .37250
Volumetric .00935 .00935
Scheduled Daily Overrun .00935 .38185
Annual Overrun .00935 .38185
Rate Schedule TI-1 (2)
Volumetric (7) .00935 .38185
Rate Schedule TFL-1 (4) (5)
Reservation - -
Volumetric (2) - -
Scheduled Overrun (2) - -
Rate Schedule TIL-1 (2)
Volumetric - -

Exhibit No.4
Case No. INT-G-25-04
Intermountain Gas Company
Page 4 of 29
Northwest Pipeline LLC
FERC Gas Tariff Twenty Third Revised Sheet No.5B
Fifth Revised Volume No.1
STATEMENT OF RATES (Continued)
Effective Rates Applicable to
Rate Schedules TF-1, TF-2, TI-1, TFL-1 and TIL-1 (Continued)
Footnotes (Continued)
(3) To the extent Transporter discounts the Maximum Base Tariff Rate, such
discounts will be applied on a non-discriminatory basis, subject to the
policies of Order No. 497.
Shippers receiving service under these rate schedules are required to
furnish fuel reimbursement in-kind at the rates specified on Sheet No.
14.
An incremental facilities charge or other payment method provided for
in Section 21 or 29 of the General Terms and Conditions, is payable in
addition to all other rates and charges if such a charge is included in
Exhibit C to a Shipper's Transportation Service Agreement.
In addition to the rates set forth on Sheet No. 5, Puget Sound Energy,
Inc.'s Transportation Service Agreement Nos. 140053 and 143077 are
subject to an annual incremental facility charge pursuant to Section 21
of the General Terms and Conditions. The effective annual incremental
facility charge for the South Seattle Delivery Lateral Expansion
Project is $1,855,387, and it is billed in equal monthly one-twelfth
increments with a daily incremental facility charge of $0.07955 per
Dth. The effective annual incremental facility charge for the North
Seattle Lateral Upgrade Project is $8,972,208, and it is billed in
equal monthly one-twelfth increments with a daily incremental facility
charge of $0.14225 per Dth.
In addition to the reservation rates shown on Sheet No. 5, Shippers who
contract for Columbia Gorge Expansion Project capacity are subject to a
facility reservation surcharge pursuant to Section 3.4 of Rate Schedule
TF-1. The facility charge used in deriving the Columbia Gorge Expansion
Project facility reservation surcharge has a minimum rate of $0 and a
maximum rate of $0.10646.
In addition to the reservation rates shown on Sheet No. 5, Shippers who
contract service under Rate Schedules TF-1 (Large Customer) , TF-1 25-
Year Evergreen, and TF-2 are subject to a Modernization and Emissions
Program Cost Recovery Mechanism (CRM) Surcharge pursuant to Section 30
of this Tariff. CRM Surcharge is currently $0.02256.

Exhibit No.4
Case No. INT-G-25-04
Intermountain Gas Company
Page 5 of 29
Document Accession #: 20221130-5273 Filed Date: 11/30/2022
Northwest Pipeline LLC
FERC Gas Tariff Tenth Revised Sheet No.7
Fifth Revised Volume No.1 Superseding
Ninth Revised Sheet No.7
STATEMENT OF RATES (Continued)
Effective Rates Applicable to Rate Schedules SGS-2F and SGS-2I
(Dollars per Dth)
Base
Rate Schedule and Tariff Rate (1)
Type of Rate Minimum Maximum
Rate Schedule SGS-2F (2) (3) (4) (5)
Demand Charge
Pre-Expansion Shipper 0.00000 0.02220
Expansion Shipper 0.00000 0.03393
Capacity Demand Charge
Pre-Expansion Shipper 0.00000 0.00081
Expansion Shipper 0.00000 0.00291
Volumetric Bid Rates
Withdrawal Charge
Pre-Expansion Shipper 0.00000 0.02220
Expansion Shipper 0.00000 0.03393
Storage Charge
Pre-Expansion Shipper 0.00000 0.00081
Expansion Shipper 0.00000 0.00291
Rate Schedule SGS-2I
Volumetric 0.00000 0.00240
Footnotes
(1) Shippers receiving service under these rate schedules are required to
furnish fuel reimbursement in-kind at the rates specified on Sheet
No. 14.

Exhibit No.4
Case No. INT-G-25-04
Intermountain Gas Company
Page 6 of 29
Document Accession #: 20221130-5273 Filed Date: 11/30/2022
Northwest Pipeline LLC
FERC Gas Tariff Tenth Revised Sheet No.8-A
Fifth Revised Volume No.1 Superseding
Ninth Revised Sheet No.8-A
STATEMENT OF RATES (Continued)
Effective Rates Applicable to Rate Schedules LS-2F and LS-2I
(Dollars per Dth)
Base
Rate Schedule and Tariff Rate (1)
Type of Rate Minimum Maximum
Rate Schedule LS-2F (3)
Demand Charge (2) 0.00000 0.03136
Capacity Demand Charge (2) 0.00000 0.00401
Volumetric Bid Rates
Vaporization Demand-Related Charge (2) 0.00000 0.03136
Storage Capacity Charge (2) 0.00000 0.00401
Liquefaction 0.58646 0.58646
Vaporization 0.07272 0.07272
Rate Schedule LS-2I
Volumetric 0.00000 0.00802
Liquefaction 0.58646 0.58646
Vaporization 0.07272 0.07272
Footnotes
(1) Shippers receiving service under these rate schedules are required to
furnish fuel reimbursement in-kind at the rates specified on Sheet No.
14.
(2) Rates are daily rates computed on the basis of 365 days per year.
(3) Rates are also applicable to capacity release service except for short-
term capacity release transactions for a term of one year or less that
take effect on or before one year from the date on which Transporter is
notified of the release, which are not subject to the stated Maximum
Base Tariff Rate. (Section 22 of the General Terms and Conditions
describes how bids for capacity release will be evaluated.) The
Vaporization Demand-Related Charge and Storage Capacity Charge are
applicable to Replacement Shippers bidding for capacity released on a
one-part volumetric bid basis.

Exhibit No.4
Case No. INT-G-25-04
Intermountain Gas Company
Page 7 of 29
FEDERAL ENERGY REGULATORY COMMISSION
WASHINGTON,DC 20426
OFFICE OF ENERGY MARKET REGULATION
Northwest Pipeline LLC
Docket No. RP25-647-000
Issued: March 20, 2025
On February 28, 2025,Northwest Pipeline LLC filed tariff records'to reflect
adjustments to its fuel reimbursement factors. Pursuant to authority delegated to the
Director,Division of Pipeline Regulation,under 18 C.F.R. § 375.307,the tariff records
are accepted, effective April 1, 2025,as requested.
The filing was publicly noticed. No protests or adverse comments were filed.
Pursuant to Rule 214 of the Commission's regulations (18 C.F.R. § 385.214),notices of
intervention,timely-filed motions to intervene, and any unopposed motions to intervene
out-of-time filed before the issuance date of this order are granted.
This action shall not be construed as a waiver of the requirements of section 7 of
the Natural Gas Act, as amended;nor shall it be 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 the applicant's tariff;nor shall such acceptance
be deemed as recognition of any claimed contractual right or obligation associated
therewith; and such acceptance is without prejudice to any findings or orders which have
been or may hereafter be made by the Commission in any proceeding now pending or
hereafter instituted by or against the applicant.
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. § 385.713.
Issued by: Marsha K. Palazzi,Director,Division of Pipeline Regulation
'Northwest Pipeline LLC,Fifth Revised Volume No. 1; Sheet No. 14,Fuel Use
Factors (36.0.0).

Exhibit No.4
Case No. INT-G-25-04
Intermountain Gas Company
Page 8 of 29
Northwest Pipeline LLC
FERC Gas Tariff Thirty Sixth Revised Sheet No.14
Fifth Revised Volume No.1
STATEMENT OF FUEL USE REQUIREMENTS FACTORS
FOR REIMBURSEMENT OF FUEL USE
Applicable to Transportation Service Rendered Under
Rate Schedules Contained in this Tariff, Fifth Revised Volume No. 1
The rates set forth on Sheet Nos. 5, 6, 7, 8 and 8-A are exclusive of
fuel use requirements. Shipper shall reimburse Transporter in-kind for its
fuel 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 follows
for the applicable Rate Schedules included in this Tariff:
Rate Schedules TF-1, TF-2, TI-1, and DEX-1 1.39%
Rate Schedule TF-1 - Evergreen Expansion
Incremental Surcharge (1) 0.50%
Rate Schedule TFL-1 -
Rate Schedule TIL-1 -
Rate Schedules SGS-2F and SGS-2I 0.39%
Rate Schedules LS-2F, LS-3F and LS-2I
Liquefaction 1.31%
Vaporization 1.56%
Rate Schedule LD-4I
Liquefaction 1.31%
The fuel use factors set forth above shall be calculated and adjusted
as explained in Section 14 of the General Terms and Conditions. Fuel
reimbursement quantities to be supplied by Shippers to Transporter shall be
determined by applying the factors set forth above to the quantity of gas
nominated for receipt by Transporter from Shipper for transportation,
Jackson Prairie injection, Plymouth liquefaction, Plymouth vaporization, or
for deferred exchange, as applicable.
Footnote
(1) In addition to the Rate Schedule TF-1 fuel use requirements factor, the
Evergreen Expansion Incremental Surcharge will apply to the quantity of gas
nominated for receipt at the Sumas, SIPI or Pacific Pool receipt points under
Evergreen Expansion service agreements.

Exhibit No.4
Case No. INT-G-25-04
Intermountain Gas Company
Page 9 of 29
NOVA GAS TRANSMISSION LTD.
(4 pages)

Exhibit No.4
Case No. INT-G-25-04
Intermountain Gas Company
Page 10 of 29
Canada Energy Regie de 1'6nergie
Regulator du Canada
ORDER TG-003-2025
IN THE MATTER OF the Canadian Energy Regulator
Act(CER Act); and
IN THE MATTER OF an application filed by NGTL GP
Ltd. (NGTL GP), as general partner on behalf of NGTL
Limited Partnership with the Canada Energy Regulator
(CER) pursuant to section 226 and paragraph 229(1)(b)
of the CER Act under File 6411511.
BEFORE the Commission of the CER on 27 May 2025.
WHEREAS on 29 May 2014,the National Energy Board (NEB)issued the MH-001-2013
Decision, approving NOVA Gas Transmission Ltd. 's(NGTL)methodology for calculating
abandonment surcharges;
AND WHEREAS on 25 March 2020,the Commission issued Order TG-001-2020, approving
NGTL's rate design (Rate Design);
AND WHEREAS on 16 February 2024 the Commission issued Order MO-002-2024,
granting leave for NGTL to transfer, and NGTL GP to acquire, all of the facilities that
comprise the NGTL System;
AND WHEREAS on 27 March 2024,the Commission approved NGTL's Abandonment Cost
Estimate of$5,203,697,226(2023 dollars);
AND WHEREAS on 14 May 2024,the Commission issued amending orders to change the
name of the holder of relevant certificates of public convenience and necessity and orders,to
reflect the change in ownership of the NGTL System facilities from NGTL to NGTL GP;
AND WHEREAS on 26 September 2024,the Commission issued Order TG-006-2024,
approving NGTL GP's 2025-2029 Revenue Requirement Settlement(Settlement);
AND WHEREAS on 10 December 2024,the Commission issued Order TGI-003-2024,
approving NGTL GP's interim tolls and abandonment surcharges effective 1 January 2025;
AND WHEREAS on 25 April 2025, NGTL GP filed an application (Application)requesting
an order approving final 2025 rates,tolls and charges for services on the NGTL System,for
the period 1 January 2025 to 31 May 2025, at the level previously approved by the
Commission as interim rates effective 1 January 2025 through Order TGI-003-2024, and final
2025 rates,tolls and charges for services on the NGTL System for the period 1 June 2025 to
31 December 2025 at the level contained in Attachment G to the Application effective
1 June 2025, (collectively, Final 2025 Tolls)and final 2025 abandonment surcharges
(Final 2025 Abandonment Surcharges);
/2

Exhibit No.4
Case No. INT-G-25-04
Intermountain Gas Company
Page 11 of 29
-2-
AND WHEREAS the Commission is satisfied with the consultation conducted and is not
aware of any outstanding concerns with the Application from shippers and participants of
NGTL GP's Tolls,Tariffs, Facilities and Procedures Committee or other interested parties;
AND WHEREAS the Commission finds the Final 2025 Tolls are just, reasonable and not
unjustly discriminatory and have been calculated in accordance with the Settlement and Rate
Design, and the Final 2025 Abandonment Surcharges have been calculated in accordance
with the NEB MH-001-2013 Decision and the Commission 27 March 2024 Decision
respecting abandonment costs and surcharges;
IT IS ORDERED pursuant to section 226 and paragraph 229(1)(b)of the CER Act that:
1. The interim tolls approved via Order TGI-003-2024 are approved as final for the
period 1 January 2025 to 31 May 2025;
2. The proposed tolls, as contained in Attachment G to the Application, are approved as
final for the period 1 June 2025 to 31 December 2025;
3. The interim abandonment surcharges approved via Order TGI-003-2024, and as
contained in Attachment H to the Application, are approved as final for the period
1 January 2025 to 31 December 2025.
THE COMMISSION OF THE CANADA ENERGY REGULATOR
Signed by
Ramona Sladic
Secretary of the Commission
TG-003-2025

Exhibit No.4
Case No. INT-G-25-04
Intermountain Gas Company
Page 12 of 29
NGTL GP Ltd. Attachment 2
Delivery Point Rates
Page 1 of 10
Final June-December 2025 Rates
NGTL SYSTEM DELIVERY POINT RATES
Group 1
Delivery FT-D Demand Rate ry Rate
IT-D Group 1 Delivery Point Name Price Point"Z" ($/GJ/
Number ($/GJ/mo)
2000 ALBERTA-B.C.BORDER 7.51 0.2716
31111 ALLIANCE CLAIRMONT INTERCONNECT APN 6.84 0.2474
31110 ALLIANCE EDSON INTERCONNECT APN 6.84 0.2474
31112 ALLIANCE SHELL CREEK INTERCONNECT APGC 6.84 0.2474
1958 EMPRESS BORDER 6.84 0.2474
3886 GORDONDALE BORDER 6.84 0.2474
6404 MCNEILL BORDER 6.84 0.2474
3826 WILLOW VALLEY INTERCONNECT 6.84 0.2474
Group 2 Subject to
Delivery FT-D Demand Rate IT-D Rate ATCO
Point Group 2 Delivery Point Name Price Point..Z" Pipelines
($/GJ/mo) ($/GJ/d) Franchise
Number
Fees'
31000 A.T.PLASTICS SALES APN 9.70 0.3508 Yes
32799 ACHESON B SALES APN 9.70 0.3508
31001 ADM AGRI INDUSTRIES SALES APN 9.70 0.3508 Yes
3880 AECOINTERCONNECTION 9.70 0.3508
31003 AGRIUM CARSELAND SALES APS 9.70 0.3508
31002 AGRIUM FT.SASK SALES APN 9.70 0.3508 Yes
31004 AGRIUM REDWATER SALES APN 9.70 0.3508
31005 AINSWORTH SALES APGP 9.70 0.3508
31006 AIR LIQUIDE SALES APN 9.70 0.3508
6126 AITKEN CREEK SOUTH SALES 2 12.12 0.4303
3820 AITKEN CREEK INTERCONNECT 2 12.12 0.4303
3214 AKUINU RIVER WEST SALES 9.70 0.3508
31007 ALBERTA ENVIROFUELS SALES APN 9.70 0.3508 Yes s
31008 ALBERTA HOSPITAL SALES APN 9.70 0.3508 Yes
3868 ALBERTA-MONTANA BORDER 9.70 0.3508
3297 ALDER FLATS SOUTH NO 2 SALES 9.70 0.3508
3059 ALLISON CREEK SALES 9.70 0.3508
6132 ALTARES SALES 2 12.12 0.4303
6133 ALTARES SOUTH SALES 2 12.12 0.4303
31009 ALTASTEEL SALES APN 9.70 0.3508 Yes s
6145 ANDERSON LAKE SALES 9.70 0.3508
31012 APL JASPER SALES APN 9.70 0.3508 Yes
3488 ARDLEY SALES 9.70 0.3508
3237 ASPEN SALES 9.70 0.3508
3662 ATUSIS CREEK EAST SALES 9.70 0.3508
3216 AURORA NO 2 SALES 9.70 0.3508
3135 AURORA SALES 9.70 0.3508
3288 BANTRY SALES 9.70 0.3508
3423 BASHAW WEST SALES 9.70 0.3508
6158 BASSET LAKE WEST SALES 9.70 0.3508
31013 BAYMAG SALES APS 9.70 0.3508
6112 BAY TREE SALES 9.70 0.3508
31014 BEAR CREEK COGEN SALES APGP 9.70 0.3508
Order:TG-003-2025 Effective:June 1,2025

Exhibit No.4
Case No. INT-G-25-04
Intermountain Gas Company
Page 13 of 29
NGTL GP Ltd.,as general partner on behalf of
NGTL Limited Partnership Table of Rates,Tolls and Charges
Page 1 of 1
Final June-December 2025 Rates
TABLE OF RATES,TOLLS AND CHARGES
Service Rates,Tolls and Charges
Refer to Attachment I"for applicable FT-R Demand Rate per month based on a three-year term(Price Point"B")&Surcharge for each Receipt
1. Rate Schedule FT-R Point
Average Firm Service Receipt Price(AFSRP) $340.45/103m3/month
2. Rate Schedule FT-RN Refer to Attachment"1"for applicable FT-RN Demand Rate per month&Surcharge for each Receipt Point
Refer to Attachment"2"for applicable FT-D Demand Rate per month based on a one-year term(Price Point"Z")&Surcharge for each Group 1 or
Group 2 Delivery Point
3. Rate Schedule FT-D' Average FT-D Demand Rate for Group 1 Delivery Points $7.08/GJ/month
FT-D Demand Rate for Group 2 Delivery Points $9.70/GJ/month
FT-D Demand Rate for Group 3 Delivery Points $11.64/GJ/month
4. Rate Schedule STFT STFT Bid Price=Minimum of 100%of the applicable FT-D Demand Rate based on a one-year term(Price Point"Z")for each Group 1 Delivery
Point
FT-DW Bid Price=Minimum of 125%of the applicable FT-D Demand Rate based on a three-year term(Price Point"Y")for each Group 1 Delivery
5. Rate Schedule FT-DW Point
6. Rate Schedule FT-P' Refer to Attachment"3"for applicable FT-P Demand Rate per month
7. Rate Schedule FT-LE Refer to Attachment"4"for applicable FT-LE Demand Rate per day and per month
8. Rate Schedule IT-R Refer to Attachment I"for applicable IT-R Rate for each Receipt Point
9. Rate Schedule IT-D' Refer to Attachment"2"for applicable IT-D Rate for each Delivery Point
10. Rate Schedule FCS The FCS Charge is determined in accordance with Attachment"1"to the applicable Schedule of Service
11. Rate Schedule PT Schedule No. PT Rate PT Gas Rate
9025-010116 $1,303/day 2.9/103m3/day
9025-010115 $12,869/day 10.9/103m3/day
9025-010114 $3,003/day 5.8/103m3/day
9025-010117 $1,943/day 3.6/103m3/day
9025-010118 $3,845/day 10.8/103m3/day
9025-010119 $4,860/day 14.4/103m3/day
12.Rate Schedule OS Schedule No. Charge
2024457257 $150462/103m3/month
2003004522 Applicable IT-D Rate on Over-Run
2011476052/ $0.3188/GJ subject to
2011476054 $717,000 Minimum Annual Charge
2017887638/2011476092 $0.095/GJ and
2016721799/2016759254 $1,000/month
2021735873 120193055731 $8.73/GJ/month and
2024335033 Applicable IT-D Rate on Over-Run
13. Rate Schedule COz Tier 1 2 3
COz Rate(/1030) $622.05 $492.16 $319.28
14.Monthly Abandonment Surcharge z $14.33/103m3/month $0.38/GJ/month
15. Daily Abandonment Surcharge 3 $0.47/103m3/day $0.0125/GJ/day
16. Federal Fuel Charge° Marketable Natural Gas 5 $0.0000/m3
1.Service under Rate Schedules FT-D,FT-P and IT-D for delivery stations identified in Attachment 2,and Rate Schedule OS No.2017887638,2011476092,2016721799,and
2016759254 are subject to the ATCO Pipelines Franchise Fees pursuant to paragraph 15.13 of the General Terms and Conditions.
2.Monthly Abandonment Surcharge applicable to Rate Schedules FT-R,FT-D,FT-P,FT-LE,FT-RN,FT-DW,and STFT,and the following
Schedules OS:2024457257,2021735873,2019305573,2024335033.
3.Daily Abandonment Surcharge applicable to Rate Schedules IT-R,IT-D,the following Rate Schedules OS:2003004522,2011476052,2011476054,
2017887638,2011476092,2016721799,2016759254,and if applicable Over-Run Gas.
4.Collected on all deliveries of gas within Alberta pursuant to any Rate Schedule unless NGTL has received a valid exemption certificate
pursuant to the Greenhouse Gas Pollution Pricing Act.
5.See FCN12 Canada Revenue Agency Administrative Position regarding Marketable Natural Gas under Part 1 of the Greenhouse Gas Pollution Pricing Act.
Order:TG-003-2025 Effective:June 1,2025

Exhibit No.4
Case No. INT-G-25-04
Intermountain Gas Company
Page 14 of 29
FOOTHILLS PIPE LINES LTD.
(3 pages)

Exhibit No.4
Case No. INT-G-25-04
Intermountain Gas Company
Page 15 of 29
C( TCEnergy
450—1 Street SW
Calgary,Alberta T2P 5H1
Tel:[phone]
Fax:[phone]
Email:[e-mail]
November 8,2024
Canada Energy Regulator Filed Electronically
Suite 210, 517 Tenth Avenue SW
Calgary,Alberta T2R OA8
Attention:Ramona Sladic,Secretary of the Commission
Dear Ramona Sladic:
Re: Foothills Pipe Lines Ltd.(Foothills)
Statement of Rates and Charges effective January 1,2025
Foothills encloses for filing with the Commission pursuant to section 229(1)(a)of the Canadian
Energy Regulator Act rates and charges for transportation service on Foothills Zones 6,7, 8 and
9 to be effective January 1,2025 (Effective 2025 Rates).
The following attachments are included with this letter:
• Attachment 1 consists of supporting Schedules A through G
• Attachments 2 and 3 are black-lined and clean copies,respectively,of the Table of
Effective Rates for 2025
The rates and charges are based on the methodology approved in Order TG-8-2004,as amended
by Order TG-03-2007.
The filing also includes the Foothills Abandonment Surcharges effective January 1,2025,which
are included in the Table of Effective Rates for 2025.The supporting information on the
Abandonment Surcharge calculations are provided in the attached Schedule G.
Foothills met with customers and interested parties on October 29,2024 and presented the
preliminary 2025 revenue requirement,preliminary Effective 2025 Rates and preliminary
Abandonment Surcharges.Based on this consultation,Foothills is not aware of any objections to
its proposal for establishing the Effective 2025 Rates.
Foothills understands that any party that is opposed to the rates and charges will advise the
Commission accordingly.
Foothills will notify its customers and interested parties of this filing and post a copy of it on
TC Energy's Foothills System website at:http://www.tccustomerexpress.com/934.html

Exhibit No.4
Case No. INT-G-25-04
Intermountain Gas Company
Page 16 of 29
November 8,2024
Ramona Sladic
Page 2 of 2
Communication regarding this filing should be directed to:
Martin Gonzalez Ashley Mitchell
Regulatory Project Manager Senior Legal Counsel
Tolls and Tariffs,Canadian Natural Gas Pipelines Canadian Law,Natural Gas Pipelines
Foothills Pipe Lines Ltd. Foothills Pipe Lines Ltd.
450— 1 Street SW 450— 1 Street SW
Calgary,Alberta T2P 51-11 Calgary,Alberta T2P 51-11
Telephone: [phone] Telephone: [phone]
Facsimile: [phone] Facsimile: [phone]
Email:[e-mail] Email: [e-mail]
Yours truly,
Foothills Pipe Lines Ltd.
Original signed by
Roman Karski
Manager,Regulatory Tolls and Tariffs
Canadian Natural Gas Pipelines
Attachments
cc: Foothills Firm Customers
Interruptible Customers and Interested Parties

Exhibit No.4
Case No. INT-G-25-04
Intermountain Gas Company
Page 17 of 29
Foothills Pipe Lines Ltd. Page 1
TABLE OF EFFECTIVE RATES
1. Rate Schedule FT,Firm Transportation Service
Demand Rate
($/GJ/Km/Month)
Zone 6 0.0051793540
Zone 7 0.0017479490
Zone 8* 0.0238303058
Zone 9 0.0190635827
2. Rate Schedule OT,Overrun Transportation Service
Commodity Rate
($/GJ/Km)
Zone 6 0.0001873081
Zone 7 0.0000632135
3. Rate Schedule IT,Interruptible Transportation Service
Commodity Rate
($/GJ/Km)
Zone 8 0.0008618083
Zone 9 0.0006894227
4. Monthly Abandonment Surcharge**
All Zones 0.1162843 612($/GJ/Month)
5. Daily Abandonment Surcharge***
All Zones 0.0038230475 ($/GJ/Day)
*For Zone 8,Customers Haul Distance shall be 170.7 km.
**Monthly Abandonment Surcharge applicable to Rate Schedule Firm Transportation Service,and Short Tenn Finn
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:January 1,2025

Exhibit No.4
Case No. INT-G-25-04
Intermountain Gas Company
Page 18 of 29
GAS TRANSMISSION NORTHWEST LLC
(6 pages)

Exhibit No.4
Case No. INT-G-25-04
Intermountain Gas Company
Page 19 of 29
FEDERAL ENERGY REGULATORY COMMISSION
WASHINGTON,DC 20426
OFFICE OF ENERGY MARKET REGULATION
Gas Transmission Northwest LLC
Docket No. RP23-1099-005
Issued: December 12, 2024
On November 21,2024,Gas Transmission Northwest LLC (GTN)filed tariff
records' in compliance with the Commission's order in Docket Nos. RP23-1099-000 and
RP23-1099-004,2 which approved a stipulation and agreement of settlement(Settlement).
GTN states that the purpose of this filing is to place its Phase I Settlement rates into
effect as set forth in Article VI of the Settlement. Pursuant to authority delegated to the
Director,Division of Pipeline Regulation,under 18 C.F.R. § 375.307,the tariff records
are accepted, effective April 1,2024, as requested.
The filing was publicly noticed. No protests or adverse comments were filed.
Pursuant to Rule 214 of the Commission's regulations (18 C.F.R. § 385.214),notices of
intervention,timely-filed motions to intervene, and any unopposed motions to intervene
out-of-time filed before the issuance date of this order are granted.
This action shall not be construed as a waiver of the requirements of section 7 of
the Natural Gas Act, as amended; nor shall it be 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 the applicant's tariff;nor shall such acceptance
be deemed as recognition of any claimed contractual right or obligation associated
therewith; and such acceptance is without prejudice to any findings or orders which have
been or may hereafter be made by the Commission in any proceeding now pending or
hereafter instituted by or against the applicant.
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. § 385.713.
Issued by: Marsha K. Palazzi,Director,Division of Pipeline Regulation
'See Appendix.
2 Gas Transmission Nw. LLC, 189 FERC¶61,055 (2024).

Exhibit No.4
Case No. INT-G-25-04
Intermountain Gas Company
Page 20 of 29
Gas Transmission Northwest LLC PART 4.1
FERC Gas Tariff 4.1 -Statement of Rates
Fourth Revised Volume No. 1-A FTS-1,LFS-1,and FHS Rates
v.22.0.0 Superseding v.21.0.1
STATEMENT OF EFFECTIVE RATES AND CHARGES FOR
TRANSPORTATION OF NATURAL GAS
Rate Schedules FTS-1,LFS-1,and FHS
For Rate Schedules FTS-1 and LFS-1:
RESERVATION
DAILY DAILY
MILEAGE(a) NON-MILEAGE(b) DELIVERY(c)
(Dth-Mile) (Dth) (Dth-Mile)
Max. Min. Max. Min. Max. Min
BASE 0.0003620 0.0000000 0.0286120 0.0000000 0.0000160 0.0000160
STF(e) (e) 0.0000000 (e) 0.0000000 0.0000160 0.0000160
EXTENSION CHARGES
MEDFORD
E-1 (fl 0.0025110 0.0000000 0.0042230 0.0000000 0.0000260 0.0000260
E-2(h) 0.0029720 0.0000000 --- --- 0.0000000 0.0000000
(Diamond 1)
E-2(h) 0.0011660 0.0000000 --- --- 0.0000000 0.0000000
(Diamond 2)
COYOTE SPRINGS
E-3(i) 0.0011670 0.0000000 0.0011680 0.0000000 0.0000000 0.0000000
CARTY LATERAL
E-4(p) --- --- 0.1514920 0.0000000 0.000000 0.0000000
OVERRUN CHARGE 0)
--- --- --- --- --- ---
Issued: November 21,2024 Docket No.RP23-1099-005
Effective: April 1,2024 Accepted: December 12,2024

Exhibit No.4
Case No. INT-G-25-04
Intermountain Gas Company
Page 21 of 29
FEDERAL ENERGY REGULATORY COMMISSION
WASHINGTON,DC 20426
OFFICE OF ENERGY MARKET REGULATION
Gas Transmission Northwest LLC
Docket No. RP23-1099-006
Issued: December 12, 2024
On November 21,2024,Gas Transmission Northwest LLC (GTN)filed tariff
records' in compliance with the Commission's order in Docket Nos. RP23-1099-000 and
RP23-1099-004,2 which approved a stipulation and agreement of settlement(Settlement).
GTN states that the purpose of this filing is to implement the tariff provisions as set forth
in Appendix B-3 of the Settlement. Pursuant to authority delegated to the Director,
Division of Pipeline Regulation,under 18 C.F.R. § 375.307,the tariff records are
accepted, effective November 21,2024, as requested.
The filing was publicly noticed. No protests or adverse comments were filed.
Pursuant to Rule 214 of the Commission's regulations (18 C.F.R. § 385.214),notices of
intervention,timely-filed motions to intervene, and any unopposed motions to intervene
out-of-time filed before the issuance date of this order are granted.
This action shall not be construed as a waiver of the requirements of section 7 of
the Natural Gas Act, as amended; nor shall it be 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 the applicant's tariff, nor shall such acceptance
be deemed as recognition of any claimed contractual right or obligation associated
therewith; and such acceptance is without prejudice to any findings or orders which have
been or may hereafter be made by the Commission in any proceeding now pending or
hereafter instituted by or against the applicant.
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. § 385.713.
Issued by: Marsha K. Palazzi,Director,Division of Pipeline Regulation
'See Appendix.
2 Gas Transmission Nw. LLC, 189 FERC¶61,055 (2024).

Exhibit No.4
Case No. INT-G-25-04
Intermountain Gas Company
Page 22 of 29
Gas Transmission Northwest LLC PART 4.6
FERC Gas Tariff 4.6-Statement of Rates
Fourth Revised Volume No. 1-A Negotiated Rate Agreements-FTS-1 and LFS-1
v.16.0.0 Superseding v.15.0.0
NRG Business 06/01/24 FTS-1 5,000 Kingsgate Malin /14
Marketing LLC/1 06/30/24
NRG Business 06/01/24 FTS-1 5,000 Kingsgate Malin 115
Marketing LLC/1 06/30/24
Tourmaline Oil 07/17/24 FTS-1 17,000 Kingsgate Malin /16
Marketing Corp./1 Full in-service
of GTNXP
Intermountain Gas 07/17/24 FTS-1 26,333 Kingsgate Malin /16
Company/1 Full in-service
of GTNXP
Cascade Natural 07/17/24 FTS-1 6,667 Kingsgate Malin /16
Gas Corporation/1 Full in-service
of GTNXP
Cascade Natural 12/13/24 FTS-1 20,000 Kingsgate Malin /17
Gas Corporation 1/12/56
Intermountain Gas 12/13/24 FTS-1 79,000 Kingsgate Malin /17
Company 1/12/55
Tourmaline Oil 12/13/24 FTS-1 51,000 Kingsgate Malin /17
Marketing Corp. 12/12/57
Issued: November 13,2024 Docket No.RP25-182-000
Effective: December 13,2024 Accepted: December 4,2024

Exhibit No.4
Case No. INT-G-25-04
Intermountain Gas Company
Page 23 of 29
Gas Transmission Northwest LLC PART 4.7
FERC Gas Tariff 4.7-Statement of Rates
Fourth Revised Volume No. 1-A Footnotes for Negotiated Rates-FTS-1 and LFS-1
v.16.0.0 Superseding v.15.0.0
b.Effective the earlier of January 1,2022, or the termination of the Amended Settlement in
Docket No. RP15-904-001, the negotiated rate for all quantities on the Kingsgate to Malin
path shall be a fixed Reservation Charge of$0.2600 along with applicable surcharges.
Al a. Effective November 1, 2019 continuing until December 31, 2021, GTN and Shipper
have agreed to a fixed reservation charge of$0.2375 along with applicable surcharges for
all quantities on the Kingsgate to Malin path.
b.Effective the earlier of January 1,2022, or the termination of the Amended Settlement in
Docket No. RP15-904-001, the negotiated rate for all quantities on the Kingsgate to Malin
path shall be a fixed Reservation Charge of$0.2500 along with applicable surcharges.
/12 a. Effective November 1, 2020 continuing until December 31, 2021, GTN and Shipper
have agreed to a fixed reservation charge of$0.2375 along with applicable surcharges for
all quantities on the Kingsgate to Malin path.
b. Effective January 1, 2022 and continuing until May 31. 2035, the negotiated rate for all
quantities on the Kingsgate to Malin path shall be a fixed Reservation Charge of$0.2500
along with applicable surcharges.
/13 Effective March 17, 2023 and continuing until March 16, 2057, GTN and Shipper have
agreed to a fixed reservation charge of$0.2800 along with applicable surcharges for all
quantities on the Kingsgate to Malin path.
/14 Effective June 1, 2024 and continuing until June 30, 2024, GTN and Shipper have agreed
to a fixed reservation charge of$0.35000 along with applicable surcharges for all quantities
on the Kingsgate to Malin path.
115 Effective June 1, 2024 and continuing until June 30, 2024, GTN and Shipper have agreed
to a fixed reservation charge of$0.40000 along with applicable surcharges for all quantities
on the Kingsgate to Malin path.
/16 Effective July 17,2024, GTN and Shipper have agreed that Shipper shall pay a Negotiated
Daily Demand Rate equal to $0.31 per dekatherm along with the maximum applicable
system commodity rate and all applicable maximum reservation and commodity
surcharges.
/17 Effective December 13, 2024. GTN and Shipper have agreed that Shipper shall pay a
Negotiated Demand Rate equal to$0.31 per dekatherm along with the maximum applicable
system commodity rate and all applicable maximum reservation and commodity
surcharges.
/18 Reserved
Issued: November 13,2024 Docket No.RP25-182-000
Effective: December 13,2024 Accepted: December 4,2024

Exhibit No.4
Case No. INT-G-25-04
Intermountain Gas Company
Page 24 of 29
Location DRN Mlle Poet
Kingsgate 3498 0.00
Moyie Springs 198186 22.06
Boners Ferry 3503 27.04
SeNietzer 159304 55.50
Sandpoint 3496 59.26
Dover Bay 634335 61.14
Sagle Sales 769368 65.22
Athol 160164 84.77
Rathdmm City 3539 97.64
Rathtlmm Gen Tap 160138 97.64
Lancaster 314085 99.78 whamom
TC PIPELINE
Chase Road Delivery 1389605 102.50 Con^ry INGSGATE BORDER MS
Spokane City 28203 108.29
Spokane Summary 28201 108.29 Pend
Mica 28204 121.15 Skagit Oreille Eastport 3
county Cnu°ty
Spangle 28205 134.18 Okanogan MOYI SP NOS MS
Rosalia 28245 145.71 Count, Ferry ONNER FE RYMS Q�
St.John 28246 158.89 county B a,y
Palouse smwons 217745 172.07 Sandpoint-4
Lacrosse 28247 182.79 omish Snohomish County SC EITZE IMS Lyons Ferry 21747 206.50 my county S NDPOIN MSS� r
county
Attalla 21750 252.71 D VERB MS-��
Kosmos Farm 159305 271.66 Chelan SAG SAL MSS L c
Stanfield 18503 277.37 canary unt
Stanfield City 18505 282.76 13ou91as iy ATHO era
Calpine H.P.P. 314578 282.88 n�, un
744 S DR coty RATH MC M Co ry
RA `
South Hermiston 217 289.83 n Athol`�
CSBRR 198185 304.22 LANCASTER P ER LLC-m
Co ore Springs 198184 304.23 County CHA E ROAD SPOKAN CITY MS
Coyote Springs 2 314579 304.24 SPOKAN
Coyote 5 217723 304.25 Kittitzs Grant ICA MS a ai SUMARY MS
Count n Mine
Carty 401645 319.66 Y C°°nty SPA GL m^ Rosalia 6 Canm
Carty Generating Station 1421748 319.70 SH NGTON Benewah Shoshone
ThreeMile Road Dairy D 21749 319.76 Atlama 1 ry y
ThreeMile Road Dairy R 21749 319.70 C°°°ty °'"� � ROSA(.1 coon coum
Madms 18430 410.16 cam SAINT JOIN SALES
Prineville 18432 426.80 NO THWEST 1 .
Redmond 18402 438.30 LACROSSE 4S Latah
EMS `OYmy
Pronghom Tap 360889 445.80 county Frank' /
North Send 233740 450.28 Cn NS FER I Clearwater
Bend 18403 454.51
AnnuA Starbuck 7 Ceunry
South Bend 217724 457.50 ez Peree
Steams 18404 469.19 COYOTE SPRINGS II MS Bent°n a walk commcia n,e a onn
QY IV M ty ry
Lapine 159307 483.90 C _TE S Coun °unry y Lewis
Gilchrist 18437 500.97 Klickitat COYOTE SPRINGS MS liec°°Wallula(8) co my
Chemult 1B440 519.44 KOSM °
ly
Halpold Sales 1402105 599.23 CARTY C� r STANFIELD MS
Kingsley Field Tap 473654 599.26 CARTY 1'rr0 1 m� STANFIELD Cl
Klamath COGen 1 288499 599.27 GENER?TING STATION CA14INE MS
West Klamath Tap 198183 599.28 THREEMILEl) ✓ SOUTH MISTO MS l4aha
Klamath Expansion 311972 ROAD DAIRY RID C RR MS 599.29 Umatilla county
Phoe ix Medford 198182 599.30 Scanrr n Gill lone(9) County c° y
Tu u se Flats 1049174 609.80 y
Morrow
Tuscarom/GTN Interconnect 190094 609.80 Coacnty ■ coonry Unlnry
Malln 1820 612.46 Kent-(10)
my
Benton
CountyLimn Jefferson-my MADRAS S wheeler Atlama
County �� County county
Madras(11) ker
Qeammea ;'�RINEVILL Grant
ID HO
C-my
PRON'HORN MS REDMOND MS Conn" l Washington county
ane L Z N RTH BEND MS county
BEND MS
C°nnry
ST AFINS MS ��SO END MS Crook
`m coonry
Bend(12) P'ye11e
County Gam
PINE MS OREGON `-ty
Connry
GILC RIST MS
Douglas eanyo
coonry CHEMUL7 coonry
Chemult(13)
II can
H D SALE Y Elm
WEST KLAMAT Carney Malheur IIII ^ry
County county I
TAP
KLAMA H coonry
I
EXPANSION S
KLAMATH CC GE .MS I
Jac �
Owvhe.
m Bonanza(14) i count N
--T0146SLEYm3, TUSCAR RAMS
TURQUOISE FLATS RUBY PIPELINE
MALIN M8 � i
Siskl ,PHOENIX/MEDFORD I ------__
ro
Co-, i TIC Energy
PACIFIC GAS&
ELECTRIC PIPELINE County NEVADA
GAS TRANSMISSION NORTHWEST LLC
T CARORAPIPEL E SYSTEM MAP
i.my umbr
°nnty washes ca MARCH 31,2021
T,inity CALIFORNIA
coonry Shasta m Meter Station 0 20 40 80
coonry Lassen
coonry Compressor Station Scale in Miles
■
GTN

Exhibit No.4
Case No. INT-G-25-04
Intermountain Gas Company
Page 25 of 29
MOUNTAINWEST PIPELINE, LLC
(2 pages)

Exhibit No.4
Case No. INT-G-25-04
Intermountain Gas Company
Page 26 of 29
FEDERAL ENERGY REGULATORY COMMISSION
WASHINGTON,DC 20426
OFFICE OF ENERGY MARKET REGULATION
MountainWest Pipeline,LLC
Docket No. RP25-219-000
Issued: December 11,2024
On November 26,2024,MountainWest Pipeline,LLC filed a revised tariff record'
to reflect a decrease in the Fuel Gas Reimbursement Percentage from 1.04%to 0.75%.
Pursuant to authority delegated to the Director,Division of Pipeline Regulation,under 18
C.F.R. § 375.307,the tariff record is accepted, effective January 1,2025, as requested.
The filing was publicly noticed. No protests or adverse comments were filed.
Pursuant to Rule 214 of the Commission's regulations (18 C.F.R. § 385.214),notices of
intervention,timely-filed motions to intervene, and any unopposed motions to intervene
out-of-time filed before the issuance date of this order are granted.
This action shall not be construed as a waiver of the requirements of section 7 of
the Natural Gas Act, as amended; nor shall it be 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 the applicant's tariff, nor shall such acceptance
be deemed as recognition of any claimed contractual right or obligation associated
therewith; and such acceptance is without prejudice to any findings or orders which have
been or may hereafter be made by the Commission in any proceeding now pending or
hereafter instituted by or against the applicant.
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. § 385.713.
Issued by: Marsha K. Palazzi,Director,Division of Pipeline Regulation
'MountainWest Pipeline,LLC, Tariffs, Statement of Rates, Statement of Rates(23.0.0).

Exhibit No.4
Case No. INT-G-25-04
Intermountain Gas Company
Page 27 of 29
Mountain West Pipeline, LLC
FERC Gas Tariff Statement of Rates
Second Revised Volume No. 1 Section Version: 23.0.0
STATEMENT OF RATES
Base
Rate Schedule/ Tariff
Type of Charge Rate($)
(a) (b)
PEAKING STORAGE
Firm Peaking Storage Service-PKS
Monthly Reservation Charge
Maximum4/................................................................................................................................2.87375
Minimum....................................................................................................................................0.00000
Usage Charge
Injection.....................................................................................................................................0.03872
Withdrawal .................................................................................................................................0.03872
CLAY BASIN STORAGE
Firm Storage Service- FSS
Monthly Reservation Charge
Deliverability
Maximum4/..............................................................................................................................2.85338
Minimum..................................................................................................................................0.00000
Capacity
Maximum..................................................................................................................................0.02378
Minimum..................................................................................................................................0.00000
Usage Charge
Injectionl/..................................................................................................................................0.01049
Withdrawal .................................................................................................................................0.01781
Authorized Overrun Charge.........................................................................................................................
Maximum l/.................................................................................................................................0.30315
Minimuml/.................................................................................................................................0.01781
Interruptible Storage Service-ISS
Usage Charge
Inventory 5/
Maximum..................................................................................................................................0.05927
Minimum..................................................................................................................................0.00000
Injectionl/..................................................................................................................................0.01049
Withdrawal .................................................................................................................................0.01781
OPTIONAL VOLUMETRIC RELEASES/
Peaking Storage Service-PKS
Maximum4/..................................................................................................................................3.40890
Minimum......................................................................................................................................0.00000
Firm Storage Service-FSS
Maximum4/..................................................................................................................................0.57068
Minimum......................................................................................................................................0.00000
Storage Usage Charges Applicable to Volumetric Releases 6/
PeakingStorage Service-PKS:.....................................................................................................................
Injection.......................................................................................................................................0.03872
Withdrawal ...................................................................................................................................0.03872
Clay Basin Storage Service-FSS:
Injectionl/....................................................................................................................................0.01049
Withdrawal ...................................................................................................................................0.01781
PARK AND LOAN SERVICE-PAL1
Daily Charge
Maximum.....................................................................................................................................0.30315
Minimum.....................................................................................................................................0.00000
DeliveryChargel/............................................................................................................................0.02830
FUEL REIMBURSEMENT-2.0%(0.2%utility and 1.8%compressor fuel)for Rate Schedule PALL
Filed On: November 26, 2024 Effective On: January 1, 2025

Exhibit No.4
Case No. INT-G-25-04
Intermountain Gas Company
Page 28 of 29
FEDERAL ENERGY REGULATORY COMMISSION
ANNUAL CHARGES UNIT CHARGE
(1 page)

Exhibit No.4
Case No. INT-G-25-04
Intermountain Gas Company
Page 29 of 29
FEDERAL ENERGY REGULATORY COMMISSION
WASIENGTON,D.C.20426
FY 2025 GAS ANNUAL CHARGES
CORRECTION FOR ANNUAL CHARGES UNIT CHARGE
June 20,2025
The annual charges unit charge(ACA)to be applied to in fiscal year 2026 for recovery of
FY 2025 Current year and 2024 True-Up is$0.0015 per Dekatherm(Dth).The new ACA
surcharge will become effective October 1,2025.
The following calculations were used to determine the FY 2025 unit charge:
2025 CURRENT:
Estimated Program Cost$102,359,600 divided by 70,170,407,634 = 0.0014587289
Dth
2024 TRUE-UP:
Debit/Credit Cost$21,103 divided by 67,960,232,349 Dth = 0.0000003105
TOTAL UNIT CHARGE = 0.0014590394
If you have any questions,please contact Raven A.Rodriguez at(202)502-6276 or e-mail
at [e-mail].
PUBLIC

EXHIBIT NOS. 5-11
CASE NO. INT-G-25-04
INTERMOUNTAIN GAS COMPANY
(7 pages)

DmH No.5
Case No. IN-25k
Intermountain EsCompany
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Exhibit No.6
Case No. INT-G-25-04
Intermountain Gas Company
Page 1 of 1
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Case No. INT-G-25-04
Intermountain Gas Company
Page 1 of 1
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Intermountain Gas Company
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Case No. INT-G-25-04
Intermountain Gas Company
Page 1 of 1
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Exhibit No. 10
Case No. INT-G-25-04
Intermountain Gas Company
Page 1 of 1
INTERMOUNTAIN GAS COMPANY
Proposed Temporary Surcharges(Credits)-Variable Costs
Line
No. Description Amount
(a) (b)
1 Variable Amounts Which Apply to RS,GS-1,and LV-1:
2 Account 1910 Variable Costs $ 5,140,012
3 Normalized Sales Volumes (1/1/24-12/31/24) 457,109,679
4 Proposed Temporary Surcharge(Credit)-Variable Costs $ 0.01124
5 Lost and Unaccounted For Gas Amounts Which Apply to RS and GS-1:
6 Lost and Unaccounted For Gas Amounts from INT-G-24-04(Account 1910.2120) $ (2,433,477)(2)
7 Lost and Unaccounted For Gas Amortization(Account 1910.2130) 2,317,249 (3)
8 (Over)/Under Collection of Lost and Unaccounted For Gas from INT-G-24-04 (116,228)
9 Lost and Unaccounted For Gas INT-G-25-04 (800,968)(4)
10 Total Lost and Unaccounted For Gas Amounts Which Apply to RS and GS-1 $ (917,196)
11 Normalized Sales Volumes (1/1/24-12/31/24) 441,865,847
12 Proposed Temporary Surcharge(Credit)-Lost and Unaccounted For Gas Costs $ (0.00208)
13 Lost and Unaccounted For Gas Amounts Which Apply to LV-1,T-3,and T-4:
14 Lost and Unaccounted For Gas Amounts from INT-G-24-04(Account 1910.2120) $ (820,247) 51
15 Lost and Unaccounted For Gas Amortization(Account 1910.2140) 814,067 lel
16 (Over)/Under Collection of Lost and Unaccounted For Gas from INT-G-24-04 (6,180)
17 Lost and Unaccounted For Gas INT-G-25-04 (270,441) '
18 Total Lost and Unaccounted For Gas Amounts Which Apply to LV-1,T-3,and T-4 $ (276,621)
19 Normalized Sales Volumes (1/1/24-12/31/24) 399,328,333
20 Proposed Temporary Surcharge(Credit)-Lost and Unaccounted For Gas Costs $ (0.00069)
21 Convert T-4 Lost and Unaccounted For Temporary from a Volumetric Rate to a Demand Rate:
22 Proposed Temporary Surcharge(Credit)-Lost and Unaccounted For Gas Costs(Line 20) $ (0.00069)
23 Normalized T-4 Sales Volumes(1/1/24-12/31/24) 345,702,053
24 Total Temporary Collected $ (238,534)
25 Billing Determinants Demand Volumes 18,372,360
26 Proposed Temporary Surcharge(Credit)-Lost and Unaccounted For T-4 Demand Rate(Line 24 Divided by Line 25) $ (0.01298)
(') 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)
(4) See Workpaper No.5,Page 2,Line 30,Column(d),plus Line 36,Column(e)
(5) See Workpaper No.5,Page 2,Line 3,Column(c)
(6) See Workpaper No.5,Page 2,Line 14,Column(d)
(7) See Workpaper No.5,Page 2,Line 31,Column(d),plus Line 40,Column(e)

Exhibit No. 11
Case No. INT-G-25-04
Intermountain Gas Company
Page 1 of 1
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NEWS RELEASE
and
CUSTOMER NOTICE
CASE NO. INT-G-25-04
INTERMOUNTAIN GAS COMPANY
(2 pages)

NEWS RELEASE
AINTERMOUNTAIN®
GAS COMPANY
A Subsidiary ofMUU Resources Group,Inc.
In the Community to Serve'
Most Intermountain Gas Company Customers to See Lower Natural Gas Prices
BOISE,IDAHO—August 7, 2025—Intermountain Gas Company filed its annual purchased gas cost adjustment
(PGA) application(Case No. INT-G-25-04)with the Idaho Public Utilities Commission. If approved,residential and
small commercial customers will see a price decrease,while large industrial customers will see an increase. In total,
Intermountain Gas is asking the PUC to approve an average increase of 0.10% or$303,638.
The PGA application is filed each year to ensure the costs Intermountain incurs on behalf of its customers are
reflected in its sales prices. If approved, the new rates would go into effect on Oct. 1, 2025.
A typical residential customer would see a monthly decrease of$0.12 or 0.28%. Commercial customers, on average,
would see a monthly decrease of$0.06 or 0.03%. Large volume and transport customers, on average,will see the
following monthly increases: LV-1 $649.24 or 5.06%; T-3 $483.33 or 10.76%; and T-4 $435.10 or 11.30%. The
cost of natural gas is a straight passthrough to customers --Intermountain does not earn a profit on the cost of natural
gas.
The changes in the proposed PGA are due to an increase in estimated gas commodity and transportation costs for the
coming year, offset by lower estimated storage costs and over-collected gas costs from the prior PGA.
Intermountain Gas urges all customers to use energy wisely. For more information about the company's energy
efficiency program and available rebates for installing high efficiency equipment,visit www.intgas.com/saveeneig_y.
Conservation tips, information on government payment energy assistance and programs to help consumers level out
their energy bills over the year can be found on the company's website www.intgas.com.
sue.
The request is a proposal and is subject to public review and approval by the PUC. A copy of the application is
available for review at the commission, its homepage www.puc.idaho.gov, as well as the company's website
www.intgas.com. Written comments regarding the application(INT-G-25-04)may be filed with the commission by
going to puc.idaho.gov/Form/CaseComment or mailing to:
Idaho Public Utilities Commission
P.O. Box 83720
Boise, ID 83720-0074
Customers may also subscribe to the commission's RSS feed to review periodic updates via email.
About Intermountain Gas Company
Intermountain Gas Company is a natural gas distribution company serving approximately 433,300 residential,
commercial and industrial customers in 74 communities in southern Idaho. Intermountain is a subsidiary ofMDU
Resources Group, Inc., a member of the S&P SmallCap 600 index that provides essential products and services
through its regulated electric and natural gas distribution and pipeline segments,focused on energizing lives for a
better tomorrow. For more information about MD U Resources, visit www.mdu.com. For more information about
Intermountain, visit www.intpas.com.
Media Contact: Mark Snider at 208-377-6006 (o), 208-559-5613 (c) or mark.snider&mduresources.com

^INTERMOUNTAIN' CUSTOMER NOTICE
GAS COMPANY s Intermountain Gas Company files change in prices as part of PGA filing
BOISE, ID-August 7, 2025 - Intermountain Gas Company filed its annual purchased gas cost adjustment(PGA)application(Case
No. INT-G-25-04)with the Idaho Public Utilities. If approved, residential and small commercial customers will see a price decrease,while large
industrial customers will see an increase. In total,Intermountain Gas is asking the PUC to approve an average increase of 0.10%or$303,638.
The PGA application is filed each year to ensure the costs Intermountain incurs on behalf of its customers are reflected in its sales prices. If
approved,the new rates will go into effect on Oct. 1,2025.
A typical residential customer will see a monthly decrease of$0.12 or 0.28%.Commercial customers,on average,will see a monthly decrease
of$0.06 or 0.03%. Large volume and transport customers,on average,will see the following monthly increases: LV-1 $649.24 or 5.06%;T-3
$483.33 or 10.76%;and T-4$435.10 or 11.30%.The cost of natural gas is a straight passthrough to customers--Intermountain does not
earn a profit on the cost of natural gas.
The changes in the proposed PGA are due to an increase in estimated gas commodity and transportation costs for the coming year,offset by
lower estimated storage costs and over-collected gas costs from the prior PGA.
(continued on reverse side)
The request is a proposal and is subject to public review and approval by the PUC.A copy of the application is available for review at the
commission,its homepage www.puc.idaho.gov,as well as the company's website www.intgas.com.Written comments regarding the application
(INT-G-25-04)may be filed with the commission by going to puc.idaho.gov/Form/CaseComment or mailing to:
Idaho Public Utilities Commission
P.O. Box 83720
Boise,ID 83720-0074
Customers may also subscribe to the commission's RSS feed to review periodic updates via email.
Intermountain Gas Company is a natural gas distribution company serving approximately 433,300 residential,commercial and industrial customers
in 74 communities in southern Idaho. Intermountain is a subsidiary of MDU Resources Group,Inc.,a member of the S&P SmallCap 600 index that
provides essential products and services through its regulated electric and natural gas distribution and pipeline segments. For more information
about MDU Resources,visit www.mdu.com. For more information about Intermountain,visit www.intgas.com
Intermountain Gas urges all customers to use energy wisely.For more information
about the company's energy efficiency program,visit www.intgas.com/saveenergy.
Conservation tips,information on government payment energy assistance and programs to help
consumers level out their energy bills over the year can be found on the company's website ^INTERMOUNTAIN'
www.intgas.com. GAS COMPANY
I.`M:11 1 K.�O.T...'A"
In In!•Caw1AmN,fp Se"!
CUSTOMER SERVICE:800-548-3679 DOE= www.intgas.com
MON-FRI 7:30 a.m.-6:30 p.m.

WORKPAPER NOS. 1-6
CASE NO. INT-G-25-04
INTERMOUNTAIN GAS COMPANY
(11 pages)

Workpaper No. 1
Case No. INT-G-25-04
Intermountain Gas Company
Page 1 of 2
INTERMOUNTAIN GAS COMPANY
Summary of Northwest Pipeline TF-1 Full Rate Demand Costs
Line INT-G-24-04 INT-G-24-04 INT-G-24-04
No. Transportation Annual Therms Prices(') Annual Cost(2)
(a) (b) (c) (d)
1 TF-1 Reservation Contract#1 412,537,600 $ 0.038093 $ 15,714,717
2 TF-1 Reservation Contract#2 25,550,000 0.037250 951,741
3 TF-1 Reservation Contract#3 73,000,000 0.037250 2,719,250
4 TF-1 Reservation Contract#4 26,429,650 0.037250 984,501
5 TF-1 Reservation Contract#5 32,850,000 0.037250 1,223,666
6 TF-1 Reservation Contract#6 36,500,000 0.037250 1,359,625
7 TF-1 Reservation Contract#7 43,680,000 0.037250 1,627,080 (3)
8 TF-1 Reservation Contract#8 18,250,000 0.037250 679,816
9 TF-1 Reservation Contract#9 104,495,850 0.037250 3,892,467
10 TF-1 Reservation Contract#10 26,462,500 0.037250 985,727
11 TF-1 Reservation Contract#11 51,081,750 0.037250 1,902,793
12 Total 850,837,350 $ 32,041,383
Line INT-G-25-04 INT-G-25-04 INT-G-25-04
No. Transportation Annual Therms Prices(') Annual Cost(2)
(a) (b) (c) (d)
13 TF-1 Reservation Contract#1 412,537,600 $ 0.040349 $ 16,645,400
14 TF-1 Reservation Contract#2 25,550,000 0.039506 1,009,380
15 TF-1 Reservation Contract#3 6,200,000 0.037250 230,950 (4)
16 TF-1 Reservation Contract#4 26,429,650 0.039506 1,044,134
17 TF-1 Reservation Contract#5 32,850,000 0.039506 1,297,773
18 TF-1 Reservation Contract#6 36,500,000 0.039506 1,441,972
19 TF-1 Reservation Contract#8 18,250,000 0.039506 720,982
20 TF-1 Reservation Contract#9 104,495,850 0.039506 4,128,210
21 TF-1 Reservation Contract#10 26,462,500 0.039506 1,045,431
22 TF-1 Reservation Contract#11 51,081,750 0.039506 2,018,037
23 Total 740,357,350 $ 29,582,269
24 Total Annual Cost Difference(Line 23 minus Line 12) $ (2,459,114)(5)
(') Column(d)divided by Column(b),rounded to 6 decimal places
(2) Sum of the calculated monthly costs
(3) This contract expired on 3/31/2025
(4) This contract is expiring on 10/31/2025
(5) See Exhibit No.5,Line 3,Column(h)

Workpaper No. 1
Case No. INT-G-25-04
Intermountain Gas Company
Page 2 of 2
INTERMOUNTAIN GAS COMPANY
Summary of Northwest Pipeline TF-1 Discounted Demand Costs
Line INT-G-24-04 INT-G-24-04 INT-G-24-04
No. Transportation Annual Therms Prices(l) Annual Cost(2)
(a) (b) (c) (d)
1 TF-1 Reservation Contract#1 76,650,000 $ 0.024212 $ 1,855,887
2 TF-1 Reservation Contract#2 36,500,000 0.022350 815,775
3 TF-1 Reservation Contract#3 5,733,000 0.033525 192,198 (3)
4 TF-1 Reservation Contract#4 4,530,000 0.007450 33,750
5 TF-1 Reservation Contract#5 63,688,850 0.009312 593,101
6 TF-1 Reservation Contract#6 59,513,250 0.013038 775,906
7 TF-1 Reservation Contract#7 91,250,000 0.009313 849,768
8 Total 337,865,100 $ 5,116,385
Line INT-G-25-04 INT-G-25-04 INT-G-25-04
No. Transportation Annual Therms Prices(l) Annual Cost(2)
(a) (b) (c) (d)
9 TF-1 Reservation Contract#1 76,650,000 $ 0.024212 $ 1,855,887
10 TF-1 Reservation Contract#2 3,100,000 0.022350 69,285 (4)
11 TF-1 Reservation Contract#4 4,530,000 0.007450 33,750
12 TF-1 Reservation Contract#5 63,688,850 0.036989 2,355,817
13 TF-1 Reservation Contract#6 59,513,250 0.037325 2,221,337
14 TF-1 Reservation Contract#7 91,250,000 0.036990 3,375,297
15 Total 298,732,100 $ 9,911,373
16 Total Annual Cost Difference (Line 15 minus Line 8) $ 4,794,988 (5)
(1) Column(d)divided by Column (b), rounded to 6 decimal places
(2) Sum of the calculated monthly costs
(3) This contract expired on 3/31/2025
(4) This contract is expiring on 10/31/2025
(5) See Exhibit No.5, Line 4, Column (h)

Workpaper No.2
Case No. INT-G-25-04
Intermountain Gas Company
Page 1 of 2
INTERMOUNTAIN GAS COMPANY
Summary of Upstream Capacity Full Rate Demand Costs
Line INT-G-24.04 INT-G-24.04 INT-G-24.04
No. Transportation Annual Therms Pricesl'I Annual Cost(')
(a) (b) (c) (d)
1 Upstream Agreement#1 24,011,160 $ 0.016503 $ 396,252
2 Upstream Agreement#2 351,503,260 0.015289 5,374,275
3 Upstream Agreement#3 26,962,550 0.015279 411,972
4 Upstream Agreement#4 1,873,180 0.152795 286,212
5 Upstream Agreement#5 5,675,385 0.152795 867,168
6 Upstream Agreement#6 29,744,945 0.152795 4,544,892
7 Upstream Agreement#7 37,244,600 0.015279 569,076
8 Upstream Agreement#8 26,126,700 0.015315 400,128
9 Upstream Agreement#9 128,898,520 0.015315 1,974,067
10 Upstream Agreement#10 54,750,000 0.015315 838,496
11 Upstream Agreement#11 62,050,000 0.015315 950,293
12 Upstream Agreement#12 133,590,000 0.015315 2,045,916
13 Upstream Agreement#13 1,825,000 0.253954 463,466
14 Upstream Agreement#14 5,514,785 0.253952 1,400,493
15 Upstream Agreement#15 23,989,636 0.313952 7,531,591
16 Upstream Agreement#16 36,974,500 0.015315 566,258
17 Upstream Agreement#17 1,903,840 0.233099 443,784 (3)
18 Upstream Agreement#18 5,643,265 0.233095 1,315,416 "'
19 Upstream Agreement#19 30,507,795 0.233095 7,111,212 (3)
20 Upstream Agreement#20 37,657,050 0.023309 877,764
21 Total 1,026,446,171 38,368,731
22 Estimated Upstream Capacity Release Credits (500,000)
23 Total Annual Cost Including Capacity Release Credits $ 37,868,731
Line INT-G-25.04 INT-G-25-04 INT-G-25.04
No. Transportation Annual Therms Priced') Annual Cost(')
(a) (b) (c) (d)
24 Upstream Agreement#1 24,011,160 $ 0.015675 $ 376,380
25 Upstream Agreement#2 351,503,260 0.014523 5,104,787
26 Upstream Agreement#3 26,962,550 0.014513 391,320
27 Upstream Agreement#4 1,873,180 0.145133 271,860
28 Upstream Agreement#5 5,675,385 0.145134 823,692
29 Upstream Agreement#6 29,744,945 0.145134 4,316,988
30 Upstream Agreement#7 3,163,240 0.014240 45,045 (4)
31 Upstream Agreement#8 26,126,700 0.013496 352,602
32 Upstream Agreement#9 128,898,520 0.013496 1,739,594
33 Upstream Agreement#10 54,750,000 0.013496 738,891
34 Upstream Agreement#11 62,050,000 0.013496 837,413
35 Upstream Agreement#12 133,590,000 0.013496 1,802,902
36 Upstream Agreement#13 1,825,000 0.255937 467,085
37 Upstream Agreement#14 5,514,785 0.255939 1,411,447
38 Upstream Agreement#15 28,835,000 0.315938 9,110,071
39 Upstream Agreement#16 3,140,300 0.013496 42,381 '4'
40 Upstream Agreement#20 3,198,270 0.026853 85,882 (4)
41 Total 890,862,295 27,918,340
42 Estimated Upstream Capacity Release Credits (500,000)
43 Total Annual Cost Including Capacity Release Credits $ 27,418,340
44 Total Annual Cost Difference(Line 43 minus Line 23) $ (12,450,391)(5)
") Column(d)divided by Column(b),rounded to 6 decimal places
(2) Sum of the calculated monthly costs
(3) Moved to Workpaper No.2,Page 2
(4) These contracts are expiring on 1 0/3112 0 2 5
(s) See Exhibit No.5,Line 5,Column(h)

Workpaper No.2
Case No. INT-G-25-04
Intermountain Gas Company
Page 2 of 2
INTERMOUNTAIN GAS COMPANY
Summary of Upstream Capacity Discounted Demand Costs
Line INT-G-24-04 INT-G-24-04 INT-G-24-04
No. Transportation Annual Therms Prices(l) Annual Cost(Z)
(a) (b) (c) (d)
1 Upstream Agreement#1 452,311,650 $ 0.021048 $ 9,520,200
2 Total 452,311,650 $ 9,520,200
Line INT-G-25-04 INT-G-25-04 INT-G-25-04
No. Transportation Annual Therms Prices(l) Annual Cost(Z)
(a) (b) (c) (d)
3 Upstream Agreement#1 452,311,650 $ 0.024763 $ 11,200,548
4 Upstream Agreement#2 1,903,840 $ 0.247628 $ 471,444
5 Upstream Agreement#3 5,643,265 $ 0.247629 $ 1,397,436
6 Upstream Agreement#4 30,507,795 $ 0.247629 $ 7,554,612
7 Total 490,366,550 $ 20,624,040
8 Total Annual Cost Difference (Line 7 minus Line 2) $ 11,103,840 (3)
Column (d)divided by Column (b), rounded to 6 decimal places
(2) Sum of the calculated monthly costs
(3) See Exhibit No. 5, Line 6, Column (h)

Workpaper No.3
Case No. INT-G-25-04
Intermountain Gas Company
Page 1 of 1
INTERMOUNTAIN GAS COMPANY
Summary of Other Storage Facility Costs
INT-G-24.04
Line Monthly INT-G-24-04 INT-G-24-04 INT-G-24-04
No. Storage Facilities Billing Determinant Prices Monthly Cost Annual Cost
(a) (b) (c) (d) (e)
1 Clay Basin Costs:
2 Clay Basin I Reservation 266,250 (1) $ 0.285338 $ 75,971 $ 911,652
3 Clay Basin II Reservation 221,880 (') 0.285338 63,311 759,732
4 Clay Basin III Reservation 213,010 (') 0.285338 60,780 729,360
5 Clay Basin I Capacity 31,950,000 (2) 0.002378 75,977 911,724
6 Clay Basin II Capacity 26,625,000 (2) 0.002378 63,314 759,768
7 Clay Basin III Capacity 25,560,000 (2) 0.002378 60,782 729,384
8 Total Clay Basin Costs $ 400,135 $ 4,801,620
9 Rexburg LNG Facility:
10 Transportation Reservation $ 99,000
11 Variable Transportation 18,000
12 Total Rexburg LNG Facility Costs $ 117,000
13 Storage Demand Charge Credit $ (2,300,000)
14 Total Costs Including Storage Credit $ 2,618,620
INT-G-25-04
Line Monthly INT-G-25-04 INT-G-25-04 INT-G-25-04
No. Storage Facilities Billing Determinant Prices Monthly Cost Annual Cost
(a) (b) (c) (d) (e)
15 Clay Basin Costs:
16 Clay Basin I Reservation 266,250 (') $ 0.285338 $ 75,971 $ 911,652
17 Clay Basin II Reservation 221,880 (') 0.285338 63,311 759,732
18 Clay Basin III Reservation 213,010 (') 0.285338 60,780 729,360
19 Clay Basin I Capacity 31,950,000 (2) 0.002378 75,977 911,724
20 Clay Basin II Capacity 26,625,000 (2) 0.002378 63,314 759,768
21 Clay Basin III Capacity 25,560,000 (2) 0.002378 60,782 729,384
22 Total Clay Basin Costs $ 400,135 $ 4,801,620
23 Rexburg LNG Facility:
24 Transportation Reservation $ 99,000
25 Variable Transportation 18,000
26 Total Rexburg LNG Facility Costs $ 117,000
27 Estimated Storage Demand Charge Credit $ (7,775,000)
28 Total Costs Including Storage Credit $ (2,856,380)
29 Total Annual Cost Difference(Line 28 minus Line 14) $ (5,475,000)(3)
(') Charge Based on Maximum Daily Withdrawal
(2) Charge Based on Maximum Contractual Capacity
(3) See Exhibit No.5,Line 20,Column(h)

Workpaper No.4
Case No. INT-G-25-04
Intermountain Gas Company
Page 1 of 1
INTERMOUNTAIN GAS COMPANY
Allocation Factors
Peak Demand
Line
No. Description RS GS-1 LV-1 T-3 T-4 Total
(a) (b) (c) (d) (e) (f) W
1 INT-G-25.04 Cost of Gas Allocators:
2 Peak Demand Per Customer 8.94 40.22
3 January 2025 Actual Customers 393,104 36,706
4 INT-G-25-04 Peak Demand Therms(Line 2 times Line 3) 3,514,350 1,476,315 80,605 (') 5,071,270
5 Percent of Total 69,2993% 29,11130/ 1,5894% N/A N/A immo/
6 INT-G-25-04 LNG Sales Credit Demand Allocators:
7 Peak Demand Per Customer 8.94 40.22
8 January 2025 Actual Customers 393,104 36,706
9 INT-G-25-04 Peak Demand Therms(Line 7 times Line 8) 3,514,350 1,476,315 80,605 (') 1,531,030 (') 6,602,300
10 Percent of Total .253 292% 22�. 606% 1.2� N/A 2 10-m1k
I'I Contract Demand

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Workpaper No.6
Case No. INT-G-25-04
Intermountain Gas Company
Page 1 of 1
INTERMOUNTAIN GAS COMPANY
Lost and Unaccounted for Gas
(Volumes in Therms)
Line
No. Description Oct 2021-Sept 2022 Oct 2022-Sept 2023 Oct 2023-Sept 2024
(a) (b) (c) (d)
1 Core Customer Purchased Gas 429,712,484 473,909,088 422,139,148
2 Transportation Customer Gas 372,687,753 386,739,419 387,681,823
3 LNG Storage Withdrawals 4,583,559 9,808,219 7,425,284
4 Under Deliveries of Gas from Pipeline(Draft) - 2,237,240 23,030
5 Total Deliveries to System 806,983,796 872,693,966 817,269,285
6 Core Customer Billed Gas 439,666,208 481,176,312 426,927,370
7 Unbilled Adjustment (8,262,099) 2,308,693 (744,029)
8 Transportation Customer Billed Gas 372,687,753 386,739,419 387,681,823
9 Company Use Gas 474,937 471,263 219,258
10 LNG Storage Injections 2,110,199 14,333,354 6,897,161
11 Line Breaks-Found Gas 988,790 144,075 80,226
12 Other - (4,673,158) (32,591)
13 Over Deliveries of Gas from Pipeline(Pack) 914,530 -
14 Total Deliveries to Customers 808,580,318 880,499,958 821,029,218
15 Lost/(Found)Gas(Line 5 minus 14) (1,596,522) (7,805,992) (3,759,933)
16 Average Purchase WACOG $ 0.31795 $ 0.39753 $ 0.25569
17 Cost of Lost/(Found)Gas(Line 15 times Line 16) $ (507,614) $ (3,103,116) $ (961,377)
18 Lost Gas$/Therm(Line 17 divided by Line 5) $ (0.00063) $ (0.00356) $ (0.00118)
19 Lost/(Found)Gas(Line 15) (1,596,522) (7,805,992) (3,759,933)
20 Lost/(Found)Gas Therms Deferred
21 Lostl(Found)Gas Adjustment(Line 19 minus Line 20) (1,596,522) (7,805,992) (3,759,933)
22 Actual Lost Gas Rate(Line 15 divided by Line 5) -0.1978% -0.8945% -0.4601%
23 3-Year Average Lost Gas Rate -0.3678%t11 —0.5959%(2) —0.5175%c3i
See Case No.INT-G-23-04
Z See Case No.INT-G-24-04
Current PGA 3-Year Average