HomeMy WebLinkAbout20230814Application.pdf
August 14, 2023
Ms. Jan Noriyuki
Commission Secretary
Idaho Public Utilities Commission
P.O. Box 83720
Boise, ID 83720-0074
RE: Case No. INT-G-23-04
Dear Ms. Noriyuki:
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, 2023.
If you should have any questions regarding the attached, please don’t hesitate to contact me at (208)
377-6015.
Sincerely,
Lori A. Blattner
Director, Regulatory Affairs
Intermountain Gas Company
Enclosure
cc: Mark Chiles
Preston Carter
RECEIVED
2023 AUGUST 14, 2023 3:28PM
IDAHO PUBLIC
UTILITIES COMMISSION
INTERMOUNTAIN GAS COMPANY
CASE NO. INT-G-23-04
APPLICATION,
EXHIBITS,
AND
WORKPAPERS
In the Matter of the Application of INTERMOUNTAIN GAS COMPANY
For Authority to Decrease its Prices on October 1, 2023
(October 1, 2023 Purchased Gas Cost Adjustment Filing)
INTERMOUNTAIN GAS COMPANY’S APPLICATION - 2
Preston N. Carter, ISB No. 8462
Morgan D. Goodin, ISB No. 11184
Givens Pursley LLP
601 W. Bannock St.
Boise, Idaho 83702
Telephone: (208) 388-1200
Attorneys for Intermountain Gas Company
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
In the Matter of the Application of
INTERMOUNTAIN GAS COMPANY
for Authority to Change its Prices
Case No. INT-G-23-04
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, 2023
new rate schedules which will decrease its annualized revenues by approximately $86.9 million.
Because of changes in Intermountain’s gas related costs, as described more fully in this Application,
Intermountain’s earnings will not be impacted as a result of the proposed changes in prices and
revenues. Exhibit No. 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@intgas.com
INTERMOUNTAIN GAS COMPANY’S APPLICATION - 3
and
Preston N. Carter
Givens Pursley LLP
601 W. Bannock St.
Boise, Idaho 83702
prestoncarter@givenspursley.com
stephaniew@givenspursley.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;
Power County - American Falls;
Twin Falls County - Buhl, Filer, Hansen, Kimberly, Murtaugh, and Twin Falls;
Washington County - Weiser.
INTERMOUNTAIN GAS COMPANY’S APPLICATION - 4
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) a decrease
in Intermountain’s Weighted Average Cost of Gas (“WACOG”), 3) interest expense on short-term
debt borrowed to pay for the unprecedented gas costs incurred during the 2022-2023 heating season,
4) an updated customer allocation of gas related costs pursuant to the Company’s Purchased Gas
Cost Adjustment (“PGA”) provision, 5) the inclusion of temporary surcharges and credits for one
year relating to natural gas purchases and interstate transportation costs from Intermountain’s
deferred gas cost accounts, 6) benefits resulting from Intermountain’s management of its storage
and firm capacity rights on various pipeline systems, 7) benefits associated with the sale of liquefied
natural gas from the Company’s Nampa, Idaho facility, 8) the recovery of deferred in-person
customer payment fees, and 9) the recovery of over-refunded Residential Energy Efficiency funds.
Intermountain also seeks to eliminate the temporary surcharges and credits included in its current
prices during the past 12 months, pursuant to Case No. INT-G-22-04. If approved, these changes
would result in a price increase to T-3 customers and a price decrease to all other 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 - 5
III.
The Commission approved the current temporary and transportation prices in Order
No. 35538, Case No. INT-G-22-04. Prices related to the cost of gas were approved in Order
No. 35673, Case No. INT-G-22-08.
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-22-04. 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”). Intermountain has held more
firm transportation receipt capacity at Stanfield on Northwest Pipeline than it had firm
transportation delivery capacity at Stanfield on GTN. This mismatch meant Intermountain was
unable to take full advantage of the more economically priced natural gas out of the Aeco supply
basin in the Province of Alberta. In late 2020, Intermountain was informed by TC Energy (the
parent company of NOVA, Foothills, and GTN) that they would be conducting an open season
for a pipeline expansion on NOVA, Foothills and GTN for firm transportation service from Aeco
to Malin, OR. Intermountain was awarded 79,000 MMBtu per day of firm transportation on
GTN and the related upstream pipelines of Foothills and NOVA with an expected in-service date
of November 1, 2023. The open season award left Intermountain 21,000 MMBtu per day short
INTERMOUNTAIN GAS COMPANY’S APPLICATION - 6
of their requested participation level. With the assistance of IGI Resources, Intermountain was
able to acquire an additional 21,000 per day through a permanent release of firm transportation
capacity from two producers. This 21,000 per day permanent release was on all three pipelines
(NOVA, Foothills and GTN) and the start date of such capacity is April 1, 2024. The Company
is confident (based on current longer term futures gas prices) that the increase in transportation
costs will be more than offset by access to the significantly lower priced gas supplies out of the
Aeco supply basin. The total firm transportation cost increase resulting from these changes is
approximately $18.9 million.
In addition to the changes described above, Northwest Pipeline has decreased its
transportation rates since the last PGA, while Foothills and NOVA have increased their rates.
The net price increase resulting from these changes and the changes above is $17,458,630 and is
included on Exhibit No. 5, Lines 3-6. Exhibit No. 5 is attached and incorporated by reference.
V.
Intermountain continues to contract a variety of natural gas storage assets on Northwest
Pipeline’s system as well as with Dominion Energy Questar Pipeline, LLC (“Dominion”). In
addition to providing operational reliability, these storage contracts can provide significant price
stability to customers.
Furthermore, Intermountain continues to effectively manage its natural gas storage assets
at Northwest’s Jackson Prairie and Dominion’s Clay Basin storage facilities. Supporting
documents to Line 20 of Exhibit No. 5 show Intermountain’s management of these storage assets
resulted in $2.3 million in savings for customers.
INTERMOUNTAIN GAS COMPANY’S APPLICATION - 7
Since the last PGA, Northwest Pipeline has increased rates for some aspects of its storage
services while decreasing rates for other aspects. As seen on Exhibit No. 5, Lines 7 through 20,
the total increase to Intermountain’s prices resulting from these changes is $399,204.
VI.
The WACOG reflected in Intermountain’s proposed prices is $0.30455 per therm, as shown
on Exhibit No. 5, Line 22, Col. (f). This compares to $0.52808 per therm currently included in the
Company’s tariffs. This represents a decrease of approximately $98.5 million as seen on Exhibit
No. 5, Line 22, Col. (h).
As the market approached the winter of November 2022 to March 2023, a number of factors
contributed to the unprecedented rise in the regional commodity gas cost throughout the Western
U.S. last winter. November 2022 started off very cold versus normal and the colder than normal
weather continued into December. As a result, many utilities in the Pacific Northwest initially held
back on withdrawing any gas from storage in order to protect such storage balances should there be
a continued cold period or a new cold snap later in the winter, which in turn put a higher demand on
non-storage gas and a rise in prices. Certain well freeze offs also occurred in the Rocky Mountain
region further exacerbating the price increases.
The combination of all these events, and the commensurate run up in natural gas prices,
prompted the Company to file an Interim PGA (Case No. INT-G-22-08) to increase its WACOG
from $0.39216 to $0.52808, an overall increase of 17.12% to customer prices. Increasing the
WACOG to match current market conditions helped to keep deferrals lower by sending accurate
price signals to customers. Since that time there has been a substantial decrease in natural gas
prices. That pricing decrease together with the Company’s hedging program has resulted in the
significant WACOG decrease proposed in this year’s filing.
INTERMOUNTAIN GAS COMPANY’S APPLICATION - 8
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 2023 - 2024 PGA period. Intermountain will employ, in
addition to those fixed price agreements already in place, cost effective price arrangements to
further secure the price of flowing gas embedded within this Application when, and if, those pricing
opportunities materialize in the marketplace.
Intermountain believes that timely natural gas price signals enhance its customers’ ability to
make informed and appropriate energy use decisions. The Company is committed to alert
customers to any significant impending price changes before their winter natural gas usage occurs.
By employing the Company’s Energy Efficiency programs, customer mailings, the Company’s
website, and various media resources, Intermountain will continue to educate its customers
regarding the wise and efficient use of natural gas, billing options available to help manage their
energy budget, and any pending natural gas price changes.
INTERMOUNTAIN GAS COMPANY’S APPLICATION - 9
VII.
Pursuant to the Commission’s Order in Case No. INT-G-22-04, Intermountain included
temporary credits in its October 1, 2022 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 $5.74 million as outlined on Exhibit
No. 8. These benefits include credits generated through releases of a portion of Intermountain’s
firm capacity rights on Northwest Pipeline as well as credits generated from releases of
Intermountain’s upstream pipeline capacity. Intermountain proposes to pass back these credit
amounts via the per therm credits, as detailed on Exhibit No. 8 and included on Exhibit No. 7, Line
INTERMOUNTAIN GAS COMPANY’S APPLICATION - 10
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, 2023 to September 30, 2024, 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 $21.3 million is attributable to a true-up of the collection
of interstate pipeline capacity costs, a federal income tax refund from Northwest Pipeline, 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 $24.2
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, 2022.
Additionally, the Company proposes to collect the interest expense on short-term debt it
borrowed to pay for the extraordinary natural gas costs incurred during the 2022-2023 heating
season that the Company would not have otherwise borrowed. As an example of the unprecedented
nature of these costs, the commodity costs incurred in December 2022 and January 2023 were so
large that they equal approximately 99% of the entire 2023-2024 forecasted commodity costs
included in this filing. As a direct consequence of these unprecedented costs, on December 27,
2022, the Company filed an Interim PGA, Case No. INT-G-22-08, to significantly increase the
WACOG. Although raising the WACOG helped the Company collect additional money from
INTERMOUNTAIN GAS COMPANY’S APPLICATION - 11
customers to pay for the increased gas costs, the collection occurred over a period of months. To
bridge the gap between the payment of gas costs and collection, on December 28, 2022,
Intermountain filed Case No. INT-G-22-09 to request authority to issue up to $150 million of short-
term debt to cover natural gas costs that would be payable in January and February of 2023. This
short-term debt was critical since Intermountain did not have sufficient cash to pay for these
unexpected and extremely high gas costs.
Between January and June 2023, the Company incurred approximately $3 million of short-
term interest expense and estimates that it will incur an additional $768,049 between July and
September on the balance of short-term debt currently outstanding. The Company is proposing to
offset this amount of expense by the total interest accumulated on PGA deferral balances between
January and September 2023 as well as the interest income earned on the Company’s money market
account between January and April 2023 which held the Company’s net cash balance related to the
short-term borrowings during this time period. In total, the estimated short-term interest expense
through September 30, 2023, which the Company is proposing to collect, is approximately $3.2
million as shown on Exhibit No. 10, Line 3, Col. (b). Additionally, the Company proposes to true-
up the July-September estimate and defer any additional short-term interest expense, net of the
interest accumulated on PGA deferral balances, incurred through January 19, 2024 which is the
maturity date of the short-term debt.
The sum of the variable gas costs since October 1, 2022 and the short-term interest expense
is $27,430,825 as shown on Exhibit No. 10, Line 4, Col. (b). Intermountain proposes to collect this
balance via a per therm debit, as shown on Exhibit No. 10, Line 6, Col. (b) and included on Exhibit
No. 7, Line 3.
INTERMOUNTAIN GAS COMPANY’S APPLICATION - 12
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 7 through 28, Col. (b). This
deferral results in a per therm decrease to Intermountain’s customers, as illustrated on Exhibit No.
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 $1.4 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.
In Commission Order No. 34099, Case No. INT-G-18-01, the Company was directed to
defer and later collect through the PGA the fees associated with in-person customer payments at
third party vendors. This authorization was extended in Order No. 35047, Case No. INT-G-21-02.
Finally, Order No. 35836, Case No. INT-G-22-07, authorized the Company to collect in-person
payment fees through base rates going forward, with the fees deferred from October 1, 2022
through February 1, 2023 to be collected in this PGA filing. Exhibit No. 12 summarizes the
customer class surcharges associated with these deferred costs which are included on Exhibit No. 7,
Line 5. Exhibit No. 12 is attached and incorporated by reference.
XIII.
In Commission Order No. 35539, Case No. INT-G-22-05, the Commission approved the
credit of $4.85 million in over-collected Energy Efficiency Residential Funds to be passed back to
INTERMOUNTAIN GAS COMPANY’S APPLICATION - 13
residential customers in the PGA. By September 30, 2023, the Company estimates that it will have
over-refunded Residential Energy Efficiency Funds by $686,777 as shown on Exhibit No. 13. The
Company proposes to collect this balance as shown on Exhibit No. 13, Line 5 and on Exhibit No. 7,
Line 6. Exhibit No. 13 is attached and incorporated by reference.
XIV.
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 customers and a rate
decrease for T-4 customers.
XV.
The proposed price changes herein requested among the classes of service of Intermountain
reflect a just, fair, and equitable pass-through of changes in gas related costs to Intermountain’s
customers.
XVI.
This Application has been brought to the attention of Intermountain’s customers through a
Customer Notice and by a Press Release sent to daily and weekly newspapers, and major radio and
television stations in Intermountain’s service area. The Press Release and Customer Notice are
attached 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 - 14
XVII.
Intermountain requests that this matter be handled under modified procedure pursuant to
Rules 201-204 of the Commission’s Rules of Procedure. Intermountain stands ready for immediate
consideration of this matter.
INTERMOUNTAIN GAS COMPANY’S APPLICATION - 15
XIII.
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, 2023 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 14, 2023.
INTERMOUNTAIN GAS COMPANY GIVENS PURSLEY LLP
B B
Lori A. Blattne Preston N. Carte
Director – Regulatory Affairs Attorney for Intermountain Gas Company
INTERMOUNTAIN GAS COMPANY’S APPLICATION - 13
CERTIFICATE OF SERVICE
I certify that on August 14, 2023, a true and correct copy of the foregoing Case No. INT-G-
23-04 was served upon the following parties via the manner indicated below:
Ed Finklea
Alliance of Western Energy Consumers
545 Grandview Drive
Ashland, OR 97520
efinklea awec.solutions
Electronic Mail
Michael Hale
J. R. Simplot Company
1099 W. Front St.
Boise, ID 83702
michael.hale simplot.co
Electronic Mail
/s/Jacob Betterbed_________________________________
Jacob Betterbed – Regulatory Analyst
EXHIBIT NO. 1
CASE NO. INT-G-23-04
INTERMOUNTAIN GAS COMPANY
SUMMARY OF PRICE CHANGES
(2 pages)
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Exhibit No. 1 Case No. INT-G-23-04 Intermountain Gas Company Page 1 of 2
INTERMOUNTAIN GAS COMPANY
ANALYSIS OF INT-G-23-04 PRICE CHANGE
Line No.Description Amount Total
(a) (b) (c)
1 Deferrals:
2 INT-G-22-04 Temporaries Reversed (1,957,026)$ (1)
3 Add INT-G-23-04 Temporaries:
4 Fixed Deferred Gas Costs (27,023,889)$ (2)
5 Variable Deferred Gas Costs 27,430,825 (3)
6 Lost and Unaccounted For Gas Costs (419,549) (4)
7 LNG Sales Credit (1,423,100) (5)
8 In-Person Payment Fees Deferral 32,461 (6)
9 Residential Energy Efficiency Funds 686,777 (7)
10 Total Temporaries Added (716,475)
11 Total Deferrals (2,673,501)$
12 Base Rate Price Change:
13 Fixed Cost Changes:
14 NWP TF-1 Reservation (Full Rate) (1,616,442)$ (8)
15 NWP TF-1 Reservation (Discounted)(533,930) (9)
16 Upstream Capacity (Full Rate) 19,059,870 (10)
17 Upstream Capacity (Discounted)549,132 (11)
18 SGS-2F and LS-2F 399,204 (12)
19 Other Storage Facility - (13)
20 Total Fixed Cost Change 17,857,834
21 Changes in WACOG (98,484,903) (14)
22 Reallocation of Fixed Costs (3,559,548) (15)
23 Total Base Rate Price Changes (84,186,617)
24 Total Annual Price Change (86,860,118)$
25 Annual Price Change per Exhibit No. 1, Page 1 (86,862,693)$ (16)
26 Difference Due to Rounding 2,575$
(1)
(2)See Exhibit No. 8, Line 3, Column (b), plus Exhibit No. 9, Line 7, Column (b)
(3)See Exhibit No. 10, Line 4, Column (b)
(4)See Exhibit No. 10, Line 12 plus Line 20, Column (b)
(5)See Exhibit No. 11, Line 5, Column (b)
(6)See Exhibit No. 12, Line 4, Column (b)
(7)See Exhibit No. 13, Line 3, Column (b)
(8)See Exhibit No. 5, Line 3, Column (h)
(9)See Exhibit No. 5, Line 4, Column (h)
(10)See Exhibit No. 5, Line 5, Column (h)
(11)See Exhibit No. 5, Line 6, Column (h)
(12)See Exhibit No. 5, sum of Lines 9 - 19, Column (h)
(13)See Exhibit No. 5, Line 20, Column (h)
(14)See Exhibit No. 5, Line 22, Column (h)
(15)See Exhibit No. 5, Line 28, Columns (i) - (k), times Line 24, Columns (i) - (k)
(16)See Exhibit No. 1, Page 1, Line 11, Column (e)
Temporary prices from INT-G-22-04 times Exhibit No. 1, Page 1, Lines 2 - 4, 7 and 9, Column (b)
Exhibit No. 1 Case No. INT-G-23-04 Intermountain Gas Company Page 2 of 2
EXHIBIT NO. 2
CASE NO. INT-G-23-04
INTERMOUNTAIN GAS COMPANY
CURRENT TARIFFS
Showing Proposed Price Changes
(10 pages)
INTERMOUNTAIN GAS COMPANYComparison of Proposed October 1, 2023 PricesTo Currently Approved Prices
Line No.Rate Class
Currently Approved Prices Proposed Adjustment
Proposed
Prices
(a)(b)(c)(d)
1 RS 0.83980$ (0.18554)$ 0.65426$
2 GS-1
3 Block 1 0.87448 (0.21833) 0.65615
4 Block 2 0.85301 (0.21833) 0.63468
5 Block 3 0.83228 (0.21833) 0.61395
6 Block 4 0.76959 (0.21833) 0.55126
7 CNG Fuel
8 Block 1 0.82908 (0.21833) 0.61075
9 Block 2 0.76639 (0.21833) 0.54806
10 IS-R (1)0.84206 (0.20585) 0.63621
11 IS-C (2)
12 Block 1 0.87128 (0.21833) 0.65295
13 Block 2 0.84981 (0.21833) 0.63148
14 Block 3 0.82908 (0.21833) 0.61075
15 Block 4 0.76639 (0.21833) 0.54806
16 LV-1
17 Demand Charge 0.32000 - 0.32000
18 Block 1 0.67765 (0.21612) 0.46153
19 Block 2 0.65952 (0.21612) 0.44340
20 Block 3 0.65500 (0.21612) 0.43888
21 T-3
22 Block 1 0.03612 0.00051 (3)0.03663
23 Block 2 0.01422 0.00051 (3)0.01473
24 Block 3 0.00472 0.00051 (3)0.00523
25 T-4
26 Demand Charge 0.30032 (0.00446) (4)0.29586
27 Block 1 0.02172 - 0.02172
28 Block 2 0.00768 - 0.00768
29 Block 3 0.00236 - 0.00236
(1)
(2)The IS-C price is based on the GS-1 price and receives the same PGA adjustments
(3)
(4)
Line 7, Column (e)
Line 7, Column (f)
The IS-R price is based on the RS price and receives the same PGA adjustments, except for the the
Exhibit No. 2 Case No. INT-G-23-04 Intermountain Gas Company Page 1 of 10
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Exhibit No. 2 Case No. INT-G-23-04 Intermountain Gas Company Page 2 of 10
I.P.U.C. Gas Tariff
Rate Schedules Twelfth Thirteenth Revised Sheet No. 1 (Page 1 of 1)
Name
of Utility
Intermountain Gas Company
Issued by: Intermountain Gas Company
By: Lori A. Blattner Title: Director Regulatory Affairs
Effective: July October 1, 2023
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: $0.839800.65426*
*Includes the following:
Cost of Gas: 1) Temporary purchased gas cost adjustment ($0.000570.00078)
2) Weighted average cost of gas $0.528080.30455
3) Gas transportation cost $0.163640.20184
Distribution Cost: $0.13301
EE Charge: $0.01564
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 Companys 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.
Exhibit No. 2 Case No. INT-G-23-04 Intermountain Gas Company Page 3 of 10
I.P.U.C. Gas Tariff
Rate Schedules
Sixty-Seventh Eighth Revised Sheet No. 3 (Page 1 of 2)
Name of Utility
Intermountain Gas Company
Issued by: Intermountain Gas Company
By: Lori A. Blattner Title: Director Regulatory Affairs
Effective: JulyOctober 1, 2023
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 Companys 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 @ $0.874480.65615*
Block Two: Next 1,800 therms per bill @ $0.853010.63468*
Block Three: Next 8,000 therms per bill @ $0.832280.61395*
Block Four: Over 10,000 therms per bill @ $0.769590.55126*
*Includes the following:
Cost of Gas: 1) Temporary purchased gas cost adjustment $0.01445($0.00377)
2) Weighted average cost of gas $0.528080.30455
3) Gas transportation cost $0.159900.18332
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: $0.00320
Exhibit No. 2 Case No. INT-G-23-04 Intermountain Gas Company Page 4 of 10
I.P.U.C. Gas Tariff
Rate Schedules
Sixty-Seventh Eighth Revised Sheet No. 3 (Page 2 of 2)
Name of Utility
Intermountain Gas Company
Issued by: Intermountain Gas Company
By: Lori A. Blattner Title: Director Regulatory Affairs
Effective: JulyOctober 1, 2023
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 @ $0.829080.61075*
Block Two: Over 10,000 therms per bill @ $0.766390.54806*
*Includes the following:
Cost of Gas: 1) Temporary purchased gas cost adjustment $0.01445($0.00377)
2) Weighted average cost of gas $0.528080.30455
3) Gas transportation cost $0.159900.18332
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 Companys 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.
Exhibit No. 2 Case No. INT-G-23-04 Intermountain Gas Company Page 5 of 10
I.P.U.C. Gas Tariff
Rate Schedules Twenty-ThirdFourth Revised Sheet No. 4 (Page 1 of 2)
Name of Utility
Intermountain Gas Company
Issued by: Intermountain Gas Company
By: Lori A. Blattner Title: Director Regulatory Affairs
Effective: July October 1, 2023
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 Companys 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: $0.842060.63621*
*Includes the following:
Cost of Gas: 1) Temporary purchased gas cost adjustment $0.01733($0.00319)
2) Weighted average cost of gas $0.528080.30455
3) Gas transportation cost $0.163640.20184
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.
Exhibit No. 2 Case No. INT-G-23-04 Intermountain Gas Company Page 6 of 10
I.P.U.C. Gas Tariff
Rate Schedules Twenty-Second Third Revised Sheet No. 5 (Page 1 of 2)
Name of Utility
Intermountain Gas Company
Issued by: Intermountain Gas Company
By: Lori A. Blattner Title: Director Regulatory Affairs
Effective: July October 1, 2023
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 Companys 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 @ $0.871280.65295*
Block Two: Next 1,800 therms per bill @ $0.849810.63148*
Block Three: Next 8,000 therms per bill @ $0.829080.61075*
Block Four: Over 10,000 therms per bill @ $0. 766390.54806*
*Includes the following:
Cost of Gas: 1) Temporary purchased gas cost adjustment $0.01445($0.00377)
2) Weighted average cost of gas $0.528080.30455
3) Gas transportation cost $0.159900.18332
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
Exhibit No. 2 Case No. INT-G-23-04 Intermountain Gas Company Page 7 of 10
I.P.U.C. Gas Tariff
Rate Schedules Seventy-Fourth Fifth Revised Sheet No. 7 (Page 1 of 2)
Name of Utility
Intermountain Gas Company
Issued by: Intermountain Gas Company
By: Lori A. Blattner Title: Director Regulatory Affairs
Effective: July October 1, 2023
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 Companys 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 @ $0.677650.46153*
Block Two: Next 35,000 therms per bill @ $0.659520.44340*
Block Three: Over 70,000 therms per bill @ $0.655000.43888*
*Includes the following:
Cost of Gas: 1) Temporary purchased gas cost adjustment $0.032470.03253
2) Weighted average cost of gas $0.528080.30455
3) Gas transportation cost $0.087100.09445
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 customers meter.
Exhibit No. 2 Case No. INT-G-23-04 Intermountain Gas Company Page 8 of 10
I.P.U.C. Gas Tariff
Rate Schedules Twenty-ThirdFourth Revised Sheet No. 8 (Page 1 of 1)
Name
of Utility
Intermountain Gas Company
Issued by: Intermountain Gas Company
By: Lori A. Blattner Title: Director Regulatory Affairs
Effective: July October 1, 2023
Rate Schedule T-3 INTERRUPTIBLE DISTRIBUTION TRANSPORTATION SERVICE
AVAILABILITY:
Available at any point on the Company's distribution system to any customer upon execution of a one year
minimum written service contract. MONTHLY RATE:
Customer Charge: $300.00 per bill Per Therm Charge: Block One: First 100,000 therms transported @ $0.036120.03663*
Block Two: Next 50,000 therms transported @ $0.014220.01473*
Block Three: Over 150,000 therms transported @ $0.004720.00523*
*Includes temporary purchased gas cost adjustment of ($0.0008231)
ANNUAL MINIMUM BILL:
The customer shall be subject to the payment of an annual minimum bill based on annual usage of 200,000
therms. The deficit usage below 200,000 therms shall be billed at the T-3 Block 1 rate.
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for the cost of purchased gas as provided for in Rate Schedule PGA.
This adjustment is incorporated into the calculation of the Cost of Gas stated on customer bills.
SERVICE CONDITIONS:
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 Companys distribution system.
Exhibit No. 2 Case No. INT-G-23-04 Intermountain Gas Company Page 9 of 10
I.P.U.C. Gas Tariff
Rate Schedules
Twenty-Second Third Revised Sheet No. 9 (Page 1 of 2)
Name of Utility
Intermountain Gas Company
Issued by: Intermountain Gas Company
By: Lori A. Blattner Title: Director Regulatory Affairs
Effective: July October 1, 2023
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: $0.30032 0.29586 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 ($0.0196802414)
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 Companys
Tariff, of which this Rate Schedule is a part.
2. This service does not include the cost of the customers gas supply of the interstate pipeline capacity.
The customer is responsible for procuring its own supply of natural gas and transportation to
Intermountains 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 customers meter.
Exhibit No. 2 Case No. INT-G-23-04 Intermountain Gas Company Page 10 of 10
EXHIBIT NO. 3
CASE NO. INT-G-23-04
INTERMOUNTAIN GAS COMPANY
PROPOSED TARIFFS
(8 pages)
I.P.U.C. Gas Tariff
Rate Schedules
Thirteenth Revised Sheet No. 1 (Page 1 of 1)
Name
of Utility
Intermountain Gas Company
Issued by: Intermountain Gas Company
By: Lori A. Blattner Title: Director – Regulatory Affairs
Effective: October 1, 2023
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: $0.65426*
*Includes the following:
Cost of Gas: 1) Temporary purchased gas cost adjustment ($0.00078)
2) Weighted average cost of gas $0.30455
3) Gas transportation cost $0.20184
Distribution Cost: $0.13301
EE Charge: $0.01564
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.
Exhibit No. 3 Case No. INT-G-23-04 Intermountain Gas Company Page 1 of 8
I.P.U.C. Gas Tariff
Rate Schedules
Sixty-Eighth Revised Sheet No. 3 (Page 1 of 2)
Name
of Utility
Intermountain Gas Company
Issued by: Intermountain Gas Company
By: Lori A. Blattner Title: Director – Regulatory Affairs
Effective: October 1, 2023
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 @ $0.65615*
Block Two: Next 1,800 therms per bill @ $0.63468*
Block Three: Next 8,000 therms per bill @ $0.61395*
Block Four: Over 10,000 therms per bill @ $0.55126*
*Includes the following:
Cost of Gas: 1) Temporary purchased gas cost adjustment ($0.00377)
2) Weighted average cost of gas $0.30455
3) Gas transportation cost $0.18332
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: $0.00320
Exhibit No. 3 Case No. INT-G-23-04 Intermountain Gas Company Page 2 of 8
I.P.U.C. Gas Tariff
Rate Schedules
Sixty-Eighth Revised Sheet No. 3 (Page 2 of 2)
Name
of Utility
Intermountain Gas Company
Issued by: Intermountain Gas Company
By: Lori A. Blattner Title: Director – Regulatory Affairs
Effective: October 1, 2023
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 @ $0.61075*
Block Two: Over 10,000 therms per bill @ $0.54806*
*Includes the following:
Cost of Gas: 1) Temporary purchased gas cost adjustment ($0.00377)
2) Weighted average cost of gas $0.30455
3) Gas transportation cost $0.18332
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.
Exhibit No. 3 Case No. INT-G-23-04 Intermountain Gas Company Page 3 of 8
I.P.U.C. Gas Tariff
Rate Schedules
Twenty-Fourth Revised Sheet No. 4 (Page 1 of 2)
Name
of Utility
Intermountain Gas Company
Issued by: Intermountain Gas Company
By: Lori A. Blattner Title: Director – Regulatory Affairs
Effective: October 1, 2023
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: $0.63621*
*Includes the following:
Cost of Gas: 1) Temporary purchased gas cost adjustment ($0.00319)
2) Weighted average cost of gas $0.30455
3) Gas transportation cost $0.20184
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.
Exhibit No. 3 Case No. INT-G-23-04 Intermountain Gas Company Page 4 of 8
I.P.U.C. Gas Tariff
Rate Schedules
Twenty-Third Revised Sheet No. 5 (Page 1 of 2)
Name
of Utility
Intermountain Gas Company
Issued by: Intermountain Gas Company
By: Lori A. Blattner Title: Director – Regulatory Affairs
Effective: October 1, 2023
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 @ $0.65295*
Block Two: Next 1,800 therms per bill @ $0.63148*
Block Three: Next 8,000 therms per bill @ $0.61075*
Block Four: Over 10,000 therms per bill @ $0.54806*
*Includes the following:
Cost of Gas: 1) Temporary purchased gas cost adjustment ($0.00377)
2) Weighted average cost of gas $0.30455
3) Gas transportation cost $0.18332
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
Exhibit No. 3 Case No. INT-G-23-04 Intermountain Gas Company Page 5 of 8
I.P.U.C. Gas Tariff
Rate Schedules
Seventy-Fifth Revised Sheet No. 7 (Page 1 of 2)
Name
of Utility
Intermountain Gas Company
Issued by: Intermountain Gas Company
By: Lori A. Blattner Title: Director – Regulatory Affairs
Effective: October 1, 2023
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 @ $0.46153*
Block Two: Next 35,000 therms per bill @ $0.44340*
Block Three: Over 70,000 therms per bill @ $0.43888*
*Includes the following:
Cost of Gas: 1) Temporary purchased gas cost adjustment $0.03253
2) Weighted average cost of gas $0.30455
3) Gas transportation cost $0.09445
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.
Exhibit No. 3 Case No. INT-G-23-04 Intermountain Gas Company Page 6 of 8
I.P.U.C. Gas Tariff
Rate Schedules
Twenty-Fourth Revised Sheet No. 8 (Page 1 of 1)
Name
of Utility
Intermountain Gas Company
Issued by: Intermountain Gas Company
By: Lori A. Blattner Title: Director – Regulatory Affairs
Effective: October 1, 2023
Rate Schedule T-3 INTERRUPTIBLE DISTRIBUTION TRANSPORTATION SERVICE
AVAILABILITY:
Available at any point on the Company's distribution system to any customer upon execution of a one year
minimum written service contract.
MONTHLY RATE:
Customer Charge: $300.00 per bill
Per Therm Charge: Block One: First 100,000 therms transported @ $0.03663*
Block Two: Next 50,000 therms transported @ $0.01473*
Block Three: Over 150,000 therms transported @ $0.00523*
*Includes temporary purchased gas cost adjustment of ($0.00031)
ANNUAL MINIMUM BILL:
The customer shall be subject to the payment of an annual minimum bill based on annual usage of 200,000
therms. The deficit usage below 200,000 therms shall be billed at the T-3 Block 1 rate.
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for the cost of purchased gas as provided for in Rate Schedule PGA.
This adjustment is incorporated into the calculation of the Cost of Gas stated on customer bills.
SERVICE CONDITIONS:
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.
Exhibit No. 3 Case No. INT-G-23-04 Intermountain Gas Company Page 7 of 8
I.P.U.C. Gas Tariff
Rate Schedules
Twenty-Third Revised Sheet No. 9 (Page 1 of 2)
Name
of Utility
Intermountain Gas Company
Issued by: Intermountain Gas Company
By: Lori A. Blattner Title: Director – Regulatory Affairs
Effective: October 1, 2023
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: $0.29586 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 ($0.02414)
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.
Exhibit No. 3 Case No. INT-G-23-04 Intermountain Gas Company Page 8 of 8
EXHIBIT NO. 4
CASE NO. INT-G-23-04
INTERMOUNTAIN GAS COMPANY
PERTINENT EXCERPTS PERTAINING TO INTERSTATE PIPELINES AND RELATED
FACILITIES
(28 pages)
NORTHWEST PIPELINE LLC
(6 pages)
Exhibit No. 4 Case No. INT-G-23-04 Intermountain Gas Company Page 1 of 28
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 records1 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, 2022.2
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
1 See Appendix.
2 Northwest Pipeline LLC., 181 FERC ¶ 61,118 (2022).
Exhibit No. 4 Case No. INT-G-23-04 Intermountain Gas Company Page 2 of 28
Exhibit No. 4 Case No. INT-G-23-04 Intermountain Gas Company Page 3 of 28
Exhibit No. 4 Case No. INT-G-23-04 Intermountain Gas Company Page 4 of 28
Exhibit No. 4 Case No. INT-G-23-04 Intermountain Gas Company Page 5 of 28
FEDERAL ENERGY REGULATORY COMMISSION
WASHINGTON, DC 20426
OFFICE OF ENERGY MARKET REGULATION
Northwest Pipeline LLC
Docket No. RP23-479-000
Issued: March 23, 2023
On February 28, 2023, Northwest Pipeline LLC filed a tariff record1 to reflect its
revised fuel reimbursement factors, pursuant to sections 14.12 and 14.20 of the General
Terms and Conditions of its tariff. Pursuant to authority delegated to the Director,
Division of Pipeline Regulation, under 18 C.F.R. § 375.307, the tariff record is accepted,
effective April 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
1 Northwest Pipeline LLC, Fifth Revised Volume No. 1, Sheet No. 14, Fuel Use
Factors (32.0.0).
Exhibit No. 4 Case No. INT-G-23-04 Intermountain Gas Company Page 6 of 28
Northwest Pipeline LLC
FERC Gas Tariff
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 1.06%
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 0.49%
Rate Schedules LS-2F, LS-3F and LS-2I
Liquefaction 2.08%
Vaporization 0.09%
Rate Schedule LD-4I
Liquefaction 2.08%
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-23-04 Intermountain Gas Company Page 7 of 28
NOVA GAS TRANSMISSION LTD.
(4 pages)
Exhibit No. 4 Case No. INT-G-23-04 Intermountain Gas Company Page 8 of 28
Exhibit No. 4 Case No. INT-G-23-04 Intermountain Gas Company Page 9 of 28
Exhibit No. 4 Case No. INT-G-23-04 Intermountain Gas Company Page 10 of 28
NOVA Gas Transmission Ltd.Attachment 2
Delivery Point Rates
Page 1 of 11Final June-December 2023 Rates
DELIVERY POINT RATES
Group 1
Delivery
Point
Number
Group 1 Delivery Point Name
FT-D Demand Rate
Price Point "Z"
($/GJ/mo)
IT-D Rate
($/GJ/d)
2000 ALBERTA-B.C. BORDER 6.61 0.2391
31111 ALLIANCE CLAIRMONT INTERCONNECT APN 5.95 0.2151
31110 ALLIANCE EDSON INTERCONNECT APN 5.95 0.2151
31112 ALLIANCE SHELL CREEK INTERCONNECT APGC 5.95 0.2151
1958 EMPRESS BORDER 5.95 0.2151
3886 GORDONDALE BORDER 5.95 0.2151
6404 MCNEILL BORDER 5.95 0.2151
Group 2
Delivery
Point
Number
Group 2 Delivery Point Name
FT-D Demand Rate
Price Point "Z"
($/GJ/mo)
IT-D Rate
($/GJ/d)
Subject to
ATCO
Pipelines
Franchise
Fees1
31000 A.T. PLASTICS SALES APN 8.37 0.3028 Yes
31001 ADM AGRI INDUSTRIES SALES APN 8.37 0.3028 Yes
3880 AECO INTERCONNECTION 8.37 0.3028
31003 AGRIUM CARSELAND SALES APS 8.37 0.3028
31002 AGRIUM FT. SASK SALES APN 8.37 0.3028 Yes
31004 AGRIUM REDWATER SALES APN 8.37 0.3028
31005 AINSWORTH SALES APGP 8.37 0.3028
31006 AIR LIQUIDE SALES APN 8.37 0.3028
6126 AITKEN CREEK SOUTH SALES 2 10.73 0.3805
3820 AITKEN CREEK INTERCONNECT 2 10.73 0.3805
3214 AKUINU RIVER WEST SALES 8.37 0.3028
31007 ALBERTA ENVIROFUELS SALES APN 8.37 0.3028 Yes 3
31008 ALBERTA HOSPITAL SALES APN 8.37 0.3028 Yes
3868 ALBERTA-MONTANA BORDER 8.37 0.3028
3297 ALDER FLATS SOUTH NO 2 SALES 8.37 0.3028
3059 ALLISON CREEK SALES 8.37 0.3028
6132 ALTARES SALES 2 10.73 0.3805
6133 ALTARES SOUTH SALES 2 10.73 0.3805
31009 ALTASTEEL SALES APN 8.37 0.3028 Yes 3
6145 ANDERSON LAKE SALES 8.37 0.3028
31012 APL JASPER SALES APN 8.37 0.3028 Yes
3488 ARDLEY SALES 8.37 0.3028
3237 ASPEN SALES 8.37 0.3028
3662 ATUSIS CREEK EAST SALES 8.37 0.3028
3216 AURORA NO 2 SALES 8.37 0.3028
3135 AURORA SALES 8.37 0.3028
3288 BANTRY SALES 8.37 0.3028
3423 BASHAW WEST SALES 8.37 0.3028
6158 BASSET LAKE WEST SALES 8.37 0.3028
31013 BAYMAG SALES APS 8.37 0.3028
6112 BAY TREE SALES 8.37 0.3028
31014 BEAR CREEK COGEN SALES APGP 8.37 0.3028
3299 BEAR RIVER WEST SALES 8.37 0.3028
3068 BEAVER HILLS SALES 8.37 0.3028
3268 BENBOW SOUTH SALES 8.37 0.3028
3933 BIG EDDY INTERCONNECTION 8.37 0.3028
Order: TG-003-2023 Effective: June 1, 2023
Exhibit No. 4 Case No. INT-G-23-04 Intermountain Gas Company Page 11 of 28
NOVA Gas Transmission Ltd.Table of Rates, Tolls and Charges
Page 1 of 1
Final June-December 2023 Rates
TABLE OF RATES, TOLLS AND CHARGES
Service
$283.02 / 103m3 / month
2. Rate Schedule FT-RN
$6.19 / GJ / month
$8.37 / GJ / month
$10.05 / GJ / month
4. Rate Schedule STFT
5. Rate Schedule FT-DW
6. Rate Schedule FT-P 1
7. Rate Schedule IT-R
8. Rate Schedule IT-D 1
9. Rate Schedule FCS
10. Rate Schedule PT Schedule No.
9021-01000-0 $1,138 / day 3.1 / 103m3 / day
9021-01000-1 $4,896 / day 11.0 / 103m3 / day
9022-01000-0 $1,690 / day 3.6 / 103m3 / day
9022-01001-0 $3,071 / day 11.0 / 103m3 / day
9022-01002-0 $3,997 / day 14.6 / 103m3 / day
11. Rate Schedule OS Schedule No.
2022993541 / 2022956310 $127.71 / 103m3 / month
2022017998 $666 / month
2003004522
2011476052 / $0.2753 / GJ subject to
2011476054 $717,000 Minimum Annual Charge
2017887638 / 2011476092 $0.095 / GJ and
2016721799 / 2016759254 $1,000 / month
$7.54 / GJ / month and
12. Rate Schedule CO2 Tier 1 2 3
CO2 Rate ( / 103m3)$625.19 $494.89 $324.51
13. Monthly Abandonment Surcharge 2 $6.94 /103m3 /month $0.18 /GJ /month
14. Daily Abandonment Surcharge 3 $0.23 /103m3 /day $0.0060 /GJ /day
15. Federal Fuel Charge 4 Marketable Natural Gas 5 $0.1239 / m3
Applicable IT-R and IT-D Rate
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.
1. Service under Rate Schedules FT-D, FT-P and IT-D for delivery stations identified in Attachment 2, and Rate Schedule OS No. 2011476092,
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-RN, FT-DW, and STFT, and the following
Schedules OS: 2022993541, 2022956310, 2022017998, 2021735873, 2019305573.
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.
2021735873 / 2019305573 Applicable IT-D Rate on Over-Run
Refer to Attachment “1” for applicable IT-R Rate for each Receipt Point
Refer to Attachment “2” for applicable IT-D Rate for each Delivery Point
PT Rate PT Gas Rate
Charge
The FCS Charge is determined in accordance with Attachment “1” to the applicable Schedule of Service
Rates, Tolls and Charges
1. Rate Schedule FT-R
Refer to Attachment “1” for applicable FT-R Demand Rate per month based on a three-year term (Price Point “B”) &
Surcharge for each Receipt Point
Average Firm Service Receipt Price (AFSRP)
Refer to Attachment “1” for applicable FT-RN Demand Rate per month & Surcharge for each Receipt Point
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 Point
Refer to Attachment “3” for applicable FT-P Demand Rate per month
3. Rate Schedule FT-D 1
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
Average FT-D Demand Rate for Group 1 Delivery Points
FT-D Demand Rate for Group 2 Delivery Points
FT-D Demand Rate for Group 3 Delivery Points
Order: TG-003-2023 Effective: June 1, 2023
Exhibit No. 4 Case No. INT-G-23-04 Intermountain Gas Company Page 12 of 28
FOOTHILLS PIPE LINES LTD.
(3 pages)
Exhibit No. 4 Case No. INT-G-23-04 Intermountain Gas Company Page 13 of 28
450 – 1 Street SW
Calgary, Alberta T2P 5H1
Tel: (403) 920-2603
Fax: (403) 920-2347
Email: bernard_pelletier@tcenergy.com
November 4, 2022
Canada Energy Regulator Filed Electronically
Suite 210, 517 Tenth Avenue SW
Calgary, Alberta T2R 0A8
Attention: Ms. Ramona Sladic, Secretary of the Commission
Dear Ms. Sladic:
Re: Foothills Pipe Lines Ltd. (Foothills)
Statement of Rates and Charges effective January 1, 2023
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, 2023 (Effective 2023 Rates).
The following attachments are included with this letter:
x Attachment 1 consists of supporting Schedules A through G
x Attachments 2 and 3 are black-lined and clean copies, respectively, of the Table of
Effective Rates for 2023
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, 2023, which
are included in the Table of Effective Rates for 2023. The supporting information on the
Abandonment Surcharge calculations are provided in the attached Schedule G.
Foothills met with customers and interested parties on October 27, 2022 and presented the
preliminary 2023 revenue requirement, preliminary Effective 2023 Rates and preliminary
Abandonment Surcharges. Based on this consultation, Foothills is not aware of any objections to
its proposal for establishing the Effective 2023 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-23-04 Intermountain Gas Company Page 14 of 28
November 4, 2022
Ms. Sladic
Page 2 of 2
Communication regarding this filing should be directed to:
Andrew Pittet
Regulatory Project Manager
Tolls and Tariffs, Canadian Natural Gas Pipelines
Foothills Pipe Lines Ltd.
450 – 1 Street SW
Calgary, Alberta T2P 5H1
Telephone: (403) 920-5682
Facsimile: (403) 920-2347
Email: andrew_pittet@tcenergy.com
Ashley Mitchell
Senior Legal Counsel
Canadian Law, Natural Gas Pipelines
Foothills Pipe Lines Ltd.
450 – 1 Street SW
Calgary, Alberta T2P 5H1
Telephone: (403) 920-2184
Facsimile: (403) 920-2347
Email: ashley_mitchell@tcenergy.com
Yours truly,
Foothills Pipe Lines Ltd.
Original signed by
Bernard Pelletier
Director, Regulatory Tolls and Tariffs
Canadian Natural Gas Pipelines
Attachments
cc: Foothills Firm Customers
Interruptible Customers and Interested Parties
Exhibit No. 4 Case No. INT-G-23-04 Intermountain Gas Company Page 15 of 28
Foothills Pipe Lines Ltd. Page 1
TARIFF – PHASE I Effective Date: January 1, 2023
TABLE OF EFFECTIVE RATES
Demand Rate
($/GJ/Km/Month)
2. Rate Schedule OT, Overrun Transportation Service
3. Rate Schedule IT, Interruptible Transportation Service
($/GJ/Km)
4. Monthly Abandonment Surcharge**
5. Daily Abandonment Surcharge***
* For Zone 8, Customers Haul Distance shall be 170.7 km.
**Monthly Abandonment Surcharge applicable to Rate Schedule Firm Transportation Service, and Short Term Firm
Transportation Service for all zones.
***Daily Abandonment Surcharge applicable to Rate Schedule Overrun Transportation Service for Zone 6 & 7,
Interruptible Transportation Service for Zone 8 & 9, and Small General Service for Zone 9.
Exhibit No. 4 Case No. INT-G-23-04 Intermountain Gas Company Page 16 of 28
GAS TRANSMISSION NORTHWEST LLC
(6 pages)
Exhibit No. 4 Case No. INT-G-23-04 Intermountain Gas Company Page 17 of 28
177 FERC ¶ 61,110
FEDERAL ENERGY REGULATORY COMMISSION
WASHINGTON, DC 20426
November 18, 2021
In Reply Refer To:
Gas Transmission Northwest LLC
Docket No. RP15-904-003
Gas Transmission Northwest LLC
Wright & Talisman P.C.
1200 G Street NW
Suite 600
Washington, DC 20005
Attention: Joseph S. Koury, Attorney
Dear Mr. Koury:
On September 29, 2021, Gas Transmission Northwest LLC (GTN) filed a
stipulation and agreement (Settlement) pursuant to Rule 207 of the Commission’s Rules
of Practice and Procedure.1 The Settlement is submitted in lieu of a Natural Gas Act
(NGA) section 4 general rate case filing and fulfills GTN’s obligation, established in
earlier proceedings, to submit rates to be effective no later than April 1, 2022.2 GTN
believes that the Settlement is supported or unopposed by all of its shippers and other
interested parties. As discussed below, we approve the Settlement as proposed to be
effective January 1, 2022.
Previously, the Commission approved a settlement filed by GTN on June 30, 2015
(2015 Settlement)3 and an amendment to that 2015 Settlement on November 30, 2018.4
1 18 C.F.R. § 385.207(a)(5) (2020).
2 Gas Transmission Northwest LLC, 151 FERC ¶ 61,280 (2015); Gas Transmission
Northwest LLC, 165 FERC ¶ 61,195 (2018) (approving 2018 settlement amending an
earlier settlement); Gas Transmission Northwest LLC, 175 FERC ¶ 61,250 (2021)
(extending deadline for rate filing under earlier settlements).
3 Gas Transmission Northwest LLC, 151 FERC ¶ 61,280 (2015).
4 Gas Transmission Northwest LLC, 165 FERC ¶ 61,195 (2018).
Document Accession #: 20211118-3098 Filed Date: 11/18/2021
Exhibit No. 4 Case No. INT-G-23-04 Intermountain Gas Company Page 18 of 28
Docket No. RP15-904-003 - 2 -
On June 4, 2021, GTN filed a motion to extend GTN’s obligation to file an NGA
section 4 rate case until April 1, 2022. The Commission approved the extension of time
on June 28, 2021.5
This Settlement resolves issues regarding GTN’s rates and rate filing obligations.
The Settlement maintains existing tariff recourse rates and establishes depreciation rates
and a carbon tax regulatory asset. It also provides for the establishment of income tax
allowance and accumulated deferred income tax in the future. In addition, it establishes
that after December 31, 2023, GTN will report to settling parties the expenses, capital
expenditures and amounts recovered relating to dithiazine contamination and
remediation.
GTN states that the Settlement establishes a rate case moratorium through
December 31, 2023 and a comeback provision to file for rates to become effective no
later than April 1, 2024, accounting for any Commission-imposed suspension period.
GTN further states that the standard of review for modifications by the Commission to
the terms of the Settlement “shall be the most stringent standard permissible under
applicable law.”6
Public notice of the filing was issued on October 1, 2021. Interventions and
protests were due as provided in section 154.210 of the Commission’s regulations.7
Pursuant to Rule 214,8 all timely filed motions to intervene are granted. The Canadian
Association of Petroleum Producers intervened, supporting the Settlement. No protests
or adverse comments were filed.
The Settlement appears to provide that the standard of review applicable to
modifications to the Settlement proposed by third parties and the Commission acting sua
sponte “shall be the most stringent standard permissible under applicable law.”9
Although we do not decide in this order what standard of review applies to the Settlement
or any component of it, we clarify the framework that would apply if the Commission
were required to determine the standard of review in a later challenge to the Settlement
by a third party or the Commission acting sua sponte.
5 Gas Transmission Northwest LLC, 175 FERC ¶ 61,250 (2021).
6 Settlement at article V and article XIII.
7 18 C.F.R. § 154.210 (2020).
8 18 C.F.R. § 385.214 (2020).
9 Settlement at article V and article XIII.
Document Accession #: 20211118-3098 Filed Date: 11/18/2021
Exhibit No. 4 Case No. INT-G-23-04 Intermountain Gas Company Page 19 of 28
Docket No. RP15-904-003 - 3 -
The Mobile-Sierra “public interest” presumption applies to an agreement only
if the agreement has certain characteristics that justify the presumption. In ruling on
whether the characteristics necessary to justify a Mobile-Sierra presumption are present,
the Commission must determine whether the agreement at issue embodies either:
(1) individualized rates, terms, or conditions that apply only to sophisticated parties who
negotiated them freely at arm’s length; or (2) rates, terms, or conditions that are generally
applicable or that arose in circumstances that do not provide the assurance of justness and
reasonableness associated with arm’s-length negotiations. Unlike the latter, the former
constitute contract rates, terms, or conditions that necessarily qualify for a Mobile-Sierra
presumption. In New England Power Generators Association v. FERC,10 however, the
Court of Appeals for the D.C. Circuit determined that the Commission is legally
authorized to impose a more rigorous application of the statutory “just and reasonable”
standard of review on future changes to agreements that fall within the second category
described above.
We find that the uncontested Settlement appears to be fair and reasonable and in
the public interest. The Settlement is supported or not opposed by all parties to the
proceeding and establishes a rate moratorium. Therefore, we approve the Settlement as
proposed to be effective January 1, 2022. The Commission’s approval of the Settlement
does not constitute approval of, or precedent regarding, any principle or issue in this
proceeding.
By direction of the Commission. Commissioner Danly is concurring with a
separate statement attached.
Kimberly D. Bose,
Secretary.
10 New England Power Generators Ass’n v. FERC, 707 F.3d 364, 370-371
(D.C. Cir. 2013).
Document Accession #: 20211118-3098 Filed Date: 11/18/2021
Exhibit No. 4 Case No. INT-G-23-04 Intermountain Gas Company Page 20 of 28
UNITED STATES OF AMERICA
FEDERAL ENERGY REGULATORY COMMISSION
Gas Transmission Northwest LLC Docket No. RP15-904-003
(Issued November 18, 2021)
DANLY, Commissioner, concurring:
I agree with the Commission’s decision to approve Gas Transmission Northwest
LLC’s Amended and Restated Stipulation and Agreement of Settlement (Settlement).1
As I stated in my dissent in Kinetica Deepwater Express, LLC, I suggest to anyone
participating in the natural gas industry that it might be prudent to be clearer in your
settlement agreements as to whether you are actually a party to that agreement.2 Though
I understand that defining “Settling Parties” as parties that “either support or do not
oppose”3 the Settlement is common in the industry, situations will almost certainly arise
in which an entity’s status as party or non-party to a settlement will be dispositive. This
will be even more important should the issue be presented to a body less indifferent to
fundamentals of contract law than this Commission.
For these reasons, I respectfully concur.
________________________
James P. Danly
Commissioner
1 Gas Transmission Nw. LLC, 177 FERC ¶ 61,110 (2021).
2 Kinetica Deepwater Express, LLC, 175 FERC ¶ 61,048 (2021) (Danly, Comm’r,
concurring in part and dissenting in part at P 10 n.12).
3 Settlement at Art. III(A) and App. A.
Document Accession #: 20211118-3098 Filed Date: 11/18/2021
Exhibit No. 4 Case No. INT-G-23-04 Intermountain Gas Company Page 21 of 28
Gas Transmission Northwest LLC PART 4.1
FERC Gas Tariff 4.1 -
-A FTS-1, LFS-
v.19.0.0
January 1, 2020 Accepted:
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) FUEL (d)
(Dth-MILE) (Dth) (Dth-MILE) (Dth-MILE)
Max. Min. Max. Min. Max. Min. Max. Min.
BASE 0.000362 0.000000 0.028612 0.000000 0.000016 0.000016 0.0050% 0.0000%
STF (e) (e) 0.000000 (e) 0.000000 0.000016 0.000016 0.0050% 0.0000%
EXTENSION CHARGES
MEDFORD
E-1 (f) 0.002511 0.000000 0.004223 0.000000 0.000026 0.000026 --- ---
E-2 (h) 0.002972 0.000000 --- --- 0.000000 0.000000 --- ---
(Diamond 1)
E-2 (h) 0.001166 0.000000 --- --- 0.000000 0.000000 --- ---
(Diamond 2)
COYOTE SPRINGS
E-3 (i) 0.001167 0.000000 0.001168 0.000000 0.000000 0.000000 --- ---
CARTY LATERAL
E-4 (p) --- --- 0.151492 0.000000 0.000000 0.000000 --- ---
OVERRUN CHARGE (j)
--- --- --- --- --- --- --- ---
SURCHARGES
ACA (k) --- --- --- --- (k) (k) --- ---
Exhibit No. 4 Case No. INT-G-23-04 Intermountain Gas Company Page 22 of 28
"
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OREGON
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KINGSGATE BORDER MS
SAGLE SALES MS
TUSCARORA MS
SPOKANE SUMARY MS
MADRAS MS
SOUTH HERMISTON MS
RATHDRUM GEN. MS
STANFIELD MS
PHOENIX / MEDFORD
MICA MS
KLAMATHEXPANSION MS
BEND MS
LA PINE MS
MOYIE SPRINGS MS
PRINEVILLE MS
PALOUSE MS
REDMOND MS
ATHOL MS
STEARNS MS
SCHWEITZER MS
CHEMULT MS
GILCHRIST MS
PRONGHORN MS
ROSALIA SALES
SAINT JOHN SALES
LACROSSE MS
SPANGLE MS
NORTH BEND MS
STANFIELD CITY MS
COYOTE SPRINGS II MS
CALPINE MS
DOVER BAY MS
KOSMOS FARMS MS
CSBRR MS
SANDPOINT MS
KLAMATH COGEN. MS
COYOTE V MS
BONNERS FERRY MS
COYOTE SPRINGS MS
TURQUOISE FLATS MS
LANCASTER POWER LLC
RATHDRUM CITY MS
WEST KLAMATHTAP MS
SOUTH BEND MS
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HARPOLD SALES
PACIFIC GAS & ELECTRIC PIPELINE
TC PIPELINE
RUBY PIPELINE
TUSCARORA PIPELINE
NORTHWEST PIPELINE
CALIFORNIA
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San JuanCounty
San Juan
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San JuanCounty
San JuanCounty
Klamath
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LatahCounty
ElmoreCounty
MarionCounty
PacificCounty
PacificCounty
OwyheeCounty
KittitasCounty
AdamsCountyWheelerCounty
Clatsop
County
ClallamCounty
HumboldtCounty
FranklinCounty
Idaho
County
PolkCounty
JacksonCounty
SnohomishCounty
SnohomishCounty
LincolnCounty
BoiseCounty
AsotinCounty
CrookCounty
ShastaCounty
Cowlitz
County
BakerCounty
UmatillaCounty
Jefferson
CountyLinn
County
SiskiyouCounty
WascoCounty
MasonCounty
MasonCounty
Douglas
County
Benton
County
King
County
King
County
BentonCounty
SkagitCounty SkagitCounty
WhatcomCounty
WhatcomCounty
WhatcomCounty
WhatcomCounty
LakeCounty
GemCounty
PendOreilleCounty
Harney
County
KlickitatCounty
YamhillCounty
ClarkCounty
LassenCounty
Grays HarborCounty
GraysHarborCounty
Canyon
County
Sherman
County
WhitmanCounty
SpokaneCounty
Valley
County
BonnerCounty
Hood RiverCounty
AdamsCounty
UnionCounty
LewisCounty
IslandCounty
IslandCounty
DouglasCounty
MorrowCounty
WahkiakumCounty
GilliamCounty
Benewah
County
OkanoganCounty
WashingtonCounty
PayetteCounty
ColumbiaCounty
KitsapCountyKitsap
County
GarfieldCounty
ElkoCounty
LewisCounty
SkamaniaCounty
MultnomahCounty
LaneCounty
Walla Walla
County
GrantCounty
ModocCounty
Grant
County
ColumbiaCounty
MalheurCounty
WashoeCounty
KootenaiCounty
YakimaCounty
PierceCounty
PierceCounty
PierceCounty
StevensCounty
Washington
County
BoundaryCounty
WallowaCounty
Nez PerceCounty
DeschutesCounty
AdaCounty
JeffersonCounty
JeffersonCounty
JeffersonCounty
ChelanCounty
ClackamasCounty
Ferry
County
³
GAS TRANSMISSION NORTHWEST LLC
SYSTEM MAP
MARCH 31, 2021
0 40 8020
Scale in Miles
This map supercedes FERC_GTN_2016.mxd R:\gis\16-Mapping\Tariff maps\Tariff map 2021\GTN\GTN_TARIFF_04062021.mxd
!'Meter Station
"Compressor Station
GTN
Location DRN Mile Post
Kingsgate 3498 0.00
Moyie Springs 198186 22.00
Bonners Ferry 3503 27.04
Schweitzer 159304 55.50
Sandpoint 3496 59.26
Dover Bay 634335 61.14
Sagle Sales 769368 65.22
Athol 160164 84.77
Rathdrum City 3539 97.64
Rathdrum Gen Tap 160138 97.64
Lancaster 314085 99.78
Chase Road Delivery 1389605 102.50
Spokane City 28203 108.29
Spokane Summary 28201 108.29
Mica 28204 121.15
Spangle 28205 134.18
Rosalia 28245 145.71
St. John 28246 158.89
Palouse 217745 172.07
Lacrosse 28247 182.79
Lyons Ferry 21747 206.50
Attalia 21750 252.71
Kosmos Farm 159305 271.66
Stanfield 18503 277.37
Stanfield City 18505 282.76
Calpine H.P.P.314578 282.88
South Hermiston 217744 289.83
CSBRR 198185 304.22
Coyote Springs 198184 304.23
Coyote Springs 2 314579 304.24
Coyote 5 217723 304.25
Carty 140177 319.50
Carty Generating Station 1401645 319.60
ThreeMile Road Dairy D 21748 319.70
ThreeMile Road Dairy R 21749 319.70
Madras 18430 410.16
Prineville 18432 426.80
Redmond 18402 438.30
Pronghorn Tap 360889 445.80
North Bend 233740 450.28
Bend 18403 454.51
South Bend 217724 457.50
Stearns 18404 469.19
Lapine 159307 483.90
Gilchrist 18437 500.97
Chemult 18440 519.44
Harpold Sales 1402105 599.23
Kingsley Field Tap 473654 599.26
Klamath CoGen 288499 599.27
West Klamath Tap 198183 599.28
Klamath Expansion 311972 599.29
Phoenix Medford 198182 599.30
Turquoise Flats 1049174 609.80
Tuscarora/GTN Interconnect 190094 609.80
Malin 1820 612.46
Exhibit No. 4 Case No. INT-G-23-04 Intermountain Gas Company Page 23 of 28
MOUNTAINWEST PIPELINE, LLC
(2 pages)
Exhibit No. 4 Case No. INT-G-23-04 Intermountain Gas Company Page 24 of 28
FEDERAL ENERGY REGULATORY COMMISSION
WASHINGTON, DC 20426
OFFICE OF ENERGY MARKET REGULATION
MountainWest Pipeline, LLC
Docket No. RP23-222-000
Issued: December 15, 2022
On November 30, 2022, MountainWest Pipeline, LLC filed a tariff record1 to
reflect a decrease in its Fuel Gas Reimbursement Percentage from 1.05% to 0.90%.
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, 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
1 MountainWest Pipeline, LLC, Tariffs, Statement of Rates, Statement of Rates
(21.0.0).
Exhibit No. 4 Case No. INT-G-23-04 Intermountain Gas Company Page 25 of 28
MountainWest Pipeline, LLC FERC Gas Tariff
Section Version:
On: November 30, 2022 Effective On:
STATEMENT OF RATES Base Rate Schedule/ Tariff Type of Charge Rate ($) (a) (b) PEAKING STORAGE Firm Peaking Storage Service - PKS Monthly Reservation Charge Maximum 4/ ........................................................................................................................... 2.87375 Minimum................................................................................................................................ 0.00000 Usage Charge Injection ................................................................................................................................ 0.03872 Withdrawal ............................................................................................................................. 0.03872 CLAY BASIN STORAGE Firm Storage Service - FSS Monthly Reservation Charge Deliverability Maximum 4/ ......................................................................................................................... 2.85338 Minimum .............................................................................................................................. 0.00000 Capacity Maximum ............................................................................................................................. 0.02378 Minimum .............................................................................................................................. 0.00000 Usage Charge Injection1/ ............................................................................................................................. 0.01049 Withdrawal ............................................................................................................................. 0.01781 Authorized Overrun Charge ..................................................................................................................... Maximum1/ ............................................................................................................................ 0.30315 Minimum1/ ............................................................................................................................. 0.01781 Interruptible Storage Service - ISS Usage Charge Inventory 5/ Maximum ............................................................................................................................. 0.05927 Minimum .............................................................................................................................. 0.00000 Injection1/ ............................................................................................................................. 0.01049 Withdrawal ............................................................................................................................. 0.01781 OPTIONAL VOLUMETRIC RELEASES / Peaking Storage Service - PKS Maximum 4/ ............................................................................................................................. 3.40890 Minimum ................................................................................................................................. 0.00000 Firm Storage Service - FSS Maximum 4/ ............................................................................................................................. 0.57068 Minimum ................................................................................................................................. 0.00000 Storage Usage Charges Applicable to Volumetric Releases 6/ Peaking Storage Service - PKS: ................................................................................................................. Injection .................................................................................................................................. 0.03872 Withdrawal ............................................................................................................................... 0.03872 Clay Basin Storage Service - FSS: Injection1/ ............................................................................................................................... 0.01049 Withdrawal ............................................................................................................................... 0.01781 PARK AND LOAN SERVICE - PAL1 Daily Charge Maximum ................................................................................................................................ 0.30315 Minimum ................................................................................................................................ 0.00000 Delivery Charge1/ ....................................................................................................................... 0.02830 FUEL REIMBURSEMENT - 2.0% (0.2% utility and 1.8% compressor fuel) for Rate Schedule PAL1
Exhibit No. 4 Case No. INT-G-23-04 Intermountain Gas Company Page 26 of 28
FEDERAL ENERGY REGULATORY COMMISSION
ANNUAL CHARGES UNIT CHARGE
(1 page)
Exhibit No. 4 Case No. INT-G-23-04 Intermountain Gas Company Page 27 of 28
Exhibit No. 4 Case No. INT-G-23-04 Intermountain Gas Company Page 28 of 28
EXHIBIT NOS. 5-13
CASE NO. INT-G-23-04
INTERMOUNTAIN GAS COMPANY
(9 pages)
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a
t
i
o
n
F
a
c
t
o
r
o
n
W
o
r
k
p
a
p
e
r
N
o
.
4
,
L
i
n
e
5
,
C
o
l
u
m
n
s
(
b
)
-
(
d
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(2
)
Se
e
W
o
r
k
p
a
p
e
r
N
o
.
1
,
P
a
g
e
1
(3
)
Se
e
W
o
r
k
p
a
p
e
r
N
o
.
1
,
P
a
g
e
2
(4
)
Se
e
W
o
r
k
p
a
p
e
r
N
o
.
2
,
P
a
g
e
1
(5
)
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e
W
o
r
k
p
a
p
e
r
N
o
.
2
,
P
a
g
e
2
(6
)
Pri
c
e
R
e
f
l
e
c
t
s
D
a
i
l
y
C
h
a
r
g
e
;
C
o
l
u
m
n
(
d
)
e
q
u
a
l
s
C
o
l
u
m
n
(
b
)
t
i
m
e
s
C
o
l
u
m
n
(
c
)
t
i
m
e
s
3
6
5
.
A
c
t
u
a
l
p
r
i
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s
i
n
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d
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6
d
e
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i
m
a
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s
.
(7
)
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c
e
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e
f
l
e
c
t
s
D
a
i
l
y
C
h
a
r
g
e
;
C
o
l
u
m
n
(
g
)
e
q
u
a
l
s
C
o
l
u
m
n
(
e
)
t
i
m
e
s
C
o
l
u
m
n
(
f
)
t
i
m
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s
3
6
6
.
A
c
t
u
a
l
p
r
i
c
e
s
i
n
c
l
u
d
e
6
d
e
c
i
m
a
l
s
.
(8
)
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e
W
o
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k
p
a
p
e
r
N
o
.
3
,
L
i
n
e
2
9
,
C
o
l
u
m
n
(
e
)
(9
)
Lin
e
2
2
C
o
l
u
m
n
(
f
)
m
i
n
u
s
C
o
l
u
m
n
(
c
)
t
i
m
e
s
L
i
n
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2
4
C
o
l
u
m
n
s
(
i
)
-
(
k
)
(1
0
)
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e
E
x
h
i
b
i
t
N
o
.
6
,
L
i
n
e
2
5
,
C
o
l
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m
n
s
(
e
)
-
(
g
)
(1
1
)
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e
E
x
h
i
b
i
t
N
o
.
7
,
L
i
n
e
7
,
C
o
l
u
m
n
s
(
b
)
-
(
d
)
Exhibit No. 5 Case No. INT-G-23-04 Intermountain Gas Company Page 1 of 1
IN
T
E
R
M
O
U
N
T
A
I
N
G
A
S
C
O
M
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A
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Y
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s
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r
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n
d
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t
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o
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e
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o
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I
N
T
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-
2
2
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0
4
An
n
u
a
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10
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1
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2
0
2
2
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n
u
a
l
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T
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G
-
2
3
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0
4
C
o
s
t
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f
G
a
s
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l
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r
s
(1
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Li
n
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Bi
l
l
i
n
g
D
e
t
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m
i
n
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t
s
Pr
i
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e
s
Co
s
t
No
.
De
s
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r
i
p
t
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o
n
IN
T
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-
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2
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0
4
IN
T
-
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-
2
2
-
0
4
IN
T
-
G
-
2
2
-
0
4
RS
GS
-
1
LV
-
1
(a
)
(b
)
(c
)
(d
)
(e
)
(f
)
(g
)
1
DE
M
A
N
D
C
H
A
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G
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S
:
2
Tr
a
n
s
p
o
r
t
a
t
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o
n
:
3
89
4
,
7
5
7
,
3
5
0
0.
0
3
9
4
7
$
35
,
3
1
7
,
6
2
2
$
24
,
1
3
4
,
6
5
0
$
10
,
6
1
9
,
7
6
2
$
56
3
,
2
1
0
$
4
N
W
P
T
F
-
1
R
e
s
e
r
v
a
t
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o
n
(
D
i
s
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)
37
6
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4
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9
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6
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0
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5
8
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5,9
4
9
,
0
9
5
4,
0
6
5
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3
7
4
1,
7
8
8
,
8
5
1
94
,
8
7
0
5
U
p
s
t
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a
m
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a
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t
y
(
F
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l
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)
92
1
,
6
9
0
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4
3
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0
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1
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1
10
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3
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8
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8
8
9
7,
0
5
8
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3
4
9
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1
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8
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5
16
4
,
7
1
5
6
U
p
s
t
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m
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a
p
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(
D
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45
2
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1
1
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6
5
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0.
0
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9,0
7
1
,
4
8
4
6,
1
9
9
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0
8
9
2,
7
2
7
,
7
3
2
14
4
,
6
6
3
7
St
o
r
a
g
e
:
8
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G
S
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2
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9
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e
m
a
n
d
30
3
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0.
0
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5
6
17
2
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9
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2
(2
)
11
8
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1
9
6
52
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0
0
8
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7
5
8
10
C
a
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0
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22
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2
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9
(2
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15
5
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6
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2
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6
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3
11
T
F
-
2
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e
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a
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10
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9
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3
42
6
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2
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2
29
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2
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8
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1
7
7
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7
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8
12
T
F
-
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R
e
d
e
l
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9
9
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0
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6
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2
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7
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5
13
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S
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14
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e
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0
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44
0
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23
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15
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a
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14
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53
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1
28
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1
16
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i
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0
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6
1,3
4
0
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2
3
4
91
5
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8
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2
40
2
,
9
9
9
21
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3
7
3
17
V
a
p
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a
t
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n
14
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0
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3
9
49
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9
4
8
34
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3
2
15
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0
1
9
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7
18
T
F
-
2
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e
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14
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7
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1
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3
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0
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9
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3
57
5
,
7
2
5
39
3
,
4
2
8
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1
1
6
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1
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19
T
F
-
2
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e
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14
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7
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0
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2
7
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8,3
8
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19
6
20
O
t
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e
r
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t
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a
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(3
)
1,
7
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9
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9
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7
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4
7
8
41
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2
3
3
21
To
t
a
l
F
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x
e
d
G
a
s
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o
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t
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h
a
r
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e
s
69
,
3
1
3
,
8
5
5
$
47
,
3
6
6
,
3
1
6
$
20
,
8
4
2
,
1
9
0
$
1,
1
0
5
,
3
4
9
$
22
E
s
t
i
m
a
t
e
d
S
a
l
e
s
V
o
l
u
m
e
s
(
1
0
/
1
/
2
3
-
9
/
3
0
/
2
4
)
29
7
,
7
7
1
,
7
5
9
14
3
,
6
4
2
,
5
3
9
14
,
7
0
7
,
0
0
0
23
F
i
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d
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t
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l
l
e
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t
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n
p
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h
e
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m
(
L
i
n
e
2
1
d
i
v
i
d
e
d
b
y
L
i
n
e
2
2
)
0.1
5
9
0
7
$
0.1
4
5
1
0
$
0.0
7
5
1
6
$
24
IN
T
-
G
-
2
2
-
0
4
F
i
x
e
d
C
o
s
t
C
o
l
l
e
c
t
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n
p
e
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h
e
r
m
0.1
6
3
6
4
0.1
5
9
9
0
0.0
8
7
1
0
25
Ad
j
u
s
t
m
e
n
t
t
o
F
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x
e
d
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o
s
t
C
o
l
l
e
c
t
i
o
n
(
L
i
n
e
2
3
m
i
n
u
s
L
i
n
e
2
4
)
(0
.
0
0
4
5
7
)
$
(0
.
0
1
4
8
0
)
$
(0
.
0
1
1
9
4
)
$
26
GA
S
T
R
A
N
S
P
O
R
T
A
T
I
O
N
C
O
S
T
C
A
L
C
U
L
A
T
I
O
N
:
27
A
d
j
u
s
t
e
d
F
i
x
e
d
C
o
s
t
C
o
l
l
e
c
t
i
o
n
P
e
r
T
h
e
r
m
(
L
i
n
e
2
3
)
0.1
5
9
0
7
$
0.1
4
5
1
0
$
0.0
7
5
1
6
$
28
In
c
r
e
m
e
n
t
a
l
F
i
x
e
d
C
o
s
t
C
o
l
l
e
c
t
i
o
n
(4
)
0.0
4
2
7
7
0.0
3
8
2
2
0.0
1
9
2
9
29
IN
T
-
G
-
2
3
-
0
4
G
a
s
T
r
a
n
s
p
o
r
t
a
t
i
o
n
C
o
s
t
(
L
i
n
e
s
2
7
t
h
r
o
u
g
h
2
8
)
0.2
0
1
8
4
$
0.1
8
3
3
2
$
0.0
9
4
4
5
$
(1
)
Se
e
A
l
l
o
c
a
t
i
o
n
F
a
c
t
o
r
o
n
W
o
r
k
p
a
p
e
r
N
o
.
4
,
L
i
n
e
5
,
C
o
l
u
m
n
s
(
b
)
-
(
d
)
(2
)
Pr
i
c
e
R
e
f
l
e
c
t
s
D
a
i
l
y
C
h
a
r
g
e
;
C
o
l
u
m
n
(
d
)
e
q
u
a
l
s
C
o
l
u
m
n
(
b
)
t
i
m
e
s
C
o
l
u
m
n
(
c
)
t
i
m
e
s
3
6
5
.
A
c
t
u
a
l
p
r
i
c
e
s
i
n
c
l
u
d
e
6
d
e
c
i
m
a
l
s
.
(3
)
Se
e
W
o
r
k
p
a
p
e
r
N
o
.
3
,
L
i
n
e
1
4
,
C
o
l
u
m
n
(
e
)
(4
)
Se
e
E
x
h
i
b
i
t
N
o
.
5
,
s
u
m
o
f
L
i
n
e
s
1
-
2
0
d
i
v
i
d
e
d
b
y
L
i
n
e
2
4
,
C
o
l
u
m
n
s
(
i
)
-
(
k
)
Exhibit No. 6 Case No. INT-G-23-04 Intermountain Gas Company Page 1 of 1
IN
T
E
R
M
O
U
N
T
A
I
N
G
A
S
C
O
M
P
A
N
Y
Su
m
m
a
r
y
o
f
P
r
o
p
o
s
e
d
T
e
m
p
o
r
a
r
y
S
u
r
c
h
a
r
g
e
s
(
C
r
e
d
i
t
s
)
Li
n
e
No
.
De
s
c
r
i
p
t
i
o
n
RS
GS
-
1
LV
-
1
T-
3
T-
4
(a
)
(b
)
(c
)
(d
)
(e
)
(f
)
1
(1
)
(0
.
0
1
3
7
5
)
$
(0
.
0
1
2
2
9
)
$
(0
.
0
0
6
2
0
)
$
-
$
-
$
2
Pr
o
p
o
s
e
d
T
e
m
p
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r
a
r
y
S
u
r
c
h
a
r
g
e
(
C
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e
d
i
t
)
-
F
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x
e
d
C
o
s
t
s
(2
)
(0
.
0
4
8
4
6
)
(0
.
0
5
0
7
6
)
(0
.
0
2
2
0
4
)
-
-
3
P
r
o
p
o
s
e
d
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m
p
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r
a
r
y
S
u
r
c
h
a
r
g
e
(
C
r
e
d
i
t
)
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V
a
r
i
a
b
l
e
C
o
s
t
s
0.
0
6
1
5
6
(3
)
0.
0
6
1
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Exhibit No. 7 Case No. INT-G-23-04 Intermountain Gas Company Page 1 of 1
IN
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Exhibit No. 8 Case No. INT-G-23-04 Intermountain Gas Company Page 1 of 1
IN
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Exhibit No. 9 Case No. INT-G-23-04 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 24,218,419$ (1)
3 Short-Term Interest Expense 3,212,406 (2)
4 Total Variable Costs 27,430,825$
5 Normalized Sales Volumes (1/1/22 - 12/31/22)440,589,194
6 Proposed Temporary Surcharge (Credit) - Variable Costs 0.06226$
7 Lost and Unaccounted For Gas Amounts Which Apply to RS and GS-1:
8 Lost and Unaccounted For Gas Amounts from INT-G-22-04 (Account 1910.2120)(911,923)$ (3)
9 Lost and Unaccounted For Gas Amortization (Account 1910.2130) 1,048,325 (4)
10 (Over)/Under Collection of Lost and Unaccounted For Gas from INT-G-22-04 136,402
11 Lost and Unaccounted For Gas INT-G-23-04 (432,866) (5)
12 Total Lost and Unaccounted For Gas Amounts Which Apply to RS and GS-1 (296,464)$
13 Normalized Sales Volumes (1/1/22 - 12/31/22)425,826,092
14 Proposed Temporary Surcharge (Credit) - Lost and Unaccounted For Gas Costs (0.00070)$
15 Lost and Unaccounted For Gas Amounts Which Apply to LV-1, T-3, and T-4:
16 Lost and Unaccounted For Gas Amounts from INT-G-22-04 (Account 1910.2120)(311,162)$ (6)
17 Lost and Unaccounted For Gas Amortization (Account 1910.2140) 333,795 (7)
18 (Over)/Under Collection of Lost and Unaccounted For Gas from INT-G-22-04 22,633
19 Lost and Unaccounted For Gas INT-G-23-04 (145,718) (8)
20 Total Lost and Unaccounted For Gas Amounts Which Apply to LV-1, T-3, and T-4 (123,085)$
21 Normalized Sales Volumes (1/1/22 - 12/31/22)399,061,477
22 Proposed Temporary Surcharge (Credit) - Lost and Unaccounted For Gas Costs (0.00031)$
23 Convert T-4 Lost and Unaccounted For Temporary from a Volumetric Rate to a Demand Rate:
24 Proposed Temporary Surcharge (Credit) - Lost and Unaccounted For Gas Costs (Line 22)(0.00031)$
25 Normalized T-4 Sales Volumes (1/1/22 - 12/31/22)340,008,634
26 Total Temporary Collected (105,403)$
27 Billing Determinants Demand Volumes 17,962,920
28 Proposed Temporary Surcharge (Credit) - Lost and Unaccounted For T-4 Demand Rate (Line 26 Divided by Line 27)(0.00587)$
(1)See Workpaper No. 5, Page 1, Line 16, Column (f)
(2)See Workpaper No. 7, Line 8, Column (b)
(3)See Workpaper No. 5, Page 2, Line 2, Column (c)
(4)See Workpaper No. 5, Page 2, Line 8, Column (d)
(5)See Workpaper No. 5, Page 2, Line 30, Column (d), plus Line 36, Column (e)
(6)See Workpaper No. 5, Page 2, Line 3, Column (c)
(7)See Workpaper No. 5, Page 2, Line 14, Column (d)
(8)See Workpaper No. 5, Page 2, Line 31, Column (d), plus Line 40, Column (e)
Exhibit No. 10 Case No. INT-G-23-04 Intermountain Gas Company Page 1 of 1
IN
T
E
R
M
O
U
N
T
A
I
N
G
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-
1
LV
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1
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4
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)
(b
)
(c
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(d
)
(e
)
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41
,
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1
5
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0
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,
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3
$
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Exhibit No. 11 Case No. INT-G-23-04 Intermountain Gas Company Page 1 of 1
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Exhibit No. 12 Case No. INT-G-23-04 Intermountain Gas Company Page 1 of 1
Line
No.Description
Deferred Account
2540.38107
Estimated Sept. 30,
2023 Balance (1)RS
(a)(b)(c)
1 Energy Efficiency Credit Approved in Prior PGA (Account 2540.38107)(4,850,000)$ (4,850,000)$
2 Amortization of Energy Efficiency Credit Approved in Prior PGA 5,536,777 5,536,777
3 Total Residential Energy Efficiency Funds - Over-Refund 686,777$ 686,777$
4 Normalized Sales Volumes (1/1/22 - 12/31/22)284,776,158 (2)
5 Proposed Per Therm Price Adjustment 0.00241$
(1)See Workpaper No. 5, Page 7
(2)
INTERMOUNTAIN GAS COMPANY
Residential Energy Efficiency Funds
Does not include volumes for the IS-R rate class because the Energy Efficiency Charge is not
applicable to Rate Schedule IS-R.
Exhibit No. 13 Case No. INT-G-23-04 Intermountain Gas Company Page 1 of 1
NEWS RELEASE
and
CUSTOMER NOTICE
CASE NO. INT-G-23-04
INTERMOUNTAIN GAS COMPANY
(2 pages)
Intermountain Gas Company files decrease in prices as part of PGA filing
BOISE, ID – August 14, 2023 – Intermountain Gas Company filed its annual purchased gas cost adjustment
(PGA) application with the Idaho Public Utilities Commission to decrease its prices by an average of 20.6% or
approximately $86.9 million. The PGA application is filed each year to ensure the costs Intermountain incurs on
behalf of its customers are reflected in its sales prices. If approved, the decrease would be effective Oct. 1,
2023.
The primary reason for the proposed PGA decrease is a significant decrease in estimated gas commodity costs
for the upcoming year when compared to Intermountain’s recently approved interim PGA. If approved, a
typical residential customer would see a monthly decrease of $11.96, or 19.3% based on average weather and
usage. Commercial customers, on average, would see a decrease of $72.88, or 24.4%, per month. The cost of
natural gas is a straight passthrough to customers; Intermountain does not earn a profit on the cost of natural
gas.
Intermountain Gas urges all customers to use energy wisely. For more information about the company’s energy
efficiency program and available rebates for installing high efficiency equipment, visit
www.intgas.com/saveenergy. Conservation tips, information on government payment energy assistance and
programs to help consumers level out their energy bills over the year can be found on the company’s website
www.intgas.com.
The request is a proposal and is subject to public review and approval by the PUC. A copy of the applications
are available for review at the commission, its homepage www.puc.idaho.gov, as well as the company’s website
www.intgas.com. Written comments regarding the applications may be filed with the commission. Customers
may also subscribe to the commission’s RSS feed to review periodic updates via email.
Intermountain Gas Company is a natural gas distribution company serving approximately 412,500 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 MidCap 400 and the S&P High-Yield Dividend Aristocrats
indices that provides essential products and services through its regulated energy delivery and construction
services businesses. For more information about MDU Resources, see the company’s website at www.mdu.com.
For more information about Intermountain, visit www.intgas.com.
Media Contact: Mark Hanson at 701-530-1093 or mark.hanson@mduresources.com.
NEWS RELEASE
CUSTOMER NOTICE
Intermountain Gas Company files decrease in prices as part of PGA filing
BOISE, ID-August 14, 2023 Intermountain Gas Company filed its annual purchased gas cost adjustment (PGA) application with
the Idaho Public Utilities Commission to decrease its prices by an average of 20.6% or approximately $86.9 million. The PGA
application is filed each year to ensure the costs Intermountain incurs on behalf of its customers are reflected in its sales prices. If
approved, the decrease would be effective Oct. 1, 2023.
The primary reason for the proposed PGA decrease is a significant decrease in estimated gas commodity costs for the upcoming
year when compared to Intermountain’s recently approved interim PGA. If approved, a typical residential customer would see a
monthly decrease of $11.96, or 19.3% based on average weather and usage. Commercial customers, on average, would see a
decrease of $72.88, or 24.4%, per month. The cost of natural gas is a straight passthrough to customers; Intermountain does not
earn a profit on the cost of natural gas.
Intermountain Gas urges all customers to use energy wisely. For more information about the company’s energy efficiency
program and available rebates for installing high efficiency equipment, visit www.intgas.com/saveenergy. Conservation tips,
information on 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. (continued on reverse side)
08/15/23
www.intgas.com
The request is a proposal and is subject to public review and approval by the PUC. A copy of the applications are available for
review at the commission, its homepage www.puc.idaho.gov, as well as the company’s website www.intgas.com. Written comments
regarding the applications may be filed with the commission. Customers may also subscribe to the commission’s RSS feed to review
periodic updates via email.
Intermountain Gas Company is a natural gas distribution company serving approximately 412,500 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 MidCap 400 and the S&P High-Yield Dividend Aristocrats indices that provides essential products and services through
its regulated energy delivery and construction services businesses. For more information about MDU Resources, see the company’s
website at www.mdu.com.
For more information about Intermountain Gas Company, visit www.intgas.com.
CUSTOMER SERVICE: 800-548-3679
MON-FRI 7:30 a.m. - 6:30 p.m.
WORKPAPER NOS. 1-7
CASE NO. INT-G-23-04
INTERMOUNTAIN GAS COMPANY
(14 pages)
INTERMOUNTAIN GAS COMPANY
Summary of Northwest Pipeline TF-1 Full Rate Demand Costs
Line INT-G-22-04 INT-G-22-04 INT-G-22-04
No.Transportation Annual Therms Prices(1)Annual Cost(2)
(a)(b)(c)(d)
1 TF-1 Reservation Contract #1 412,537,600 0.039876$ 16,450,268$
2 TF-1 Reservation Contract #2 25,550,000 0.040789 1,042,155
3 TF-1 Reservation Contract #3 73,000,000 0.039033 2,849,412
4 TF-1 Reservation Contract #4 26,429,650 0.039033 1,031,629
5 TF-1 Reservation Contract #5 32,850,000 0.039033 1,282,233
6 TF-1 Reservation Contract #6 36,500,000 0.039033 1,424,702
7 TF-1 Reservation Contract #7 87,600,000 0.039033 3,419,296
8 TF-1 Reservation Contract #8 18,250,000 0.039033 712,353
9 TF-1 Reservation Contract #9 104,495,850 0.039033 4,078,784
10 TF-1 Reservation Contract #10 26,462,500 0.039033 1,032,914
11 TF-1 Reservation Contract #11 51,081,750 0.039033 1,993,876
12 Total 894,757,350 35,317,622$
Line INT-G-23-04 INT-G-23-04 INT-G-23-04
No.Transportation Annual Therms Prices(1)Annual Cost(2)
(a)(b)(c)(d)
13 TF-1 Reservation Contract #1 413,667,840 0.038016$ 15,726,192$
14 TF-1 Reservation Contract #2 25,620,000 0.037174 952,390
15 TF-1 Reservation Contract #3 73,200,000 0.037174 2,721,113
16 TF-1 Reservation Contract #4 26,502,060 0.037174 985,177
17 TF-1 Reservation Contract #5 32,940,000 0.037174 1,224,503
18 TF-1 Reservation Contract #6 36,600,000 0.037174 1,360,556
19 TF-1 Reservation Contract #7 87,840,000 0.037174 3,265,335
20 TF-1 Reservation Contract #8 18,300,000 0.037174 680,278
21 TF-1 Reservation Contract #9 104,782,140 0.037174 3,895,134
22 TF-1 Reservation Contract #10 26,535,000 0.037174 986,403
23 TF-1 Reservation Contract #11 51,221,700 0.037174 1,904,099
24 Total 897,208,740 33,701,180$
25 Total Annual Cost Difference (Line 24 minus Line 12)(1,616,442)$ (3)
(1)Column (d) divided by Column (b), rounded to 6 decimal places
(2) Sum of the calculated monthly costs
(3) See Exhibit No. 5, Line 3, Column (h)
Workpaper No. 1 Case No. INT-G-23-04 Intermountain Gas Company Page 1 of 2
INTERMOUNTAIN GAS COMPANY
Summary of Northwest Pipeline TF-1 Discounted Demand Costs
Line INT-G-22-04 INT-G-22-04 INT-G-22-04
No.Transportation Annual Therms Prices(1)Annual Cost(2)
(a)(b)(c)(d)
1 TF-1 Reservation Contract #1 18,250,000 0.025372$ 463,030$
2 TF-1 Reservation Contract #2 58,400,000 0.025371 1,481,690
3 TF-1 Reservation Contract #3 36,500,000 0.023420 854,818
4 TF-1 Reservation Contract #4 32,850,000 0.008500 279,225
5 TF-1 Reservation Contract #5 11,497,500 0.035130 403,904
6 TF-1 Reservation Contract #6 4,530,000 0.031227 141,457
7 TF-1 Reservation Contract #7 63,688,850 0.009758 621,492
8 TF-1 Reservation Contract #8 59,513,250 0.013662 813,041
9 TF-1 Reservation Contract #9 91,250,000 0.009758 890,438
10 Total 376,479,600 5,949,095$
Line INT-G-23-04 INT-G-23-04 INT-G-23-04
No.Transportation Annual Therms Prices(1)Annual Cost(2)
(a)(b)(c)(d)
11 TF-1 Reservation Contract #1 9,150,000 0.024180$ 221,243$
12 TF-1 Reservation Contract #2 67,710,000 0.024161 1,635,916
13 TF-1 Reservation Contract #3 36,600,000 0.022304 816,332
14 TF-1 Reservation Contract #4 11,529,000 0.033456 385,718
15 TF-1 Reservation Contract #5 4,560,000 0.029751 135,665
16 TF-1 Reservation Contract #6 63,863,340 0.009293 593,508
17 TF-1 Reservation Contract #7 59,676,300 0.013011 776,434
18 TF-1 Reservation Contract #8 91,500,000 0.009293 850,349
19 Total 344,588,640 5,415,165$
20 Total Annual Cost Difference (Line 19 minus Line 10)(533,930)$ (3)
(1)Column (d) divided by Column (b), rounded to 6 decimal places
(2)Sum of the calculated monthly costs
(3)See Exhibit No. 5, Line 4, Column (h)
Workpaper No. 1 Case No. INT-G-23-04 Intermountain Gas Company Page 2 of 2
INTERMOUNTAIN GAS COMPANY
Summary of Upstream Capacity Full Rate Demand Costs
Line INT-G-22-04 INT-G-22-04 INT-G-22-04
No.Transportation Annual Therms Prices(1)Annual Cost(2)
(a)(b)(c)(d)
1 Upstream Agreement #1 25,933,250 0.009103$ 236,076$
2 Upstream Agreement #2 351,503,260 0.009109 3,201,859
3 Upstream Agreement #3 26,962,550 0.009103 245,448
4 Upstream Agreement #4 37,244,600 0.009103 339,048
5 Upstream Agreement #5 26,126,700 0.013496 352,607
6 Upstream Agreement #6 128,898,520 0.013496 1,739,619
7 Upstream Agreement #7 54,750,000 0.013496 738,903
8 Upstream Agreement #8 62,050,000 0.013496 837,425
9 Upstream Agreement #9 133,590,000 0.013496 1,802,933
10 Upstream Agreement #10 36,974,500 0.013496 499,003
11 Upstream Agreement #11 37,657,050 0.022200 835,968
12 Total 921,690,430 10,828,889
Total Annual Cost Including Capacity Release Credits
Line INT-G-23-04 INT-G-23-04 INT-G-23-04
No.Transportation Annual Therms Prices(1)Annual Cost(2)
(a)(b)(c)(d)
15 Upstream Agreement #1 24,082,210 0.010062$ 242,316$
16 Upstream Agreement #2 352,589,060 0.009321 3,286,545
17 Upstream Agreement #3 27,036,420 0.009319 251,940
18 Upstream Agreement #4 939,156 0.093186 87,516 (3)
19 Upstream Agreement #5 2,845,467 0.093184 265,152 (3)
20 Upstream Agreement #6 27,300,155 0.093323 2,547,743 (4)
21 Upstream Agreement #7 37,346,640 0.009318 348,012
22 Upstream Agreement #8 26,198,280 0.013496 353,568
23 Upstream Agreement #9 129,355,380 0.013496 1,745,760
24 Upstream Agreement #10 54,900,000 0.013496 740,916
25 Upstream Agreement #11 62,220,000 0.013496 839,707
26 Upstream Agreement #12 133,956,000 0.013496 1,807,842
27 Upstream Agreement #13 915,000 0.255938 234,183 (3)
28 Upstream Agreement #14 2,764,947 0.255939 707,658 (3)
29 Upstream Agreement #15 26,465,000 0.285938 7,567,348 (4)
30 Upstream Agreement #16 37,075,800 0.013496 500,369
31 Upstream Agreement #17 954,528 0.234883 224,202 (3)
32 Upstream Agreement #18 2,829,363 0.234880 664,560 (3)
33 Upstream Agreement #19 28,000,305 0.235230 6,586,514 (4)
34 Upstream Agreement #20 37,760,220 0.023488 886,908
35 Total 1,015,533,931 29,888,759
Total Annual Cost Including Capacity Release Credits
38 Total Annual Cost Difference (Line 37 minus Line 14)19,059,870$ (5)
(1) Column (d) divided by Column (b), rounded to 6 decimal places
(2) Sum of the calculated monthly costs
(3)This contract and its monthly costs will begin April 1, 2024
(4)This contract and its montly costs are anticipated to begin November 1, 2023
(5)See Exhibit No. 5, Line 5, Column (h)
Workpaper No. 2 Case No. INT-G-23-04 Intermountain Gas Company Page 1 of 2
INTERMOUNTAIN GAS COMPANY
Summary of Upstream Capacity Discounted Demand Costs
Line INT-G-22-04 INT-G-22-04 INT-G-22-04
No.Transportation Annual Therms Prices(1)Annual Cost(2)
(a)(b)(c)(d)
1 Upstream Agreement #1 452,311,650 0.020056$ 9,071,484$
2 Total 452,311,650 9,071,484$
Line INT-G-23-04 INT-G-23-04 INT-G-23-04
No.Transportation Annual Therms Prices(1)Annual Cost(2)
(a)(b)(c)(d)
3 Upstream Agreement #1 453,550,860 0.021212$ 9,620,616$
4 Total 453,550,860 9,620,616$
5 Total Annual Cost Difference (Line 4 minus Line 2)549,132$ (3)
(1) 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. 2 Case No. INT-G-23-04 Intermountain Gas Company Page 2 of 2
INTERMOUNTAIN GAS COMPANY
Summary of Other Storage Facility Costs
INT-G-22-04
Line Monthly INT-G-22-04 INT-G-22-04 INT-G-22-04
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 (1)0.285338 63,311 759,732
4 Clay Basin III Reservation 213,010 (1)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 66,000$
11 Variable Transportation 18,000
12 Total Rexburg LNG Facility Costs 84,000$
13 Storage Demand Charge Credit (2,300,000)$
14 Total Costs Including Storage Credit 2,585,620$
INT-G-23-04
Line Monthly INT-G-23-04 INT-G-23-04 INT-G-23-04
(a)(b)(c)(d)(e)
15 Clay Basin Costs:
16 Clay Basin I Reservation 266,250 (1)0.285338$ 75,971$ 911,652$
17 Clay Basin II Reservation 221,880 (1)0.285338 63,311 759,732
18 Clay Basin III Reservation 213,010 (1)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 66,000$
25 Variable Transportation 18,000
26 Total Rexburg LNG Facility Costs 84,000$
27 Estimated Storage Demand Charge Credit (2,300,000)$
Total Costs Including Storage Credit
29 Total Annual Cost Difference (Line 28 minus Line 14)-$ (3)
(1) Charge Based on Maximum Daily Withdrawal
(2)Charge Based on Maximum Contractual Capacity
(3) See Exhibit No. 5, Line 20, Column (h)
Workpaper No. 3 Case No. INT-G-23-04 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
1
2 Peak Demand Per Customer 9.12 42.43
3 January 2023 Actual Customers 374,976 35,465
4 INT-G-23-04 Peak Demand Therms (Line 2 times Line 3)3,419,781 1,504,780 79,805 (1)
5 Percent of Total 68.3360%30.0693%1.5947%N/A N/A 100.00%
6 INT-G-23-04 LNG Sales Credit Demand Allocators:
7 Peak Demand Per Customer 9.12 42.43
9 INT-G-23-04 Peak Demand Therms (Line 7 times Line 8)3,419,781 1,504,780 79,805 (1)1,496,910 (1)6,501,276
10 Percent of Total 52.6017%23.1459%1.2275%N/A 23.0249%100.00%
11 Allocation of Base Rate Revenues to RS and GS-1 Rate Classes:
12 Order No. 35836 Approved Base Rate Revenues 73,360,477$ 26,811,471$ 100,171,948$
13 Percent of Total 73.2346%26.7654%100.00%
(1) Contract Demand
Workpaper No. 4 Case No. INT-G-23-04 Intermountain Gas Company Page 1 of 1
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Workpaper No. 5 Case No. INT-G-23-04 Intermountain Gas Company Page 2 of 6
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Workpaper No. 5 Case No. INT-G-23-04 Intermountain Gas Company Page 3 of 6
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Workpaper No. 5 Case No. INT-G-23-04 Intermountain Gas Company Page 4 of 6
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Workpaper No. 5 Case No. INT-G-23-04 Intermountain Gas Company Page 5 of 6
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Workpaper No. 5 Case No. INT-G-23-04 Intermountain Gas Company Page 6 of 6
INTERMOUNTAIN GAS COMPANY
Lost and Unaccounted for Gas
(Volumes in Therms)
Line
No.Description Oct 2019- Sep 2020 Oct 2020 - Sept 2021 Oct 2021 - Sept 2022
(a)(b)(c)(d)
1 Core Customer Purchased Gas 394,224,154 403,730,817 429,712,484
2 Transportation Customer Gas 363,513,905 368,193,748 372,687,753
3 LNG Storage Withdrawals 1,455,818 4,623,368 4,583,559
4 Under Deliveries of Gas from Pipeline (Draft)568,080 10,150 -
5 Total Deliveries to System 759,761,957 776,558,083 806,983,796
6 Core Customer Billed Gas 400,017,998 409,747,004 439,666,208
7 (3,731,987) 634,162 (8,262,099)
8 Transportation Customer Billed Gas 363,513,905 368,193,748 372,687,753
9 Company Use Gas 318,139 182,923 474,937
10 LNG Storage Injections 1,086,497 3,068,540 2,110,199
11 Line Breaks - Found Gas 134,723 132,070 988,790
12 Other Found Gas 18,977 - -
13 Over Deliveries of Gas from Pipeline (Pack)- - 914,530
14 Total Deliveries to Customers 761,358,252 781,958,447 808,580,318
15 Lost/(Found) Gas (Line 5 minus 14)(1,596,295) (5,400,364) (1,596,522)
16 Average Purchase WACOG 0.21239$ 0.22682$ 0.31795$
17 Cost of Lost/(Found) Gas (Line 15 times Line 16)(339,037)$ (1,224,911)$ (507,614)$
18 Lost Gas $/Therm (Line 17 divided by Line 5)(0.00045)$ (0.00158)$ (0.00063)$
19 Lost/(Found) Gas (Line 15)(1,596,295) (5,400,364) (1,596,522)
20 Lost/(Found) Gas Therms Deferred 745,782 - -
21 Lost/(Found) Gas Adjustment (Line 19 minus Line 20)(2,342,077) (5,400,364) (1,596,522)
22 Actual Lost Gas Rate (Line 15 divided by Line 5)-0.2101%-0.6954%-0.1978%
23 3-Year Average Lost Gas Rate -0.1193%(1)-0.3617%(2)-0.3678%(3)
(1) See Case No. INT-G-21-04
(2) See Case No. INT-G-22-04
(3) Current PGA 3-Year Average
Workpaper No. 6 Case No. INT-G-23-04 Intermountain Gas Company Page 1 of 1
Line
No. Description Amount
(a) (b)
1 Accounts 4310.1111, 4310.3111 and 4190.1331 Short-Term Interest Expense:
2 Short-Term Interest Expense for Gas Commodity Costs in Accts 4310.1111 from January to June 2023 3,013,264$
3 Estimated Short-Term Interest Expense for Gas Commodity Costs from July through September 2023 768,049
4 Total Estimated Short-Term Interest Expense for Gas Commodity Costs from January through September 2023 3,781,313
5 Less: PGA Interest on Deferral Balances in Account 4310.3111 from January to June 2023 (183,575)
6 Less: Estimated PGA Interest on Deferral Balances from July through September 2023 (2,112)
7 Less: Interest Income in Account 4190.1331 from January to April 2023 (383,220)
8 Net Estimated Short-Term Interest Expense 3,212,406$
INTERMOUNTAIN GAS COMPANY
Short-Term Interest Expense
Workpaper No. 7 Case No. INT-G-23-04 Intermountain Gas Company Page 1 of 1