20120810Application and Exhibits.pdf

qZ612 Aug 10 Mi to: 2'
INTERMOUNTAIN GAS COMPAN SON
CASE NO. INT-G-12-01
APPLICATION
EXHIBITS
In the Matter of the Application of INTERMOUNTAIN GAS COMPANY
for Authority to Decrease Its Prices on October 1, 2012
(October 1, 2012 Purchased Gas Cost Adjustment Filing)
Stephen R. Thomas, ISB 2326 RECEIVED
MOFFATT THOMAS BARRETT ROCK & FIELDS, CHTD.
101 S. Capitol Boulevard, Suite 1000 202 AUG 10 AM 10: 2
Boise, Idaho 83702
Telephone: [phone] UTILITIES COMMISSION
Attorneys for Intermountain Gas Company
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
In the Matter of the Application of Case No. INT-G-12-0l
INTERMOUNTAIN GAS COMPANY APPLICATION
for Authority to Decrease Its Prices
Intermountain Gas Company ("Intermountain" or "Company"), a subsidiary of MDU
Resources Group, Inc. with general offices located at 555 South Cole Road, Boise, Idaho, hereby
requests authority, pursuant to Idaho Code Sections 61-307 and 61-622, to place into effect October
1, 2012 new rate schedules which will decrease its annualized revenues by $6.0 million, pursuant to
the Rules of Procedure of the Idaho Public Utilities Commission ("Commission"). Additionally,
Intermountain seeks to refund $11.9 million of variable deferred credits in a one-time bill credit.
Because of changes in Intermountain' s gas related costs, as described more fully in this Application,
Intermountain's earnings will not be decreased as a result of the proposed decrease in prices and
revenues. Intermountain's current rate schedules showing proposed changes are attached hereto as
Exhibit No. 1 and are incorporated herein by reference. Intermountain's proposed rate schedules are
attached hereto as Exhibit No. 2 and are incorporated herein by reference.
Communications in reference to this Application should be addressed to:
Scott Madison
Vice President & Chief Accounting Officer
Intermountain Gas Company
Post Office Box 7608
Boise, ID 83707
and
Stephen R. Thomas, ISB 2326
MOFFATT THOMAS BARRETT ROCK & FIELDS, CHTD.
101 S. Capitol Boulevard, Suite 1000
Boise, Idaho 83702
In support of this Application, Intermountain does allege and state as follows:
APPLICATION -2
I.
Intermountain is a gas utility, subject to the jurisdiction of the Idaho Public Utilities
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 - Chubbuck, Inkom, Lava Hot Springs, MeCammon, and Pocatello;
Bear Lake County - Georgetown, and Montpelier;
Bingham County - Aberdeen, Basalt, Blackfoot, Firth, Fort Hall, Moreland/Riverside, and Shelley;
Blame 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, Conda, Grace, and Soda Springs;
Cassia County - Burley, Declo, Malta, and Raft River;
Elmore County - Glenns Ferry, Hammett, and Mountain Home;
Fremont County - Parker, and St. Anthony;
Gem County - Emmett;
Gooding County - Gooding, and Wendell;
Jefferson County - Lewisville, Menan, Rigby, and Ririe;
Jerome County - Jerome;
Lincoln County - Shoshone;
Madison County - Rexburg, and Sugar City;
Minidoka County - Heybum, Paul, and Rupert;
Owyhee County - Bruneau, and Homedale;
Payette County - Fruitland, New Plymouth, and Payette;
Power County - American Falls;
Twin Falls County - Buhl, Filer, Hansen, Kimberly, Murtaugh, and Twin Falls;
Washington County - Weiser.
Intermountain's properties in these locations consist of transmission pipelines, a liquefied
natural gas storage facility, distribution mains, services, meters and regulators, and general plant and
equipment.
I.!
Intermountain seeks with this Application to pass through to each of its customer classes
changes in gas related costs resulting from: 1) an increase in costs billed Intermountain from
Northwest Pipeline GP ("Northwest" or "Northwest Pipeline") reflecting a January 1, 2013 price
increase and the purchase of additional Northwest capacity, 2) a decrease in Intermountain's
Weighted Average Cost of Gas, or "WACOG", 3) an updated customer allocation of gas related
APPLICATION -3
costs pursuant to the Company's Purchased Gas Cost Adjustment ("PGA") provision, 4) the
inclusion of temporary surcharges and credits for one year relating to natural gas purchases and
interstate transportation costs from Intermountain's deferred gas cost accounts, and 5) benefits
resulting from Intermountain's management of its storage and firm capacity rights on various
pipeline systems. Intermountain also seeks with this Application to eliminate the temporary
surcharges and credits included in its current prices during the past 12 months, pursuant to Order
No. 32372 per Case No. INT-G-11-01. The above changes would result in an overall price decrease
to Intermountain's customers.
These price changes are applicable to service rendered under rate schedules affected by and
subject to Intermountain's Purchased Gas Cost Adjustment ("PGA"), initially approved by this
Commission in Order No. 26109, Case No. INT-G-95-1, and additionally approved through
subsequent proceedings.
Exhibit No. 3 contains pertinent excerpts from applicable pipeline tariffs. Exhibit No. 4
summarizes the price changes in: 1) Intermountain' s base rate gas costs, 2) its rate class allocation,
and 3) adjusting temporary surcharges or credits flowing through to Intermountain's direct sales
customers. Exhibit Nos. 3 and 4 are attached hereto and incorporated herein by reference.
III.
The current prices of Intermountain are those approved by this Commission in Order
No. 32372, Case No. INT-G-1 1-01 and Order No. 32450, Case No. 1NT-G-1 1-03.
Iv.
Intermountain's proposed prices incorporate all changes in costs relating to the
Company's firm interstate transportation capacity including, but not limited to, any price changes
or projected cost adjustments implemented by the Company's pipeline suppliers as well as any
volumetric adjustments in contracted transportation agreements which have occurred since
Intermountain's PGA filing in Case No. INT-G-11-01.
Northwest Pipeline and its shippers settled Northwest's recent rate case filing resulting in
an approximate 9% price increase effective January 1, 2013 (see Exhibit No. 3 for Northwest's
January 1, 2013 pro forma prices incorporated in this filing). Additionally, certain existing
Northwest capacity contracts expiring before 2015 necessitated the addition of incremental
capacity to ensure future peak day deliverability.
APPLICATION -4
Intermountain continues to effectively manage its natural gas storage assets at
Northwest's Jackson Prairie and Questar Pipeline's Clay Basin storage facilities. Supporting
documents relating to Line 19 of Exhibit No. 4, include $2.7 million in savings from
Intermountain's management of these storage assets.
Exhibit No. 4, Lines 1 through 19, details the proposed changes in Intermountain's prices
resulting from adjustments to the cost of Northwest Pipeline interstate capacity, upstream
pipeline capacity, and Intermountain' s storage facility costs from its various suppliers.
LIP
The WACOG reflected in Intermountain's proposed prices is $0.33489 per therm, as shown
on Exhibit No. 4, Line 21, Col. (f). This compares to $0.41812 per therm currently included in the
Company's tariffs.
Natural gas prices have continued to fall since the previous filing. Current deliverable shale
gas reserves in North America are more significant than originally anticipated and are currently well
outpacing any demand increases in the near term. This robust supply has pushed storage balances
to record levels. The combination of ample natural gas supplies and record storage levels has kept
the near term prices for natural gas low.
Additionally, the proposed WACOG includes benefits to Intermountain's customers
generated by the Company's management of its significant natural gas storage assets. Because gas
added to storage is procured during the summer season when prices are typically lower than during
the winter, the cost of Intermountain's storage gas is normally less than what could be obtained on
the open market in winter months. Additionally, in an effort to further stabilize the prices paid by
our customers during the upcoming winter period, Intermountain has entered into various fixed
price agreements to lock-in the price for significant portions of its underground storage and other
winter "flowing" supplies.
Intermountain believes that the WACOG proposed in this Application, subject to the effect
of actual supply and demand and based on current market conditions, provides today's most
reasonable forecast of gas costs for the 2012-2013 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 customer's ability to
APPLICATION -5
make informed and appropriate energy use decisions. The Company is committed to alert
customers to impending price changes before their winter natural gas usage occurs. By employing
the use of customer mailings, the Company's website, and various media resources, Intermountain
will continue to educate its customers regarding the wise and efficient use of natural gas, billing
options available to help manage their energy budget, and pending natural gas price changes.
VI.
Pursuant to Case No. 1NT-G-1l-01, Intermountain included temporary surcharges and
credits in its October 1, 2011 prices for the principal reason of collecting or passing back to its
customers deferred gas cost charges and benefits, as outlined in Case No. 1NT-G-11-01. Line 26 of
Exhibit No. 4 reflects the elimination of these temporary surcharges and credits.
VII.
Intermountain's PGA tariff includes provisions whereby Intermountain's proposed prices
will be adjusted for updated customer class sales volumes and purchased gas cost allocations,
pursuant to the Company's approved cost of service methodology. Intermountain's proposed prices
include a fixed cost collection adjustment pursuant to these PGA provisions, as outlined on Exhibit
No. 5, Line 24. The price impact of this adjustment is included on Exhibit No. 4, Line No. 27. The
Fixed Cost Collection Rate resulting from the adjustment plus the annual difference in demand
charges from Exhibit No. 4, Lines 1 - 19, Col. (h) is shown on Exhibit No. 5, Line 28. Exhibit No.
5 is attached hereto and incorporated herein by reference.
VIII.
Intermountain proposes to pass through to its customers the benefits that will be generated
from the management of its transportation capacity totaling $3.7 million as outlined on Exhibit No.
7. These benefits include credits from a segmented release of a portion of Intermountain's firm
capacity rights on Northwest Pipeline and other non-segmented capacity releases. Intermountain
proposes to pass back these credit amounts via the per therm credits, as detailed on Exhibit No. 7
and included on Exhibit No. 6, Line 1. Exhibit Nos. 6 and 7 are attached hereto and incorporated
herein by reference.
APPLICATION -6
Ix.
Intermountain proposes to allocate deferred gas costs from its Account No. 186 balance to
its customers through temporary price adjustments to be effective during the 12-month period
ending September 30, 2013, as follows:
1)Intermountain has deferred fixed gas costs in its Account No. 186. The credit amount
shown on Exhibit No. 8, Line 8, Col. (b) of $4.8 million is attributable to a true-up of the collection
of interstate pipeline capacity costs, the true-up of expense issues previously ruled on by this
Commission, and mitigating capacity release credits generated from the incremental release of
Intermountain's pipeline capacity. Intermountain proposes to pass back these balances via the per
therm credits, as detailed on Exhibit No. 8 and included on Exhibit No. 6, Line 2. Exhibit No. 8 is
attached hereto and incorporated herein by reference.
2)Intermountain has also deferred in its Account No. 186 a variable gas credit of $1.3
million, as shown on Exhibit No. 9, Line 2, Col. (b). This deferred credit is attributable to
Intermountain' s lower variable gas costs since June 30, 2012. Intermountain proposes to pass back
this balance via a per therm credit, as shown on Exhibit No. 9, Col. (b), Line 4 and included on
Exhibit No. 6, Line 3.
3)Finally, Intermountain has deferred in its Account No. 186 deferred gas costs related to
Lost and Unaccounted For Gas as shown on Exhibit No. 9, Col. (b), Lines 5 through 20. This
deferral results in net per therm increases to Intermountain's sales customers, as illustrated on
Exhibit No. 9, Line 12, Col. (b), and included on Exhibit No. 6, Line 3. The Lost and Unaccounted
For Gas deferral also results in a per therm increase for Intermountain's transportation customers as
shown on Exhibit No. 9, Line 20, Col. (b). Exhibit No. 9 is attached hereto and incorporated herein
by reference.
Although Intermountain filed an out-of-cycle PGA which was effective February 2012 to
account for rapidly falling natural gas prices, gas prices continued to drop subsequent to that filing.
The lower natural gas commodity prices from July 2011 through June 2012 resulted in a credit
balance of $11.9 million as shown on Exhibit No. 10, Line 2, Col. (b).
To mitigate the impact that the reversal of this large credit would have on October 2013
prices, Intermountain proposes to refund this balance through a one-time credit on customer bills in
December 2012. The credit balance would be divided by actual sales volumes over the time period
APPLICATION -7
it was generated to arrive at the per therm credit detailed on Exhibit No. 10, Line 4, Cot. (b). The
per therm credit would be applied to the actual sates volumes of customers that purchase their gas
from Intermountain (RS-1, RS-2, GS, LV-1, IS-R and IS-C), for the time period July 1, 2011
through June 30, 2012. This calculated credit would be reflected as a line item on customer bills in
December 2012. Exhibit No. 10 is attached hereto and incorporated herein by reference.
XI.
Intermountain has allocated the proposed price changes to each of its customer classes based
upon Intermountain's PGA provision. However, a straight cent per therm price decrease was not
utilized for the LV- 1 tariff as no fixed costs are currently recovered in the tail block of the LV- 1
tariff. The proposed changes in the WACOG, and variable deferred credits as outlined on Exhibit
No. 9, are applied to all three blocks of the LV-1 tariff. However, all adjustments relating to fixed
costs are applied only to the first two blocks of the LV-1 tariff.
XII.
Each block of the proposed LV-1, T-3, T-4 and T-5 tariffs include a uniform cents per therm
increase to adjust for Lost and Unaccounted For Gas as detailed on Exhibit No. 9, Lines 13 through
20, Col. (b). The prices, including the proposed adjustment for each block of the T-3, T-4 and T-5
tariffs, and the removal of existing temporary price changes, are outlined on Exhibit No. 1, Page 1,
Lines 21 through 32.
XIII.
Exhibit No. 11 is an analysis of the overall price changes by class of customer. Exhibit No.
11 is attached hereto and incorporated herein by reference.
XIV.
The proposed overall 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.
XV.
This Application is filed pursuant to the applicable statutes and the Rules and Regulations of
the Commission. 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
APPLICATION -8
Notice are attached hereto and incorporated herein by reference. Copies of this Application, its
Exhibits, and Workpapers have been provided to those parties regularly intervening in
Intermountain's rate proceedings.
Intermountain requests that this matter be handled under modified procedure pursuant to
Rules 201-204 of the Commission's Rules of Procedure. Intermountain stands ready for immediate
consideration of this matter.
APPLICATION -9
WHEREFORE, Intermountain respectfully petitions the Idaho Public Utilities Commission
as follows:
a.That the proposed rate schedules herewith submitted as Exhibit No. 2 be approved
without suspension and made effective as of October 1, 2012 in the manner shown on Exhibit No.
2.
b.That this Application be heard and acted upon without hearing under modified procedure,
and
C. For such other relief as this Commission may determine proper herein.
DATED at Boise, Idaho, this 10th day of August, 2012.
INTERMO S COMPANY
By LJ
Scott Md'on
Vice President & Chief Accounting Officer
MOFFATT THOMAS BARRETT ROCK &
FIELDcHTD
By L Ste h R. Thomas
A y for Intermountain Gas Company
APPLICATION -10
CERTIFICATE OF MAILING
I HEREBY CERTIFY that on this 10th day of August, 2012, I served a copy of the
foregoing Case No. 1NT-G-12-01 upon:
Paula Pyron
Northwest Industrial Gas Users
4113 Wolf Berry Court
Lake Oswego, OR 97035-1827
R. Scott Pasley
J. R. Simplot Company
P0 Box 27
Boise, ID 83707
Chad Stokes
Cable Huston et al.
1001 SW Fifth Avenue, Suite 2000
Portland, Oregon 97204-1136
Steven Gray
J. R. Simplot Company
P0 Box 27
Boise, ID 83707
Conley E. Ward, Jr.
Givens, Pursley, Webb & Huntley
277 N. 6th St., Suite 200
P0 Box 2720
Boise, ID 83701
by depositing true copies thereof in the United States Maiostage prepaid, in envelopes addressed
to said persons at the above addresses. 1/17
Scott Mdih' ''
Vice President & Chief Accounting
APPLICATION - 11
EXHIBIT NO. 1
CASE NO. INT-G-12-01
INTERMOUNTAIN GAS COMPANY
CURRENT TARIFFS
Showing Proposed Price Changes
(11 pages)
Exhibit No. I
Case No. INT-G-12-01
Intermountain Gas Company
Page 1 of 11
COMPARISON OF PROPOSED OCTOBER 1, 2012 PRICES
TO OCTOBER 1, 2011 & FEBRUARY 1, 2012 PRICES
Prices per Proposed
Line INT-G-11-01 & Proposed October 1, 2012
No. Rate Class INT-G-11-03 Adjustment Prices
(a) (b) (c) (d)
1 RS-1
2 April -November $ 0.86071 $ (0.00375) $ 0.85696
3 December- March 0.74815 (0.00375) 0.74440
4 RS-2
5 April - November 0.72609 (0.02371) 0.70238
6 December - March 0.69246 (0.02371) 0.66875
7 GS-1
8 April - November
9 Block 1 0.74217 (0.02206) 0.72011
10 Block 2 0.72044 (0.02206) 0.69838
ii Block 3 0.69942 (0.02206) 0.67736
12 December - March
13 Block 1 0.69132 (0.02206) 0.66926
14 Block 2 0.67012 (0.02206) 0.64806
15 Block 3 0.64966 (0.02206) 0.62760
16 CNG Fuel 0.64966 (0.02206) 0.62760
17 LV-1
18 Block 1 0.50587 (0.05126) 0.45461
19 Block 0.46738 (0.05126) (1) 0.41612
20 Block 3 0.38456 (0.04442) (2) 0.34014
21 T-3
22 Block 1 0.05400 0.00419 (3) 0.05819
23 Block 2 0.02140 0.00419 (3) 0.02559
24 Block 3 0.00727 0.00419 0.01146
25 T-4
26 Block 1 0.05823 0.00419 (3) 0.06242
27 Block 2 0.01974 0.00419 (3) 0.02393
28 Block 3 0.00501 0.00419 (3) 0.00920
29 1-5
30 Demand Charge 0.84253 - 0.84253
31 Commodity Charge 0.00086 0.00419 (3) 0.00505
32 Over-Run Service 0.04345 0.00419 (3) 0.04764
33 IS-R (4)
34 April - November 0.69246 (0.02371) 0.66875
35 December - March 0.69246 (0.02371) 0.66875
36 IS-C (5)
37 April - November
38 Block 1 0.69132 (0.02206) 0.66926
39 Block 2 0.67012 (0.02206) 0.64806
40 Block 3 0.64966 (0.02206) 0.62760
41 December - March
42 Block 1 0.69132 (0.02206) 0.66926
43 Block 2 0.67012 (0.02206) 0.64806
44 Block 3 0.64966 (0.02206) 0.62760
See Workpaper No. 7, Line 13, Column (e)
(2) See Workpaper No. 7, Line 17, Column (e)
Remove INT-G-1 1-01 temporary of $(0.00l60) and add the temporary from Exhibit 9, Line 20, Column (b)
(4)The I5-R price is based on the RS-2 December - March price and receives the same PGA adjustments.
(5)The IS-C price is based on the GS-1 December - March price and receives the same PGA adjustments.
Exhibit No. 1
Case No. INT-G-12-01
Intermountain Gas Company
Page 2 of 11
I.P.U.C. Gas Tariff
Second Revised Volume No. 1
(Supersedes First Revised Volume No. 1)
Forty-Fourth Revised Fifth Sheet No. 01 (Page 1 of 1)
Name
of Utility Intermountain Gas Company
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Jan. 31, 2012 Fob. 1,2012
Per O.N. 32450
Jean D. Jewell Secretary
Rate Schedule RS-1
RESIDENTIAL SERVICE
AVAILABILITY:
Available to individually metered consumers not otherwise specifically provided for, using
natural gas for residential purposes.
RATE:
Monthly minimum charge is the customer charge.
For billing periods ending April through November
Customer Charge - $2.50 per bill
Commodity Charge - $0.66071 per therm* $085696
For billing periods ending December through March
Customer Charge - $6.50 per bill
Commodity Charge - $0.71815 per therm* $074440
*Includes:
Temporary purchased gas cost adjustment of $(0.07718) $(0.02618)
Weighted average cost of gas of $0.11812 $033489
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the
Company's Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the
Company's Tariff, of which this rate schedule is a part.
Issued by: Intermountain Gas Company
By: Scott Madison Title: Vice President & Chief Accounting Officer
Effective: February 1, 2012 October 1, 2012
Exhibit No. 1
Case No. INT-G-12-01
Intermountain Gas Company
Page 3 o 11
I.P.U.C. Gas Tariff
Second Revised Volume No. 1
(Supersedes First Revised Volume No. 1)
Forty Fourth Revised Fifth Sheet No. 02 (Page 1 of 1)
Name
of Utility Intermountain Gas Company
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Jan. 31, 2012 Feb. 1, 2012
Per O.N.32450
Jean D. Jewell Secretary
Rate Schedule RS-2
MULTIPLE USE RESIDENTIAL SERVICE
AVAILABILITY:
Available to individually metered consumers using gas for several residential purposes
including both water heating and space heating.
RATE:
Monthly minimum charge Is the customer charge.
For billing aeriods ending A pril through November
Customer Charge - $2.50 per bill
Commodity Charge - $0.72609 per th erm* $070238
For billing periods ending December through March
Customer Charge - $6.50 per bill
Commodity Charge - $0.69216 per therm* $066875
*Includes:
Temporary purchased gas cost adjustment of $(0.06720) $(0.02332)
Weighted average cost of gas of $041812 $033489
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the
Company's Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the
Company's Tariff, of which this rate schedule is a part.
Issued by: Intermountain Gas Company
By: Scott Madison Title: Vice President & Chief Accounting Officer
Effective: Fobruo' 1, 2012 October 1 2012
Exhibit No. 1
Case No. INT-G-12-01
Intermountain Gas Company
Page 4 of 11
I.P.U.C. Gas Tariff
Second Revised Volume No. I
(Supersedes First Revised Volume No. 1)
Forty-th Revised Seventh Sheet No. 03 (Page 1 of 2)
Name
of Utility Intermountain Gas Company
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Jon. 31, 2012 Feb. 4,2042
Per O.N. 32450
Jean D. Jewell Secretary
Rate Schedule GS-1
GENERAL SERVICE
AVAILABILITY:
Available to individually metered customers whose requirements for natural gas do not
exceed 2,000 therms per day, at any point on Company's distribution system. Requirements in
excess of 2,000 therms per day may be served under this rate schedule upon execution of a one-
year written service contract.
RATE:
Monthly minimum charge is the customer charge.
For billing periods ending April through November
Customer Charge - $200 per bill
Commodity Charge - First 200 therms per bill @ $0.71217* $0.72011
Next 1,800 therms per bill @ $0.72011 $069838
Over 2,000 therms per bill © $0.69942* $067736
For billing periods ending December through March
Customer Charge - $9.50 per bill
Commodity Charge - First 200 therms per bill @ $0.69132* $066926
Next 1,800 therms per bill @ $0.6701 2* $064806
Over 2,000 therms per bill @ $0.61966* $062760
*Includes:
Temporary purchased gas cost adjustment of $(0.07988) $(0.02861)
Weighted average cost of gas of $0.11812 $033489
Issued by: Intermountain Gas Company
By: Scott Madison Title: Vice President & Chief Accounting Officer
Effective: February 1, 2944 October 1, 2012
Exhibit No. 1
Case No. INT-G-12-01
Intermountain Gas Company
Page 5 of 11
l.P.U.C. Gas Tariff
Second Revised Volume No. 1
(Supersedes First Revised Volume No. 1)
Forty-Sixth Revised Seventh Sheet No. 03 (Page 2 of 2)
Name
of Utility Intermountain Gas Company
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Jan. 31, 2012 Feb. 1, 2012
PcrO.N. 32450
Jean D. Jewell Secretary
Rate Schedule GS-1
GENERAL SERVICE (Continued)
For separately metered deliveries of gas utilized solely as Compressed Natural Gas Fuel in
vehicular internal combustion engines.
Customer Charge - $9.50 per bill
Commodity Charge - $0.61966 per therm* $062760
*Includes:
Temporary purchased gas cost adjustment of $(O.07988) $(0.02861)
Weighted average cost of gas of $0,41 812 $033489
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the
Company's Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
Any GS-1 customer who leaves the GS-1 service will pay to Intermountain Gas Company,
upon exiting the GS-1 service, all gas and transportation related costs incurred to serve
the customer during the GS-1 service period not borne by the customer during the time
the customer was using GS-1 service. Any GS-1 customer who leaves the GS-1 service
will have refunded to them, upon exiting the GS-1 service, any excess gas commodity or
transportation payments made by the customer during the time they were a GS-1
customer.
2. All natural gas service hereunder is subject to the General Service Provisions of the
Company's Tariff, of which this rate schedule is a part.
Issued by: Intermountain Gas Company
By: Scott Madison Title: Vice President & Chief Accounting Officer
Effective: Fobruary 1, 2944 October 1, 2012
Exhibit No. I
Case No. INT-G-12-01
Intermountain Gas Company
Page 6 of 11
I.P.U.C. Gas Tariff IDAHO PUBLIC UTILITIES COMMISSION Second Revised Volume No. I Approved Effective (Supersedes First Revised Volume No. I)
kH1. 31, 2012 Feb. 1, 2012 Fifty Fourth Revised Fifth Sheet No. 04 (Page 1 of 2)
Per O.N. 32460 Name
of Utility Intermountain Gas Company Jean D. Jewell Secretary
Rate Schedule LV-1
LARGE VOLUME FIRM SALES SERVICE
AVAILABILITY:
Available at any mutually agreeable delivery point on the Company's distribution system to any
existing customer receiving service under the Company's rate schedule LV-1 or any new customer
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:
Commodity Charge:
First 250,000 therms per bill @ $0.50587* $045461
Next 500,000 therms per bill @ $0.16738* $041612
Amount Over 750,000 therms per bill @ $O.38156** $034014
The above prices include weighted average cost of gas of $0,41842 $033489 * Includes temporary purchased gas cost adjustment of $(0.01992) $(0.02818) ** Includes temporary purchased gas cost adjustment of $(0.01017) $(0.00136)
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the
Company's Purchased Gas Cost Adjustment Provision.
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.Any LV-1 customer who exits the LV-1 service at any time (including, but not limited to, the
expiration of the contract term) will pay to Intermountain Gas Company, upon exiting the LV-1 service,
all gas and/or interstate transportation related costs to serve the customer during the LV-1 contract
period not borne by the customer during the LV-1 contract period. Any LV-1 customer will have
refunded to them, upon exiting the LV-1 service, any excess gas and/or interstate transportation related
payments made by the customer during the LV-1 contract period.
3.In the event that total deliveries to any customer within the last three contract periods met
or exceeded the 200,000 therm threshold, but the customer during the current contract period used
less than the contract minimum of 200,000 therms, an additional amount shall be billed. The additional
amount shall be calculated by billing the deficit usage below 200,000 therms at the LV-1 Block I rate
adjusted for the removal of variable gas costs. The customer's future eligibility for the LV-1 Rate
Schedule will be renegotiated with the Company.
Issued by: Intermountain Gas Company
By: Scott Madison Title: Vice President & Chief Accounting Officer
Effective: February 1, 2012 October 1, 2012
Exhibit No. 1
Case No. INT-G-12-01
Intermountain Gas Company
Page 7 of 11
IDAHO PUBLIC UTILITIES COMMISSION
I.P.U.C. Gas Tariff Approved Effective
Second Revised Volume No. 1 Sept. 30, 2011 Oct. 1, 2011
(Supersedes First Revised Volume No. 1) Per O.N. 32,372

44h Revised Seventh Sheet No. 11 (Page 1 of 2) Jean D. Jewell Secretary
Name
of Utility Intermountain Gas Company
Rate Schedule 1-3
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:

Block One: First 100,000 therms transported $0.05100* $005819

Block Two: Next 50,000 therms transported $0.02110* $002559

Block Three: Amount over 150,000 therms transported $0.00727* $001146
*Includes temporary purchased gas cost adjustment of $(0.00160) $0.00259
ANNUAL MINIMUM BILL:
The customer shall be subject to the payment of an annual minimum bill of $30,000
during each annual contract period, unless a higher minimum is required under the
service contract to cover special conditions.
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the
Company's Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
1.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.
2.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.
3.Interruptible Distribution Transportation Service may be made firm by a written
agreement between the parties if the customer has a dedicated line.
4.If requested by the Company, the customer expressly agrees to interrupt its
operations during periods of capacity constraints on the distribution system.
5.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.
6.The customer understands and agrees that the Company is not responsible to
deliver gas supplies to the customer which have not been nominated and accepted for
delivery by the interstate pipeline.
7.An existing LV-1, T-4, or T-5 customer electing this schedule may concurrently
utilize Rate Schedule T-3 on the same or contiguous property.
Issued by: Intermountain Gas Company
By: Scott Madison Title: Vice President & Chief Accounting Officer
Effective: October 1, 2011 October 1, 2012
Exhibit No. I
Case No. INT-G-12-01
Intermountain Gas Company
Page 8 of 11
IDAHO PUBLIC UTILITIES COMMISSION
I.P.U.C. Gas Tariff proved Effective ff
Second Revised Volume No. 1 Sept. 30, 2011 Oct. 1, 2011
(Supersedes First Revised Volume No. 1) Per O.N. 32372
ifth Revised Sixth Sheet No. 13 (Page 1 of 2) Jean D. Jewell Secretary
Name
of Utility Intermountain Gas Company
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:
Commodity Charge:
Block One: First 250,000 therms transported $0.05823* $006242
Block Two: Next 500,000 therms transported@ $0.01971* $002393
Block Three: Amount over 750,000 therms transported@ $504 * $000920
*Includes temporary purchased gas cost adjustment of $(0-00469) $0.00259
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company's
Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
1.This service excludes the service and cost of firm interstate pipeline charges.
2.The customer is responsible for procuring its own supply of natural gas and interstate
transportation under this Rate Schedule. The customer understands and agrees that the
Company is not responsible to deliver gas supplies to the customer which have not been
nominated, scheduled, and delivered by the interstate pipeline to the designated city gate.
3.All natural gas service hereunder is subject to the General Service Provisions of the
Company's Tariff, of which this Rate Schedule is a part.
4.The customer shall nominate a Maximum Daily Firm Quantity (MDFQ), which will be stated in
the contract and in effect throughout the term of the service contract.
5.An existing LV-1, T-3, or T-5 customer electing this schedule may concurrently utilize Rate
Schedule T-4 on the customer's same or contiguous property.
BILLING ADJUSTMENTS:
In the event that total deliveries to any customer within the last three contract periods met or
exceeded the 200,000 therm threshold, but the customer during the current contract period
used less than the contract minimum of 200,000 therms, an additional amount shall be billed.
The additional amount shall be calculated by billing the deficit usage below 200,000 therms
at the 1-4 Block I rate. The customer's future eligibility for the T-4 Rate Schedule will be
renegotiated with the Company.
Issued by: Intermountain Gas Company
By: Scott Madison Title: Vice President & Chief Accounting Officer
Effective: Ootobor 1 2011 October 1 2012
Exhibit No. 1
Case No. INT-G-12-01
Intermountain Gas Company
Page 9 of 11
I.P.U.C. Gas Tariff
Second Revised Volume No. 1
(Supersedes First Revised Volume No. 1)
oth Revised Fifth Sheet No. 14 (Page 1 of 2)
Name
of Utility Intermountain Gas Company
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Sept. 30, 2011 Oct. 1, 2011
Per- O.N.32372
Jean D. Jewell Secretary
Rate Schedule T-5
FIRM DISTRIBUTION SERVICE WITH MAXIMUM DAILY DEMANDS
AVAILABILITY:
Available at any mutually agreeable delivery point on the Company's distribution system to any
existing T-5 customer whose daily contract demand on any given day meets or exceeds a predetermined
level agreed to by the customer and the Company upon execution of a one-year minimum written service
contract for firm distribution service in excess of 200,000 therms per year.
MONTHLY RATE:
Firm Service
Demand Charge:
Firm Daily Demand -
Commodity Charge:
For Firm Therms Transported
Over-Run Service
Commodity Charge:
For Therms Transported In Excess Of MDFQ:
Rate Per Therm
$0.84253
$0.00086* $000505
$0.01345* $004764
*I ncludes temporary purchased gas cost adjustment of $(0.00160) $000259
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company's
Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
I 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 nominate a Maximum Daily Firm Quantity (MDFQ), which will be stated in and will
be in effect throughout the term of the service contract.
3.The monthly Demand Charge will be equal to the MDFQ times the Firm Daily Demand rate. Firm
demand relief will be afforded to those 1-5 customers paying both demand and commodity charges
for gas when, in the Company's judgment, such relief is warranted.
4.The actual therm usage for the month or the MDFQ times the number of days in the billing month,
whichever is less, will be billed at the applicable commodity charge for firm therms.
Issued by: Intermountain Gas Company
By: Scott Madison Title: Vice President & Chief Accounting Officer
Effective: Octobor 1, 2011 October 1, 2012
Exhibit No. I
Case No. INT-G-12-01
Intermountain Gas Company
Page lOofli
I.P.U.C. Gas Tariff
Thc4 Revised Fourth Sheet No. 16 (Page 1 of 2)
Name
of Utility Intermountain Gas Company
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Jan. 31, 2012 Feb. 4,2042
Per O.N. 32450
Jean D. Jewell Secretary
Rate Schedule IS-R
RESIDENTIAL INTERRUPTIBLE SNOWMELT SERVICE
APPLICABILITY:
Applicable to any new residential or Customer using natural gas 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.
For billing periods ending April throuoh November
Customer Charge - $2.50 per bill
Commodity Charge - $069216 per therm* $0.66875
For billing periods cndinq December throuah March
Customer Charge -$6.50 per bill
Commodity Charge - $0.69216 per th erm* $066875
*Includes:
Temporary purchased gas cost adjustment of $(0.06720) $(0.02332)
Weighted average cost of gas of $0.11812 $0.33489
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the
Company's Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
1. All natural gas service hereunder is subject to the General Service Provisions of the
Company's Tariff, of which this Rate Schedule is a part.
Issued by: Intermountain Gas Company
By: Scott Madison Title: Vice President & Chief Accounting Officer
Effective: February 1, 2944 October 1, 2012
Exhibit No. I
Case No. INT-G-12-01
Intermountain Gas Company
Page 11 of 11
I.P.U.C. Gas Tariff
Th4c4 Revised Fourth Sheet No. 17 (Page 1 of 2)
Name
of Intermountain Gas Company
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Jon. 31, 2012 Fob. 1, 2012
Per O.N. 32460
Jean D. Jewell Secretary
Rate Schedule IS-C
SMALL COMMERICAL INTERRUPTIBLE SNOWMELT SERVICE
APPLICABILITY:
Applicable to any new Customer otherwise eligible to receive gas service under Rate Schedule
GS-1 and using natural gas 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.
For billing periods ending April through November
Customer Charge - $2.00 per bill
Commodity Charge - First 200 therms per bill @ $0 691 32* $066926
Next 1,800 therms per bill @ $0 ,6701 1 $064806
Over 2,000 therms per bill @ $0.64966* $062760
For billing periods ending December through March
Customer Charge - $9.50 per bill
Commodity Charge - First 200 therms per bill @$0.69132 $066926
Next 1,800 therms per bill © $0.6701 2* $064806
Over 2,000 therms per bill © $0.61966* $062760
*Includes:
Temporary purchased gas cost adjustment of $(0.07988) $(0.02861)
Weighted average cost of gas of $0.11812 $033489
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the
Company's Purchased Gas Cost Adjustment Provision.
Issued by: Intermountain Gas Company
By: Scott Madison Title: Vice President & Chief Accounting Officer
Effective: February 1, 2012 October 1, 2012
EXHIBIT NO. 2
CASE NO. INT-G-12-01
INTERMOUNTAIN GAS COMPANY
PROPOSED TARIFFS
(10 pages)
I.P.U.C. Gas Tariff
Second Revised Volume No. I
(Supersedes First Revised Volume No. 1)
Forty-Fifth Revised Sheet No. 01 (Page 1 of 1)
Name
Of Utility Intermountain Gas Company
Exhibit No. 2
Case No. INT-G-12-01
Intermountain Gas Company
Page 1 of 10
Rate Schedule RS-1
RESIDENTIAL SERVICE
Available to individually metered consumers not otherwise specifically provided for, using
natural gas for residential purposes.
RATE:
Monthly minimum charge is the customer charge.
Customer Charge - $2.50 per bill
Commodity Charge - $0.85696 per th erm*
Customer Charge - $6.50 per bill
Commodity Charge - $0.74440 per th erm*
*Includes:
Temporary purchased gas cost adjustment of $(0.02618)
Weighted average cost of gas of $0.33489
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the
Company's Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the
Company's Tariff, of which this rate schedule is a part.
Issued by: Intermountain Gas Company
By: Scott Madison Title: Vice President & Chief Accounting Officer
Effective: October 1, 2012
Exhibit No. 2
Case No. INT-G-12-01
Intermountain Gas Company
Page 2 of 10
I.P.U.C. Gas Tariff
Second Revised Volume No. I
(Supersedes First Revised Volume No.
I Name
of Utility Intermountain Gas Company
Rate Schedule RS-2
MULTIPLE USE RESIDENTIAL SERVICE
AVAILABILITY:
Available to individually metered consumers using gas for several residential purposes
including both water heating and space heating.
RATE:
Monthly minimum charge is the customer charge.
Customer Charge - $2.50 per bill
Commodity Charge -$0.70238 per th erm*
Customer Charge - $6.50 per bill
Commodity Charge - $0.66875 per th erm*
*Includes:
Temporary purchased gas cost adjustment of $(0.02332)
Weighted average cost of gas of $0.33489
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the
Company's Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the
Company's Tariff, of which this rate schedule is a part.
Issued by: Intermountain Gas Company
By: Scott Madison Title: Vice President & Chief Accounting Officer
Effective: October 1, 2012
I.P.U.C. Gas Tariff
Second Revised Volume No. I
(Supersedes First Revised Volume No. 1)
Forty-Seventh Revised Sheet No. 03 (Page 1 of 2)
Name
of Utility Intermountain Gas Company
Exhibit No. 2
Case No. INT-G-12-01
Intermountain Gas Company
Page 3 of 10
Rate Schedule GS-1
GENERAL SERVICE
AVAILABILITY:
Available to individually metered customers whose requirements for natural gas do not
exceed 2,000 therms per day, at any point on Company's distribution system. Requirements in
excess of 2,000 therms per day may be served under this rate schedule upon execution of a one-
year written service contract.
RATE:
Monthly minimum charge is the customer charge.
Customer Charge- $2.00 per bill
Commodity Charge. First 200 therms per bill @ $0.72011*
Next 1,800 therms per bill @ $0.69838*
Over 2,000 therms per bill @ $0.67736*
Customer Charge - $9.50 per bill
Commodity Charge - First 200 therms per bill @ $0.66926*
Next 1,800 therms per bill @ $0.64806*
Over 2,000 therms per bill @ $0.62760*
*Includes:
Temporary purchased gas cost adjustment of $(0.02861)
Weighted average cost of gas of $0.33489
Issued by: Intermountain Gas Company
By: Scott Madison Title: Vice President & Chief Accounting Officer
Effective: October 1, 2012
I.P.U.C. Gas Tariff
Second Revised Volume No. I
(Supersedes First Revised Volume No. I)
Forty-Seventh Revised Sheet No. 03 (Page 2 of 2)
Name
of Utility Intermountain Gas Company
Exhibit No. 2
Case No. INT-G-12-01
Intermountain Gas Company
Page 4 of 10
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 - $9.50 per bill
Commodity Charge - $0.62760 per th erm*
*Includes:
Temporary purchased gas cost adjustment of $(0.02861)
Weighted average cost of gas of $0.33489
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the
Company's Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
Any GS-1 customer who leaves the GS-1 service will pay to Intermountain Gas Company,
upon exiting the GS-1 service, all gas and transportation related costs incurred to serve
the customer during the GS-1 service period not borne by the customer during the time
the customer was using GS-1 service. Any GS-1 customer who leaves the GS-1 service
will have refunded to them, upon exiting the GS-1 service, any excess gas commodity or
transportation payments made by the customer during the time they were a GS-1
customer.
2. All natural gas service hereunder is subject to the General Service Provisions of the
Company's Tariff, of which this rate schedule is a part.
Issued by: Intermountain Gas Company
By: Scott Madison Title: Vice President & Chief Accounting Officer
Effective: October 1, 2012
I.P.U.C. Gas Tariff
Second Revised Volume No. I
(Supersedes First Revised Volume No. 1)
Fifty-Fifth Revised Sheet No. 04 (Page 1 of 2)
Name
of Utility Intermountain Gas Company
Exhibit No. 2
Case No. INT-G-12-01
Intermountain Gas Company
Page 5 of 10
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 new customer
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:
Commodity Charge:
First 250,000 therms per bill @ $0.45461*
Next 500,000 therms per bill @ $0.41612*
Amount Over 750,000 therms per bill @ $0.34014**
The above prices include weighted average cost of gas of $0.33489 * Includes temporary purchased gas cost adjustment of $(0.02818) ** Includes temporary purchased gas cost adjustment of $(0.00136)
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the
Company's Purchased Gas Cost Adjustment Provision.
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.Any LV-1 customer who exits the LV-1 service at any time (including, but not limited to, the
expiration of the contract term) will pay to Intermountain Gas Company, upon exiting the LV-1 service,
all gas and/or interstate transportation related costs to serve the customer during the LV-1 contract
period not borne by the customer during the LV-1 contract period. Any LV-1 customer will have
refunded to them, upon exiting the LV-1 service, any excess gas and/or interstate transportation related
payments made by the customer during the LV-1 contract period.
3.In the event that total deliveries to any customer within the last three contract periods met
or exceeded the 200,000 therm threshold, but the customer during the current contract period used
less than the contract minimum of 200,000 therms, an additional amount shall be billed. The additional
amount shall be calculated by billing the deficit usage below 200,000 therms at the LV-1 Block I rate
adjusted for the removal of variable gas costs. The customer's future eligibility for the LV-1 Rate
Schedule will be renegotiated with the Company.
Issued by: Intermountain Gas Company
By: Scott Madison Title: Vice President & Chief Accounting Officer
Effective: October 1, 2012
I.P.U.C. Gas Tariff
Second Revised Volume No. I
(Supersedes First Revised Volume No. 1)
Seventh Revised Sheet No. 11 (Page 1 of 2)
Name
of Utility Intermountain Gas Company
Exhibit No. 2
Case No. INT-G-12-01
Intermountain Gas Company
Page 6 of 10
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:
Block One: First 100,000 therms transported© $0.058191
Block Two: Next 50,000 therms transported@ $00255
Block Three: Amount over 150,000 therms transported $0.01146*
*Includes temporary purchased gas cost adjustment of $0.00259
ANNUAL MINIMUM BILL:
The customer shall be subject to the payment of an annual minimum bill of $30,000
during each annual contract period, unless a higher minimum is required under the
service contract to cover special conditions.
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the
Company's Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
1.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.
2.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.
3.Interruptible Distribution Transportation Service may be made firm by a written
agreement between the parties if the customer has a dedicated line.
4.If requested by the Company, the customer expressly agrees to interrupt its
operations during periods of capacity constraints on the distribution system.
5.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.
6.The customer understands and agrees that the Company is not responsible to
deliver gas supplies to the customer which have not been nominated and accepted for
delivery by the interstate pipeline.
7.An existing LV-1, T-4, or T-5 customer electing this schedule may concurrently
utilize Rate Schedule T-3 on the same or contiguous property.
Issued by: Intermountain Gas Company
By: Scott Madison Title: Vice President & Chief Accounting Officer
Effective: October 1, 2012
I.P.U.C. Gas Tariff
Second Revised Volume No. 1
(Supersedes First Revised Volume No. 1)
Sixth Revised Sheet No. 13 (Page 1 of 2)
Name
Of Utility Intermountain Gas Company
Exhibit No. 2
Case No. INT-G-12-01
Intermountain Gas Company
Page 7 of 10
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:
Commodity Charge:
Block One: First 250,000 therms transported@ $0.06242*
Block Two: Next 500,000 therms transported@ $0.02393*
Block Three: Amount over 750,000 therms transported@ $0.00920*
*Includes temporary purchased gas cost adjustment of $0.00259
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company's
Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
1.This service excludes the service and cost of firm interstate pipeline charges.
2.The customer is responsible for procuring its own supply of natural gas and interstate
transportation under this Rate Schedule. The customer understands and agrees that the
Company is not responsible to deliver gas supplies to the customer which have not been
nominated, scheduled, and delivered by the interstate pipeline to the designated city gate.
3.All natural gas service hereunder is subject to the General Service Provisions of the
Company's Tariff, of which this Rate Schedule is a part.
4.The customer shall nominate a Maximum Daily Firm Quantity (MDFQ), which will be stated in
the contract and in effect throughout the term of the service contract.
S. An existing LV-1, T-3, or T-5 customer electing this schedule may concurrently utilize Rate
Schedule T-4 on the customer's same or contiguous property.
BILLING ADJUSTMENTS:
1. In the event that total deliveries to any customer within the last three contract periods met or
exceeded the 200,000 therm threshold, but the customer during the current contract period
used less than the contract minimum of 200,000 therms, an additional amount shall be billed.
The additional amount shall be calculated by billing the deficit usage below 200,000 therms
at the T-4 Block I rate. The customer's future eligibility for the T-4 Rate Schedule will be
renegotiated with the Company.
Issued by: Intermountain Gas Company
By: Scott Madison Title: Vice President & Chief Accounting Officer
Effective: October 1, 2012
I.P.U.C. Gas Tariff
Second Revised Volume No. I
(Supersedes First Revised Volume No. 1)
Fifth Revised Sheet No. 14 (Page 1 of 2)
Exhibit No. 2
Case No. INT-G-12-01
Intermountain Gas Company
Page 8 of 10
I Name
of Utility Intermountain Gas Company
Rate Schedule T-5
FIRM DISTRIBUTION SERVICE WITH MAXIMUM DAILY DEMANDS
AVAILABILITY:
Available at any mutually agreeable delivery point on the Company's distribution system to any
existing T-5 customer whose daily contract demand on any given day meets or exceeds a predetermined
level agreed to by the customer and the Company upon execution of a one-year minimum written service
contract for firm distribution service in excess of 200,000 therms per year.
MONTHLY RATE:
Firm Service Rate Per Therm
Demand Charge:
Firm Daily Demand - $0.84253
Commodity Charge:
For Firm Therms Transported $0.00505*
Over-Run Service
Commodity Charge:
For Therms Transported In Excess Of MDFQ: $0.04764*
*Includes temporary purchased gas cost adjustment of $0.00259
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company's
Purchased Gas Cost Adjustment Provision.
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.
2.The customer shall nominate a Maximum Daily Firm Quantity (MDFQ), which will be stated in and will
be in effect throughout the term of the service contract.
3.The monthly Demand Charge will be equal to the MDFQ times the Firm Daily Demand rate. Firm
demand relief will be afforded to those T-5 customers paying both demand and commodity charges
for gas when, in the Company's judgment, such relief is warranted.
4.The actual therm usage for the month or the MDFQ times the number of days in the billing month,
whichever is less, will be billed at the applicable commodity charge for firm therms.
Issued by: Intermountain Gas Company
By: Scott Madison Title: Vice President & Chief Accounting Officer
Effective: October 1, 2012
Exhibit No. 2
Case No. INT-G-12-01
Intermountain Gas Company
Page 9 of 10
I.P.U.C. Gas Tariff
Fourth Revised Sheet No. 16 (Page 1 of 2)
Name
Of Utility Intermountain Gas Company
Rate Schedule IS-R
RESIDENTIAL INTERRUPTIBLE SNOWMELT SERVICE
APPLICABILITY:
Applicable to any new residential or Customer using natural gas 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 - $2.50 per bill
Commodity Charge - $0.66875 per th erm*
Customer Charge - $6.50 per bill
Commodity Charge - $0.66875 per th erm*
*Includes:
Temporary purchased gas cost adjustment of $(0.02332)
Weighted average cost of gas of $0.33489
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the
Company's Purchased Gas Cost Adjustment Provision.
SERVICE CONDITIONS:
1. All natural gas service hereunder is subject to the General Service Provisions of the
Company's Tariff, of which this Rate Schedule is a part.
Issued by: Intermountain Gas Company
By: Scott Madison Title: Vice President & Chief Accounting Officer
Effective: October 1, 2012
Exhibit No. 2
Case No. INT-G-12-01
Intermountain Gas Company
Page 10 of 10
I.P.U.C. Gas Tariff
Fourth Revised Sheet No. 17 (Page 1 of 2)
Name
of Utility Intermountain Gas Company
Rate Schedule IS-C
SMALL COMMERICAL INTERRUPTIBLE SNOWMELT SERVICE
APPLICABILITY:
Applicable to any new Customer otherwise eligible to receive gas service under Rate Schedule
GS-1 and using natural gas 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 - $2.00 per bill
Commodity Charge - First 200 therms per bill @ $0.66926*
Next 1,800 therms per bill @ $0.64806*
Over 2,000 therms per bill @ $0.62760*
Customer Charge - $9.50 per bill
Commodity Charge - First 200 therms per bill @ $0.66926*
Next 1,800 therms per bill @ $0.64806*
Over 2,000 therms per bill © $0.62760*
*Includes:
Temporary purchased gas cost adjustment of $(0.02861)
Weighted average cost of gas of $0.33489
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the
Company's Purchased Gas Cost Adjustment Provision.
Issued by: Intermountain Gas Company
By: Scott Madison Title: Vice President & Chief Accounting Officer
Effective: October 1, 2012
EXHIBIT NO. 3
CASE NO. INT-G-12-01
INTERMOUNTAIN GAS COMPANY
PERTINENT EXCERPTS FROM INTERSTATE PIPELINES AND RELATED
FACILITIES
(28 pages)
Exhibit No. 3
Case No. INT-G-12-01
Intermountain Gas Company
Page 1 of 28
Northwest Pipeline GP
FERC Gas Tariff
Fifth Revised Volume No. 1
FERC GAS TARIFF
FIFTH REVISED VOLUME NO. 1
(Superseding Fourth Revised Volume No. 1)
Of
NORTHWEST PIPELINE GP
Filed with
FEDERAL ENERGY REGULATORY COMMISSION
Communications concerning this Tariff should be sent to:
Laren M. Gertsch, Director, Rates & Regulatory
Northwest Pipeline GP
295 Chipeta Way
Salt Lake City, Utah 84108
P.O. Box 58900
Salt Lake City, Utah 84158
Telephone: [phone]
Facsimile: [phone]
Exhibit No. 3
Case No. INT-G-12-01
Intermountain Gas Company
Page 2 of 28
Northwest Pipeline GP
FERC Gas Tariff Third Revised Sheet No. 5

Fifth Revised Volume No. 1 Superseding
Second Revised Sheet No. 5
STATEMENT OF RATES
Effective Rates Applicable, to
Rate Schedules TF-1, TF-2, TI-1, TFL-1 and TIL-1
(Dollars per Dth)
Currently
Base Effective
Rate Schedule and Tariff Rate Tariff Rate(3)
Type of Rate Minimum Maximum ACA(2) Minimum Maximum
Rate Schedule TF-1 (4) (5)
Reservation
(Large Customer)

System-Wide .00000 .37883 - .00000 .37883

15 Year Evergreen Exp. .00000 .37995 - .00000 .37995

25 Year Evergreen Exp. .00000 .36344 - .00000 .36344
Volumetric
(Large Customer)

System-Wide .00756 .03000 .00180 .00936 .03180

15 Year Evergreen Exp. .00369 .00369 .00180 .00549 .00549

25 Year Evergreen Exp. .00369 .00369 .00180 .00549 .00549
(Small Customer) (6) .00756 .67209 .00180 .00936 .67389
Scheduled Overrun .00756 .40984 .00180 .00936 .41164
Rate Schedule TF-2 (4) (5)
Reservation .00000 .37883 - .00000 .37883
Volumetric .00756 .03000 - .00756 .03000
Scheduled Daily Overrun .00756 .40984 - .00756 .40984

Annual Overrun .00756 .40984 - .00756 .40984
Rate Schedule TI-1

Volumetric (7) .00756 .40984 .00180 .00936 .41164
Rate Schedule TFL-1 (4) (5)

Reservation - - - - -

Volumetric - - - - -
Scheduled Ovrrun
Rate Schedule TIL-1

Volumetric - - - - -
Exhibit No. 3
Case No. JNT-G-12-01
Intermountain Gas Company
Page 3 of 28
Northwest Pipeline GP
FERC Gas Tariff Second Revised Sheet No. 7
Fifth Revised Volume No. 1 Superseding
First Revised Sheet No. 7
STATEMENT OF RATES (Continued)
Effective Rates Applicable to Rate Schedules SGS-2F and SGS-21
(Dollars per Dth)
- Currently Effective
Rate Schedule and Tariff Rate (1)
Type of Rate Minimum Maximum
Rate Schedule SGS-2F (2) (3) (4) (5)
Demand Charge
Pre-Expansion Shipper 0.00000 0.01547
Expansion Shipper 0.00000 0.08453
Capacity Demand Charge
Pre-Expansion Shipper 0.00000 0.00056
Expansion Shipper - 2010 Phase 0.00000 0.00232
Volumetric Bid Rates
Withdrawal Charge
Pre-Expansion Shipper 0.00000 0.01547
Expansion Shipper 0.00000 0.08453
Storage Charge
Pre-Expansion Shipper 0.00000 0.00056
Expansion Shipper - 2010 Phase 0.00000 0.00232
Rate Schedule SGS-21
Volumetric 0.00000 0.00113
Footnotes
(1) Shippers receiving sex-vice under these rate schedules are required to
furnish fuel reimbursement in-kind at the rates specified on Sheet
No. 14.
Exhibit No. 3
Case No. INT-G-12-01
Intermountain Gas Company
Page 4 of 28
Northwest Pipeline GP
FERC Gas Tariff Second Revised Sheet No. 8-A
Fifth Revised Volume No. 1 Superseding
First Revised Sheet No. 8-A
STATEMENT OF RATES (Continued)
Effective Rates Applicable to Rate Schedules LS-2F and LS-21
(Dollars per Dth)
Currently Effective
Rate Schedule and Tariff Rate (1)
Type of Rate Minimum Maximum
Rate Schedule LS-2F (3)
Demand Charge (2) 0.00000 0.03054
Capacity Demand Charge (2) 0.00000 0.00390
Volumetric Bid Rates
Vaporization Demand-Related Charge (2) 0.00000 0.03054
Storage Capacity Charge (2) 0.00000 0.00390
Liquefaction 0.64110 0.64110
Vaporization 0.04184 0.04184
Rate Schedule LS-21
Volumetric 0.00000 0.00783
Liquefaction 0.64110 0.64110
Vaporization 0.04184 0.04184
Footnotes
(1)Shippers receiving service under these rate schedules are required to
furnish fuel reimbursement in-kind at the rates specified on Sheet No.
14.
(2)Rates are daily rates computed on the basis of 365 days per year,
except that rates for leap years are computed on the basis of 366 days.
Exhibit No. 3
Case No. INT-G-12-01
Intermountain Gas Company
Page 5 of 28
Northwest Pipeline GP
FERC Gas Tariff Fifth Revised Sheet No. 14
Fifth Revised Volume No. 1 Superseding
Fourth Revised Sheet No. 14
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 8.1 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 Schedule TF-1 1.30%
Rate Schedule TF-1 - Evergreen Expansion
Incremental Surcharge (1) 0.50%
Rate Schedule TF-2 1.30%
Rate Schedule TI-1 1.30%
Rate Schedule TFL-1 -
Rate Schedule TIL-1 -
Rate Schedule SGS-2F 0.58%
Rate Schedule SGS-2I 0.58%
Rate Schedule LS-1 3.12%
Rate Schedule LS-2F 3.12%
Rate Schedule LS-2I 3.12%
Rate Schedule DEX-1 1.30%
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, for
injection into storage, 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. 3
Case No. INT-G-12-01
Intermountain Gas Company
Page 6of28
Exhibit No. 3
Case No. INT-G-12-01
Intermountain Gas Company
Page 7 of 28
Williams
Northwest Pipeline GP
Laren Gertsch
Director Rates & Regulatory Affairs
295 Qhioeta Way
Salt Lake City, UT 84W8
Phone: (aUl) 5B4-20O
March15, 2012
.KitnherlyD. Bose, Secreta±y
Federal Energy Regulatory Commission
888 First Street, NE
Washington, D.C.20426
RE: North West Pipeline OP
Docket No. R.12-________
Dear Ms. BOse
Pursuant to Rule 207(a)(5) of the Rules of Practiee and Prqctdure: of the FLederal nrgj RegiiiatØI
Comialon ("Commission"), 18 C.FR.. §385-207(;a)(5)(201 1), Northwest Pipeline OP ('Nrthwest")
hereby submits for filing:
o A Petition for Approval :of Settleme: ('Petition") requesting that the Cpnnnission approve- it Stipala'tion
and Settlemeht Agreement ('Séffleñient') by April 26,2012;
• The Settlement; and
. A draft-Commission Letter Order Approving Uncontested Settlement.
Northwest requests that the. Commission set March 27, 202 as the deadline for interventions and
commemits. The supporting or non-opposing parties to this Settlement represent approximately 995
percent of Northwest's long-term firm transportation and storage capacity. In addition, 100 percertoftbe.
hippert who .aotively participated ih the settlement disOiissicmn either sup.ort or do not oppose This
Settlement Therefore, Northwest does not expect this Settlement to be contested
le
Rec II mitted,
Gthsth
or of Rates and Regulatory Affairs
Exhibit No. 3
Case No. INT-G-12-01
Intermountain Gas Company
Page 8of28
UNITED STATES OF AMERICA
BEFORE THE
FEDERAL ENERGY REGULATORY COMMISSION
Northwest Pipeline GP ) Docket No. RP12-_-
)
PETITION OF
NORTHWEST PIPELINE GP
FOR APPROVAL OF SETTLEMENT
Pursuant to Rule 207(a)(5) of the Federal Energy Regulatory Commissions
("Commission") Rules of Practice and Procedure, 18 C.F.R. § 385.207(a)(5)(201 1),
Northwest Pipeline OP ("Northwest") hereby petitions the Commission for approval of
the "Stipulation and Settlement Agreement," dated March 15, 2012 ("Settlement"), and
associated pro forma tariff sheets submitted herewith. In support hereof, Northwest
shows as follows:
I.
CORRESPONDENCE AND COMMUNICATIONS
Communications concerning this filing and service of all documents should be
addressed to the following:
Laren Gertsch
Director, Rates & Regulatory Affairs
Northwest Pipeline OP
295 Chipeta Way
P.O. Box 58900
Salt Lake City, Utah 84158-0900
[phone]
[phone] (facsimile)
[e-mail]
Bruce Reemsnyder
Senior Counsel
Northwest Pipeline GP
295 Chipeta Way
P.O. Box 58900
Salt Lake City, Utah 84158-0900
[phone]
[phone] (facsimile)
Bruce.Reemsnyder(Williams.com
Exhibit No. 3
Case No. INT-G-12-01
Intermountain Gas Company
Page 9 of 28
BACKGROUND
On June 30, 2006, Northwest filed a general rate case pursuant to Section 4 of the
Natural Gas Act ("NGA"), 15 U.S.C. § 717c, in Docket No. RP06-41 6-000. On March 30,
2007, the Commission approved a Stipulation and Agreement of Settlement ("2007
Settlement"), pursuant to which Northwest and the other parties agreed to settle the matters at
issue in that general rate case proceeding.
Section 9.6 of the 2007 Settlement requires Northwest to file an NGA Section 4
general rate case not later than July 1, 2012' for rates to become effective not later than
January 1, 2013 ("2012 Rate Filing"). In anticipation of the 2012 Rate Filing, Northwest
invited all of its shippers to engage in discussions to determine if a pre-filing settlement
might be reached. Numerous and extensive meetings and discussions between Northwest
and its shippers have been held from December 2011 through early March 2012. During
the course of these meetings and discussions, the parties exchanged several offers and
counteroffers. The Settlement is the product of these meetings and discussions.
Through the Settlement, the Settling Parties have successfully resolved the issues in a
practical and carefully constructed fashion, eliminating the need for testimony, discovery,
hearing and briefing of the matters resolved. The avoidance of litigation is a valuable
outcome, benefiting the Settling Parties, the Commission and the public interest.
The supporting or non-opposing parties to this Settlement represent
approximately 99.5 percent of Northwest's long-term firm transportation and storage
capacity. In addition, 100 percent of the shippers who actively participated in the
1 Because July 1, 2012 is a Sunday, the effective filing deadline for the 2012 Rate Filing is June 29, 2012.
2
Exhibit No. 3
Case No. INT-G-12-01
Intermountain Gas Company
Päge1Oof29 .......
settlement discussion either support or do not oppose this Settlement. Therefore,
Northwest does not expect this Settlement to be contested.
The attached Settlement reflects the Settling Parties' desire to resolve their issues
and eliminate the need for Northwest to make the 2012 Rate Filing. Absent timely
approval of the Settlement, Northwest will be required to make the 2012 Rate Filing by
June 29, 2012. In order to provide Northwest sufficient time to prepare and file the 2012
Rate Filing if the Commission does not approve the Settlement, Northwest respectfully
requests that the Commission act on the Settlement by April 26, 2012.
LIII
PETITION
The Commission encourages pipelines and their customers to attempt to resolve
rate and tariff issues before making NGA Section 4 filings. See Dominion Transmission,
Inc., 111 FERC 1 61,285, at P 30 (2005) (Dominion"); Discovery Gas Transmission
LLC, 122 FERC 161,099 at P 25 & 28 (2007). The Commission recognizes that a pre-
filing settlement process enables the parties to efficiently resolve their rate and tariff
issues without the expense of a hearing and lengthy litigation.
The Commission has provided clear instructions for implementing a pre-filing
settlement agreement. The pipeline should file for approval of the pre-filing settlement
agreement pursuant to Rule 207(a)(5) of the Commission's Rules of Practice and
Procedure, 18 C.F.R. § 385.207(a)(5). The petition for approval should include pro
forma tariff sheets showing how the settlement agreement will be implemented. The
Commission will treat the petition for approval of the settlement agreement as initiating a
new proceeding and issue a notice providing for interventions, comments, and protests. If
the Commission finds that the settlement agreement is fair and reasonable and in the
3
Exhibit No. 3
Case No. INT-G-12-01
Intermountain Gas Company
. . "iage11of28 ......
public interest, then it will approve the settlement agreement Dominion, 111 FERC ¶
61,285, at P 32.
The pipeline will then be directed to file, pursuant to NGA Section 4(d) and
Section 154.203 of the Commission's regulations, actual tariff sheets implementing the
settlement agreement consistent with the terms of the settlement agreement as approved
by the Commission. The Commission will treat such a filing as a filing to comply with
the Commission's order approving the settlement agreement, and the Commission will
place tariff sheets that properly implement the settlement agreement, as approved, into
effect on the date provided for in the settlement agreement. Id.
Consistent with these instructions, Northwest files this petition requesting
Commission approval of the subject Settlement without modification or condition.
Appended to this petition is a draft Commission Letter Order approving the Settlement,
which Letter Order also contains a summary of the terms of the Settlement, reflecting an
overall balancing of the various competing interests on Northwest's system. Northwest
seeks the Commission's prompt approval of the Settlement so that Northwest and its
shippers may avail themselves of the benefits of the Settlement, without the expense of a
hearing and lengthy litigation.
4
Exhibit No. 3
Case No. INT-G-12-01
Intermountain Gas Company
Page12of28 ........
IV.
CONCLUSION
WHEREFORE, Northwest rspecthi11y requests thai the Commission grant this
petition and approve the SettIeinnt withontniodi ation Qr.conditioñ. Northwest further
requests that the Commission grant any other authorizations or-wavers that it may deem
necessary to approve the Settlement as proposed.
DATED this 15dayofM.areh 2012.
Respectfully submitted,
NORTHWEST PIPELiNE GP
Laren Qertsth
Director, .Rates & Regulatory Affairs
Northwest Pipeline GP
295 Chipeta Way
Bo 58900
Salt Lake City, Utah 84158-0900
[phone].
[phone] (faesiinile)
Laren.GertchWj1liaxns.com
Bruce Keenuyder
Senior Counsel
Northwest Pipeline GP
295 Chipeta Way
P.O Box. 58.900
Salt Lake City, Ufah 8415 -8-0900
[phone]
[phone] (facsimile)
Bruce.Reemsnyder(Wil1iams.com
Exhibit No. 3
Case No. INT-G-12-01
Intermountain Gas Company
Page13of 28 -
CERTIFICATE OF SERVICE
I hereby certify that I have this day served the foregoing petition for Approval of Settlement
and Stipulation and Settlement Agreement on each of Northwest Pipeline GPs shippers and affected
sate regulatory commissions.
Dated this 15th day of March, 2012.
Bruce Reemsnyder
Senior Counsel
Northwest Pipeline, GP
295 Chipeta Way
P.O. Box 58900
Salt Lake City, Utah 84158-0900
(80 l) 584-6742
[phone] (facsimile)
[e-mail]
Exhibit No. 3
Case No. INT-G-12-01
Intermountain Gas Company
Page 14of28
Appendix A
Northwest Pipeline GP
Docket No. RPI2-XXX
Settling Parties
Alcoa Inc.
Avista Corporation
Cardinal FG Company
Cascade Kelly Holdings, LLC dba Columbia Pacific Bio-Refmery
Cascade Natural Gas Corporation
Chevron U.S.A. Inc.
City of Blanding
City of Buckley, Washington
City Of Ellensburg
City Of Enumclaw
Clearwater Paper Corporation
Columbia Properties Tahoe,LLC dba Mont Bleu Resort Casino & Spa
ConAgra Foods Lamb Weston, Inc.
Cross Timbers Energy Services, Inc.
Cyanco Company, LLC
EP Minerals, LLC
Equilon Enterprises LLC dba Shell Oil Products US
Evraz Inc. NA
FortisBC Energy Inc.
Frederickson Power LP
Georgia-Pacific LLC
Harrah's Operating Company dba Harrah's Casino Hotel Lake Tahoe
Harvey's Tahoe Management Co., Inc.
Idaho Power Company
Idahoan Foods, LLC
IGI Resources, Inc.
Intermountain Gas Company
International Paper
Longview Fibre Paper and Packaging, Inc.
Marathon Oil Company
Newmont USA Ltd
Northwest Industrial Gas Users
Northwest Nathral Gas Company
Northwest Pipeline GP
Occidental Energy Marketing, Inc.
Oregon Public Utility Commission Staff
Exhibit No. 3
Case No. INT-G.12-01
Intermountain Gas Company
Page 15 of 28
Appendix A
Northwest Pipeline GP
Docket No. RPI2-XXX
Settling Parties
(continued)
Pacificorp
Pan-Alberta Gas Ltd.
Portland General Electric Company
Premier Magnesia, LLC
Public Utility District No. 1 of Clark County
Puget Sound Energy, Inc.
Roseburg Forest Products
Shell Energy North America (US), LP
Sierra Pacific Power Company
Snohomish County PUD No. 1
Southwest Gas Corporation
The Boeing Company
Town Of Rangely
TransAlta Energy Marketing Corp.
United States Gypsum Company
West Linn Paper Company
Weyerhaeuser NR Company
WPX Energy Marketing, LLC
Exhibit No. 3
Case No. JNT-G-12-01
Intermountain Gas Company
Page 16 of 28
Northwest Pipeline GP
FERC Gas Tariff Pro Forma Sheet No. 5
Fifth Revised Volume No. 1
STATEMENT OF RATES
Effective Rates Applicable to
Rate Schedules TF-1, TF-2, TI-1, TFL-1 and TIL-i
(Dollars per Dth)
Currently
Base Effective
Rate Schedule and Tariff Rate Tariff Rate (3)
Type of Rate Minimum Maximum ACA(2) Minimum Maximum
Rate Schedule TF-1 (4) (5)
Reservation
(Large Customer)
System-Wide .00000 .41000 - .00000 .41000
15 Year Evergreen Exp. .00000 .36263 - .00000 .36263
25 Year Evergreen Exp. .00000 .34234 - .00000 .34234
Volumetric
(Large Customer)
System-Wide .00813 .03000 .00180 .00993 .03180
15 Year Evergreen Exp. .00813 .00813 .00180 .00993 .00993
25 Year Evergreen Exp. .00813 .00813 .00180 .00993 .00993
(Small Customer) (6) .00813 .72155 .00180 .00993 .72335
Scheduled Overrun .00813 .44000 .00180 .00993 .44180
Rate Schedule TF-2 (4) (5)
Reservation .00000 .41000 - .00000 .41000
Volumetric .00813 .03000 - .00813 .03000
Scheduled Daily Overrun .00813 .44000 - .00813 .44000
Annual Overrun .00813 .44000 - .00813 .44000
Rate Schedule TI-1
Volumetric (7) .00813 .44000 .00180 .00993 .44180
Rate Schedule TFL-i (4) (5)
Reservation - - - - -
Volumetric - - - -
Scheduled Overrun - - - - -
Rate Schedule TIL-1
Volumetfic & - - - - -
Northwest Pipeline GP
FERC Gas Tariff
Fifth Revised Volume No. 1
Exhibit No. 3
Case No. INT-G-12-01
Intermountain Gas Company
Page 17 of 28
Pro Forma Sheet No. 7
STATEMENT OF RATES (Continued)
Effective Rates Applicable to Rate Schedules SGS-2F and SGS-21
(Dollars per Dth)
Currently Effective
Rate Schedule and Tariff Rate (1)
Type of Rate Minimum Maximum
Rate Schedule SGS-2F (2) (3) (4) (5)
Demand Charge
Pre-Expansion Shipper 0.00000 0.01562
Expansion Shipper 0.00000 0.04056
Capacity Demand Charge
Pre-Expansion Shipper 0.00000 0.00057
Expansion Shipper - 2010 Phase 0.00000 0.00348
Volumetric Bid Rates
Withdrawal Charge
Pre-Expansion Shipper 0.00000 0.01562
Expansion Shipper 0.00000 0.04056
Storage Charge
Pre-Expansion Shipper 0.00000 0.00057
Expansion Shipper - 2010 Phase 0.00000 0.00348
Rate Schedule SGS-21
Volumetric 0.00000 0.00224
Footnotes
(1) Shippers receiving service under these rate schedules are required to
furnish fuel reimbursement in-kind at the rates specified on Sheet
No. 14.
Exhibit No. 3
Case No. INT-G-12-01
Intermountain Gas Company
Page 18 of 28
Northwest Pipeline GP
FERC Gas Tariff Pro Forma Sheet No. 7
Fifth Revised Volume No.!
STATEMENT OF RATES (Continued)
Effective Rates Applicable to Rate Schedules SGS-2F and SGS-21
(Dollars per Dth)
Currently Effective
Rate Schedule and Tariff Rate (1)
Type of Rate Minimum Maximum
Rate Schedule SGS-2F (2) (3) (4) (5)
Demand Charge
Pre-Expansion Shipper 0.00000 0.01562
Expansion Shipper 0.00000 0.04056
Capacity Demand Charge
Pre-Expansion Shipper 0.00000 0.00057
Expansion Shipper - 2010 Phase 0.00000 0.00348
Volumetric Bid Rates
Withdrawal Charge
Pre-Expansion Shipper 0.00000 0.01562
Expansion Shipper 0.00000 0.04056
Storage Charge
Pre-Expansion Shipper 0.00000 0.00057
Expansion Shipper - 2010 Phase 0.00000 0.00348
Rate Schedule SGS-21
Volumetric 0.00000 0.00224
Footnotes
(1) Shippers receiving service under these rate schedules are required to
furnish fuel reimbursement in-kind at the rates specified on Sheet
No. 14.
Northwest Pipeline GP
FERC Gas Tariff
Fifth Revised Volume No. 1
Exhibit No. 3
Case No. INT-G-12-01
Intermountain Gas Company
Page 19 of 28
Pro Forma Sheet No. 8-A
STATEMENT OF RATES (Continued)
Effective Rates Applicable to Rate Schedules LS-2F and LS-21
(Dollars per Dth)
Currently Effective
Rate Schedule and Tariff Rate (1)
Type of Rate Minimum Maximum
Rate Schedule LS-2F (3)
Demand Charge (2) 0.00000 0.02587
Capacity Demand Charge (2) 0.00000 0.00331
Volumetric Bid Rates
Vaporization Demand-Related Charge (2) 0.00000 0.02587
Storage Capacity Charge (2) 0.00000 0.00331
Liquefaction 0.90855 0.90855
Vaporization 0.03386 0.03386
Rate Schedule LS-21
Volumetric 0.00000 0.00662
Liquefaction 0.90855 0.90855
Vaporization 0.03386 0.03386
Footnotes
(1)Shippers receiving service under these rate schedules are required to
furnish fuel reimbursement in-kind at the rates specified on Sheet No.
14.
(2)Rates are daily rates computed on the basis of 365 days per year,
except that rates for leap years are computed on the basis of 366 days.
Exhibit No. 3
Case No. INT-G-12-01
Intermountain Gas Company
Page 20 of 28
Exhibit No. 3
Case No. INT-G-12-01
Intermountain Gas Company
Page 21 of 28
NOVA Gas Transmission Ltd.
GAS TRANSPORTATION TARIFF
OF
NOVA GAS TRANSMISSION LTD.
Exhibit No. 3
Case No. INT-G-12-01
Intermountain Gas Company
Page 22 of 28
NOVA Gas Transmission Ltd. Attachment 2
Table of Rates, Tolls and Charges
Page 1 of
Group 1 F':.D Demand Rate T-D Rate per Month I I Delivery Point Group 1 Delivery Point Name Pr Point "r Day
Number ($/GJ)
2000 ALBERTA-B.C. BORDER 5.51 0.1986
31111 ALLIANCE CLAIRMONT INTERCONNECT APN 2.39 0.0861
31110 ALLIANCE EDSON INTERCONNECT APN 2.39 0.0861
31112 ALLIANCE SHELL CREEK INTERCONNECT APGC 2.39 0.0861
3002 BOUNDARY LAKE BORDER 3.44 0.1242
1958 EMPRESS BORDER 5.30 0.1911
.3886 GORDONDALE BORDER 3.44 0.1242
6404 MCNEILL BORDER 5.30 0.1911
I Group 2 FT-D Demand Rate tT-D Rate I I Subject to ATCOI
I Delivery Point Group 2 Delivery Point Name per Month
P Point per Day I Pipelines
Number ($/() ($/GJ) I Franchise Fees' I I I
Si 00(1 AT. PLASTICS SALES APN 559 0.1226 Yes
31001 ADM AGRI INDUSTRIES SALES APN 3.39 0.1226 Yes
3880 AECO INTERCONNECTION 2.39 0.0861
31003 AGRIUM CARSELAND SALES APS 2.39 0.0861
31002 AGRIUM FT. SASK SALES APN 2.39 0.0861 Yes
31004 AGRIUM REDWATER SALES APN 2.39 0.0861
31005 AINSWORTH SALES APGP 3.39 0.1226
31006 AIR UQUIDE SALES APN 3.39 0.1226
3214 AKUINU RIVER WEST SALES 2.39 0.0861
31007 ALBERTA ENVIROFUELS SALES APN 3.39 0.1226 Yes2
31008 ALBERTA HOSPITAL SALES APN 3.39 0.1226 Yes
3868 ALBERTA-MONTANA 3.44 0.1242
3059 ALLISON CREEK SALES 2.39 0.0861
31009 ALTASTEEL SALES APN 3.39 0.1226 Yes2
3562 AMOCO SALES (BP SALES TAP) 2.39 0,0861
31012 APL JASPER SALES APN 3.39 0.1226 Yes
3488 ARDLEY SALES 2.39 0.0861
3216 AURORA NO 2 SALES 2.39 0.0861
3135 AURORA SALES 2.39 0.0861
3423 BASHAW WEST SALES 2.39 0.0861
31013 BAYMAG SALES APS 2.39 0.0861
31014 BEAR CREEK COGEN SALES APGP 3.39 0.1226
3068 BEAVER HILLS SALES 2.39 0.0861
3933 BIG EDDY INTERCONNECTION 2.39 0.0861
3067 BIGSTONE SALES 2.39 0.0861
3468 BLEAK LAKE SALES 2.39 0.0861
3164 BRAINARD LAKE SALES 2.39 0.0861
3918 BUFFALO CREEK INTERCONNECTION 2.39 0.0861
31015 BURDETTCOGEN SALES APS 2.39 0.0861
3204 CABIN SALES 2.39 0.0861
3109 CALDWELL SALES 2.39 0.0861
31016 CALGARY ENERGY CENTRE SALES APS 2.39 0.0861 Yes
3634 CANOE LAKE SALES 2.39 0.0861
3165 CANOE LK SLS #2 2.39 0.0861
3866 CARBON INTERCONNECTION 2.39 0.0861
3484 CARIBOU LAKE SALES 2.39 0.0861
3157 CARIBOU LK SOUTH SL 2.39 0.0861
3106 CAFJION CREEK SALES 2.39 0.0861
3101 CAROLINE SALES 2.39 0.0861
31017 CAFISELAND COGEN SALES APS 2.39 0.0861
3495 CAVALIER SALES . . 2.39 0.0861
31018 CHAIN LAKES COOP SALES APS 2.39 0.0861
3907 CHANCELLOR INTERCONNECTION 2.39 0.0861
3151 CHEECHAM W. #2 SALES 2.39 0.0861
3622 CHEECHAM WEST SALES 2.39 0.0861
6014 CHEVRON AURORA SALES 2.39 0.0961
31019 CHEVRON FT. SASK SALES APN 3.39 0.1226 Yes
TARIFF Effective: January 1, 2012 (Amended June 1, 2012)
Exhibit No. 3
Case No. INT-G-12-01
Intermountain Gas Company
Page 23 of 28
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. 1-A
FERC GAS TARIFF
FOURTH REVISED VOLUME NO. 1-A
GAS TRANSMISSION NORTHWEST LLC
FILED WITH THE
FEDERAL ENERGY REGULATORY COMMISSION
Communications Concerning This Tariff
Should Be Addressed To:
Joan Collins
Manager, Tariffs and Compliance
Gas Transmission Northwest LLC
Mailing Address: P.O. Box 2446
Houston, TX 77252-2446
Courier Address: 717 Texas Street, Suite 2400
Houston, TX 77002-2761
Phone: [phone]
Fax: [phone]
U.
Exhibit No. 3
Case No. INT-G-12-01
Intermountain Gas Company
Page 24 of 28
Gas Transmission Northwest LLC PART 4.1
FERC Gas Tariff 4.1 - Statement of Rates
Fourth Revised Volume No. 1-A FTS-1 and LFS-1 Rates
v.7.0.0 Superseding v.6.0.0
STATEMENT OF EFFECTIVE RATES AND CHARGES FOR
TRANSPORTATION OF NATURAL GAS
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. Mm. Max. Min. Max. Min.
BASE 0.000498 0.000000 0.039216 0.000000 0.000016 0.000016 0.0050% 0.0000%
SIP (e) (e) 0.000000 (e) 0.000000 0.000016 0.000016 0.0050% 0.0000%
EXTENSION CHARGES
MEDFORD
E-1 (f) 0.003290 0.000000 0.005498 0.000000 0.000026 0.000026 --- --
E-2 (g)(1) 0.0093 63 0.000000 -- - 0.000000 0.000000 - -
(WWP)
E-2 (hXI) 0.002964 0.000000 - - 0.000000 0.000000 - -
(Diamond 1)
E-2(hXI) 0.001163 0.000000 --- - 0.000000 0.000000 -- -
(Diamond 2)
COYOTE SPRINGS
E-3 (i) 0.001412 0.000000 0.001420 0.000000 0.000000 0.000000
OVERRUN CHARGE (j)
SURCHARGES
ACA (k) - - - - 0.001800 0.001800 - --
Issued: January 11, 20.12 Docket No. RP12-301-000
Effective: January 1, 2012 Accepted: February 7, 2012
Exhibit No. 3
Case No. INT-G-12-01
Intermountain Gas Company
Page 25 of 28
Foothills Pipe Lines Ltd. Page 1
PHASE I
GAS TRANSPORTATION TARIFF
OF
FOOTHILLS PIPE LINES LTD.
This Gas Transportation Tariff is subject to the National Energy Board Act, is available for
inspection during normal business hours and is also available electronically at
www.transcanada.com . Communications concerning this Gas Transportation Tariff should be
addressed to:
Foothills Pipe Lines Ltd.
450 First Street S.W.
Calgary, Alberta
T2P5H1
Attention: Greg Szuch
TARIFF —PHASE I Effective Date: April 1, 2007
Exhibit No. 3
Case No. INT.G-12-01
Intermountain Gas Company
Page 26 of 28
Foothills Pipe Lines Ltd. Page 1
TABLE OF EFFECTIVE RATES
1.Rate Schedule FT, Finn Transportation Service
Demand Rate
($/GJ/Km/Month)
Zone 6 0.0067657123
Zone 7 0.0062022433
Zone 8* 0.0167593 368
Zone 9 0.0090496758
2.Rate Schedule OT, Overrun Transportation Service
Commodity Rate
($IGJIKrn)
Zone 6 0.0002440093
Zone 7 0.0002236875
3.Rate Schedule IT, Interruptible Transportation Service
Commodity Rate
($/GJJKm)
Zone 8* 0.000604435 1
Zone 9 0.0003263818
* For Zone 8, Shippers Haul Distance shall be 170.7 kin.
4.
TARIFF - PHASE I Effective Date: January 1, 2012
Exhibit No. 3
Case No. INT-G-12-01
Intermountain Gas Company
Page 27 of 28
FERC GAS TARIFF
SECOND REVISED VOLUME NO. 1
of
QUESTAR PIPELINE COMPANY
filed with the
FEDERAL ENERGY REGULATORY COMMISSION
Communications regarding this Tariff should be addressed to:
L. Bradley Burton,
General Manager Federal Regulatory Affairs and Chief Compliance Officer
Questar Pipeline Company
333 South State Street (84111)
P. 0. Box 45360
Salt Lake City, UT 84145-0360
Telephone: [phone]
FAX: [phone]
C.
STATEMENT OF RATES
Base Annual Currently
Tariff Charge Effective
Rate Adjustment 4/ Rate
(b) (c) (d)
$ $ $

2.87375 2.87375/Dth

0.00000 0.00000/Dth

0.03872 0.03872/0th

0.03872 0.03872/Dth

2.85338 2.85338/Dth

0.00000 0.00000/Dth

0.02378 0.02378/Dth

0.00000 0.00000/Dth
0.01049
0.01781
0.30315
0.01781
0.05927
0.00000
0.01049
0.01781
0.00180
0.00180
0.00180
0.00180
0.01229/Dth
0.01781/Dth
0.30495/Dth
0.01961/Dth
0.05927/Dth
0.00000/Dth
0.01229/Dth
0.01781/Dth
OPTIONAL VOLUMETRIC RELEASES 2/
Peaking Storage Service - PKS
Maximum 5J 3.40890
Minimum 0.00000
Firm Storage Service - FSS
Maximum 51 0.57068
Minimum 0.00000
Storage Usage Charges Applicable to Volumetric Releases 3J
Peaking Storage Service - PKS:
Injection 0.03872
Withdrawal 0.03872
Clay Basin Storage Service - FSS:
Injection 0.01049
Withdrawal 0.01781
3.40890/Dth
0.00000/Dth
O57068/Dth
0.00000/Dth
0.03872/0th
0.03872/0th
0.00180 0.01229/Dth
0.01781/0th
Exhibit No. 3
Case No. INT-G-12-01
Intermountain Gas Company
Page 28 of 28
Questar Pipeline Company
FERC Gas Tariff Statement of Rates
Second Revised Volume No. 1
Section Version: 4.0.0
Rate Schedule/
Type of Charge
(a)
PEAKING STORAGE
Monthly Reservation charge
Maximum /
Minimum
Usage Charge
Injection
Withdrawal
CLAY BASIN STORAGE
Firm Storage Service - FSS
Monthly Reservation Charge
Deliverability
Maximum &
Minimum
Capacity
Maximum
Minimum
Usage Charge
Injection
Withdrawal
Authorized Overrun Charge
Maximum
Minimum
Interruptible Storage Service - ISS
Usage Charge
Inventory .1/
Maximum
Minimum
Injection
Withdrawal
PARK AND LOAN SERVICE - PALl
Daily Charge
Maximum 0.30315 - 0.30315/0th
Minimum 0.00000 - 0.00000/Dth
Delivery Charge 0.02830 0.00180 0.03010/0th
FUEL REIMBURSEMENT - 10% (0.2% utility and 1.8% compressor fuel) for Rate Schedule PALl
Filed On: November 22, 2011 Effective On: January 1, 2012
EXHIBIT NOS. 4-11
CASE NO. INT-G-12-01
INTERMOUNTAIN GAS COMPANY
(8 pages)
INTERMOUNTAIN GAS COMPANY
Summary of Gas Cost Changes
Annual Therm,! 10(1!2011 Total Annual Annual Therm,! 10!1l2012 Total Annual Cost of Service Allocation of Gas Cost Adjustment R
Line Billing Determinants Prices Cost Billing Determinants Prices Coat Annual
No. Description INT.G-11.01 INT.G-11-01 INT.G.11.01 INT.G.12-01 INT.G.12.01 INT.G-12.01 Difference RS'i RS-2 OS-I LV-1
(a) ) (c) (d) (e) (f) (g) (h) (I) 0) (k) (I)
1 DEMAND CHARGES:
2 Transportation:
3 NWP IF-I Demand I (Full Rate)m 807,103,200 $ 0.03760 $ 30,347,351 886,804,000 $ 0.04102 $ 36,374,300 $ 6,026,949 $ 725,108 $ 3,304,431 $ 1,971,524 $ 25,886
4 MNP IF-i Demand 1 (Discounted) 0) 153,192,960 0.02093 3,206,351 171,206,900 0.02006 3,434,839 228,488 27,490 125,274 74,743 981
5 Upstream Capocity 1,250,243,140 0.01355 16,945,030 1,201,426,080 0.01357 16,300,997 (644,033) (77,484) (353,108) (210,875) (2,766)
6 Storage:
7 SOS-i
8 Demand 303,370 M 0.00155 171,742 (6) 303,370 A 0.00156 172,542
9 Capacity Demand 10,920,990 R 0.00006 223,225 (5) 10,920,990 R 0.00006 226,206 (6)
10 TF-2 Reservation 10,920,990 R 0.03798 414,779 10,920,990 0.04021 439,173
11 TF-2 Redelvery Charge 10,920,990 0.00300 32,763 10,920,990 0.00300 32,763
12 LS
13 Demand 1,132,000 (M 0.00306 0.00306 1,264,331 (6) 1,132,000 (5) 0.00308 1,261,852
14 Capacity 10,962,235 R 0.00039 1,560,474 10,962,350 (5) 0.00039 1,560,491
15 Liquefaction 10,962,235 R 0.06411 702,789 10,962,350 R 0.06411 702,796
16 Vaporization 10,962,235 )5( 0.04184 458,660 10,962,350 0.04104 458,665
17 TF-2 Reservation 10,962,235 (6) 0.03798 416,346 10,962,350 0.04021 440,844
18 TF-2 Redelivery Charge 10,962,235 rv 0.00300 32,887 10,962,350 °' 0.00300 32,887
19 Other Storage Facdtea
20 COMMODITY CHARGES:
21 Total ProducerfSuppller Purchases Including Storage 325,602,049 0.41812 (8) 136,140,729 325,602,049 0.33489 109,040,870
22 TOTAL ANNUAL COST DIFFERENCE
23 Normalized Sales Volumes (lfl!II . 12131!11)
24 Average Base Rate Change
25 Other Permanent Changes Proposed:
26 Elimination of Temporary Credits and Surcharges from Case No. 841-6-11-01
27 Adjustment to Fixed Cost Collection Rate (see EyJithft 5, Line 24)
28 Total Permanent Changes Proposed fines 24 through 27):
29 Temporary Surcharge (Credit) Proposed (Exhibit No. 6, line d Coin (bXe))
30 Proposed Average Per Therm Change in Intermountain Gas Company Tariff
11t See WoitipaperNo. 5, Line 8
See Wortipoper No.1
Sao Wortipaper No.2
(4)See Worlrpaper No.3
(5)Represents Non-Additive Demand Charge Determinants
Price Reflects Deity Charge; Annual Charge (Column (d) 4(g)) equals Price (Column (c) & (f)) tines Annual Thermu48illng Determinants (Column () & (e)) tines 365. Actual Prices include 6 decimals
See Wortipaper No. 4, Line 33, Column (e)
°1WACOG was approved in INT-G-11-03
800 96 439 262 3
2,981 359 1,634 975 13
24,394 2,935 13,374 7,980 105
(2,479) (298) (1,359) (811) (ii)
17 2 9 6 -
7 1 4 2 -
5 1 2 2 -
24,498 2,947 13,432 8,814 105
157,873 R 18,970 86,448 51,578 677
(27,099,859) (2,866,596) (14,945,356) (9,018,405) (269,500)
$ (21,280,559) $ (2,166,469) $ (11,754,778) $ (7,114,805) $ (244,507)
34,441,859 179,568,956 108,355,215 3,238,019
$ (0.08290) $ (0.06546) $ (0.06566) $ (0.07551)
0.07748 0.06720 0.07988 0.04992
0.00785 (0.00213) (0.00767) 0.00251
0.02243 (0.00039) 0.00655 (0.02308)
(0.02618) (0.02332) (0.02861) (0.02818)
$ (0.00375) $ (0.02371) $ (0.02206) $ (0.05126)
-V F 0) -0) X ID CD us (D CD
-o Z o C 0 Z 0
00 Z
OC)
Cn y ,
3 •0 0)
INTERMOUNTAIN GAS COMPANY
Summary of Fixed Gas Cost Charges
Annual Thermsl
Line Billing Determinants
No. Description lNT-G11-01
(a) (b)
1 DEMAND CHARGES:
2 Transportation:
3 NWP IF-i Demand 1 (Full Rate) 621,801060
4 NWP IF-i Demand 1 (Discounted) 338,495,100
5 Upstream Capacity 1,250243,140
6 Storage:
7 SOS-i
8 Demand 303,370
9 Capacity Demand 10,920,990
10 TF-2 Reservation 10,920,990
11 TF-2 Redeilvery Charge 10,920,990
12 IS-i
13 Demand 1,132,000
14 Capacity 10,962,235
15 LIquefaction 10,962,235
16 Vaporization 10,962,235
17 TF-2 Reservation 10,962,235
18 TF-2 Redetivery Charge 10,962,235
19 Other Storage Facilities
20 Total Fixed Gas Cost Charges
21 Normalized Sales Volumes (INT-G-12-01 Estimated Volumes)
22 Fixed Cost Collection per Therm (Line 20 divided by Line 21)
23 Current Fixed Cost Collection per Therm
24 Adjustment to Fixed Cost Collection (Line 22 mInus Line 23)
25 FIXED COST COLLECTION RATE CALCULATION:
26 Adjusted Fixed Cost Collection Per Therm (Line 22)
27 Incremental Fixed Cost Collection
28 INT-G-12-01 Fixed Costs Collected
Annual Cost of Service Allocation of Gas Coat Adjustment
Cost
INT-G-11-01 RS-1 RS-2 GS-1 LV-1
(cl) (e) (f) (g) (h)
24,392,417 $ 2,934,676 $ 13,373,777 $ 7,979,199 $ 104,765
9,161,285 1,102,203 5,022,913 2,996,821 39,348
16,945,030 2,038,674 9,290,553 5,543,024 72,779
171,742 12) 20,662 94,162 56,180 738
223,225 12) 26,856 122,389 73,021 959
414,779 49,902 227,414 135,682 1,781
32,763 3,942 17,963 10,717 141
1,264,331 121 152,113 693,203 413,585 5,430
1.560,474 121 187,742 855,571 510,459 6,702
702,789 84,553 385,323 229,895 3,018
458,660 55,182 251,472 150,036 1,970
416,346 50,091 228,273 136,194 1,788
32,887 3,957 18,031 10,758 141
3,083,891 371,026 1,690,824 1,008,796 13,245
58,860,619 $ 7,081,579 $ 32,271,868 $ 19,254,367 $ 252,805
33,539,901 182,285,966 107,719,520 3,343,141
$ 0.21114 $ 0.17704 $ 0.17875 $ 0.07562
$ 0.20329 $ 0.17917 $ 0.18642 $ 0.07311
$ 0.00785 $ (0.00213) $ (0.00767) $ 0.00251
$ 0.21114 $ 0.17704 $ 0.17875 $ 0.07562
0.02033 0.01777 0.01757 0.00772
$ 0.23147 $ 0.19481 $ 0.19632 $ 0.08334
1011(2011
Prices
INT-G-1 1-01
(c)
$ 0.03923 $
0.02706
0.01355
0,00155
0.00006
0.03798
0.00300
0.00306
0.00039
0.06411
0.04184
0.03798
0.00300
See Workpaper No. 5, Line 8
121 Price Reflects Daily Charge; Annual Charge (Column (d)) equals Price (Column (C)) times Annual Therms (Column (b)) times 365.
(3) See Exhibit 4, Lines 1-19
mom 0) .-'O) X
CD (B
- 0 Z o C 0 Z
-
G) G)
to
a),
B
0)
INTERMOUNTAIN GAS COMPANY
Summary of Proposed Temporary Surcharges (Credits)
Cost of Service Allocation of Deferred Gas Costs
Line
No. Description RS-1 RS-2 GS-1 LV-1
(a) (b) (c) (d) (e)
I Management of Pipeline Transportation Capacity (1) $ (0.01302) $ (0.01138) $ (0.01125) $ (0.00494)
2 Proposed Temporary Surcharge (Credit) - Fixed Deferral (2) (0.01395) (0.01273) (0.01815) (0.02188)
3 Proposed Temporary Surcharge (Credit) - Variable Deferral 0.00079 (3) 0.00079 (3) 0.00079 (3) (0.00136) (4)
4 Total Proposed Temporary Surcharges (Credits) $ (0.02618) $ (0.02332) $ (0.02861) $ (0.02818)
(1)See Exhibit No. 7, Line 5, Columns (c) - (f)
(2)See Exhibit No. 8, Line 10, Columns (c) - (0
(3)See Exhibit No. 9; Line 4, Column (b) plus Line 12, Column (b)
(4)See Exhibit No. 9; Line 4, Column (b) plus Line 20, Column (b)
-0 EF
-0 2 0 C 0 Z -,, 0
- Z Q)
00
P
$ (0.01302) $ (0.01138) $ (001125) $ (0.00494)
RS-1 RS-2 GS-1 LV-1
(c) (d) (e) (f)
(160,222) $ (730,154) $ (435,632) $ (5,720)
(288,090) (1,312,868) (783,297) (10,285)
(448,312) $ (2,043,022) $ (1,218,929) $ (16,005)
34,441,859 179,566,956 108,355,215 3,238,019
Total
(b)
$ (1331,728) $
(2,394,540)
$ (3,726,268)
INTERMOUNTAIN GAS COMPANY
Allocation of Annualized Credits Resulting from Management of Pipeline Transportation Capacity
Cost of Service Allocation of Deferred Gas Costs (1)
Line
No. Description
(a)
1 Segmentation Credits
2 Northwest Pipeline Capacity Releases
3 Total Management of Pipeline Transportation Capacity
4 Normalized Sales Volumes (Ill/li - 12/31/11)
5 Proposed Price Adjustment Per Therm
(1) See Workpaper No. 5, Line 8
05C)rl,
- ) X M CD ca
(DCD&
-0 Z — o C 0Z -, o
G)G)
2
•0 0)
INTERMOUNTAIN GAS COMPANY
Proposed Temporary Surcharges (Credits) - Fixed Costs
Deferred
Account 1860
Estimated Cost of Service Allocation of Deferred Gas Costs (2)
Sept. 30, 2012
Balance (1) RS-1 RS-2 GS-1 LV-1
(b) (c) (d) (e) (U
$ (36,816) $ (14,940) $ (85,150) $ 59,287 $ 3,987
1,616,301 302,670 1,315,972 50,828 (53,169)
(5,216,580) (627,612) (2,860,126) (1,706,437) (22,405)
(1,074) (129) (589) (351) (5)
(4,818,868) (567,788) (2,620,665) (1,612,841) (17,574)
3,653,011 427,385 1,964,321 1,242,978 18,327
$ (4,804,026) $ (480,414) T--(2-286,237) $ (1,966,536) $ (70,839)
34,441,859 179,566,956 108,355,215 3,238,019
$ (0.01395) $ (0.01273) $ (0.01815) $ (0.02188)
Line
No. Description
(a)
1 Fixed Costs:
2 From INT-G-1 1-01 (Accounts 1860.2050 - 2090)
3 Fixed Cost Collection Adjustment (Accounts 1860.2200)
4 Capacity Releases & Purchases (Account 1860.2320)
5 Interest (Account 1860.2430)
6 Management of Pipeline Transportation Capacity (Account 1860.2530)
7 Amortization of 1860.2530 (Accounts 1860.2540 - 1860.2550)
8 Total Fixed Costs
9 Normalized Sales Volumes (111111 - 12/31111)
10 Proposed Temporary Surcharge (Credit)-Fixed Costs
(1)See Worlcpaper No. 6, Page 1, Lines 53 -75 and Page 2, Lines 1 -37
(2)See Workpaper No. 5, Line 8
- ) )< c CD CD, CD
-0 Z - o 0 Z Q
O) Z Q
00 0)' Cl)
3
0 Cl)
Exhibit No. 9
Case No. INT-G-12-01
Intermountain Gas Company
Page 1 of I
INTERMOUNTAIN GAS COMPANY
Proposed Temporary Surcharges (Credits) Variable Costs
Line
No. Description Amount
(a) (b)
1 Account 1860 Variable Amounts Which Apply to RS-1, RS-2, OS-I, and LV-1:
2 Account 1860 Variable Costs $ (1,286,355) (1)
3 Normalized Sales Volumes (1/1/11 - 12/31/11) 325,602,049
4 Proposed Temporary Surcharge (Credit) - Variable Costs $ (0.00395)
5 Lost and Unaccounted For Gas Amounts Which Apply to RS-1, RS-2, and GS-I:
6 Lost and Unaccounted For Gas Amounts from INT-G-1 0-03 (Account 1860-2120) $ (1090,757) (2)
7 Lost and Unaccounted For Gas Amortization (Account 1860-2130) 1,068,039
8 (Over)/Under Collection of Lost and Unaccounted For Gas from INT-G-10-03 (22,718)
9 Lost and Unaccounted For Gas INT-G-12-01 1,549,466 (4)
10 Total Lost and Unaccounted For Gas Amounts Which Apply to RS-1, RS-2, and GS-1 $ 1,526,748
11 Normalized Sales Volumes (1/1/11 - 12/31/11) 322,364,030
12 Proposed Temporary Surcharge (Credit) - Lost and Unaccounted For Gas Costs $ 0.00474
13 Lost and Unaccounted For Gas Amounts Which Apply to LV-I, T-3, T-4, and 1-5:
14 Lost and Unaccounted For Gas Amounts from INT-G-1 0-03 (Account 1860-2120) $ (356,047)
15 Lost and Unaccounted For Gas Amortization (Account 1860-2140) 451,026 (6)
16 (Over)/Under Collection of Lost and Unaccounted For Gas from INT-G-10-03 94,979
17 Lost and Unaccounted For Gas INT-G-12-01 516,493
18 Total Lost and Unaccounted For Gas Amounts Which Apply to LV-1, T-3, T4 and T-5 $ 611,472
19 Normalized Sales Volumes (1/1/11 - 12/31/11) 236,392,499
20 Proposed Temporary Surcharge (Credit) - Lost and Unaccounted For Gas Costs $ 0.00259
(1)See Workpaper No. 6, Page 1: Line 7, Column (e); Line 11, Column (d) & Line 17, Column (e)
(2)See Workpaper No. 6, Page 1, Line 20, Column (c)
(3)See Workpaper No. 6, Page 1, Line 26, Column (d)
(4)See Workpaper No. 6, Page 1, Line 41, Column (d) plus Line 47, Column (e)
(5)See Workpaper No. 6, Page 1, Line 21, Column (c)
(6)See Workpaper No. 6, Page 1, Line 30, Column (d)
See Workpaper No. 6, Page 1, Line 42, Column (d) plus Line 51, Column (e)
Exhibit No. 10
Case No. INT-G-12-01
Intermountain Gas Company
Page 1 of I
Line
No.
INTERMOUNTAIN GAS COMPANY
Proposed One-Time Variable Credit
Description
(a)
Amount
(b)
1 Proposed One-Time Variable Credit:
2 Account 1860.2180 Credit through 6/30/12
$ (11,937,692) (1)
3 Actual Sales Volumes (7/1/11 - 6/30112) 307,918,911
4 Proposed One-Time Variable Per Therm Credit
$ (0.03877)
(1) See Workpaper No. 6, Pagel, Line 10, Column (d)
I
12 Total Transportation
13 Total
Demand volumes removed from the S/therm calculations
Line
Description
(a)
1 Gas Sales:
2 RS-1 Residential
3 RS-2 Residential
4 GS-1 General Service
5 LV-1 Large Volume
6 Total Gas Sales
7 1-3 Transportation
8 1-4 Transportation
9 T-5 Transportation (Demand)
10 1-5 Transportation (Commodity)
11 Total 1-5
Annual
Therms/CD Vols. Revenue $ITherm
(b) (c) (d)
34441,859 $ 29,777,743 $ 0.86458
179566,956 136,373,920 0.75946
108,355215 76,225,727 0.70348
3,238019 1,637434 0.50569
325,602,049 244,014,824 0.74943
72,684,394 1,176,033 0.01618
141,865,782 5,883,174 0.04147
660,840 556,778 0.84253
18,604,304 16,000 0.00086
18,604,304 572,778 0.03079
233.154,480 7.631,985 0.03273
$ 0.45037
Revenue $ITherm
(e) (f)
$ (129,157) $ (0.00375)
(4,257,533) (0.02371)
(2,390,316) (0.02206)
(165,981) (0.05126)
(6,942,987) (0.02132)
304,548 0.00419
594,418 0.00419
77,952 0.00419
77,952 0.00419
976,918
S (5.966.0691 $
0.00419
(0.010681
Proposed Average Prices
Effective 101112012
Revenue $/Therm
(g) (h)
$ 29,648,586 $ 0.86083
132,116,387 0.73575
73,835,411 0.68142
1,471,453 0.45443
237,071,837 0.72811
1,480,581 0.02037
6,477,592 0.04566
556,778 0.84253
93,952 0.00505
650,730 0.03498
8,608,903
$ 245,680,740 $
0.03692
0.43969
Percent
Change
(i)
-0.43%
-3,12%
-3.14%
-10.14%
-2.84%
25.90%
10.10%
0.00%
487.21%
13.61%
12.80%
-2.37%
-0 5 03.-. 0) X In CD
CD g CD &
"0 o C 0 Z
!. Z •_
00
Cn
0 C3
3 '0 0)
INTERMOUNTAIN GAS COMPANY
Analysis of Annualized Price Change by Class of Service
Normalized Volumes for Twelve Months Ended December 31, 2011
Average Prices Effective Proposed
per Case Nos. INT-G-11-01 & INT-G-11-03 Adjustments Effective
Commission Order Nos. 32372 & 32450 1011/2012
RECEIVED
2012 AUG TO ANIO:30
Uic -'J rUC.t-i
UTILTE MMSSC
WORKPAPER NOS. 1-8
CASE NO. INT-G-12-01
INTERMOUNTAIN GAS COMPANY
(9 pages)
Workpaper No. I
Case No. INT-G-12-01
Intermountain Gas Company
Page 1 of 1
INTERMOUNTAIN GAS COMPANY
Summary of Northwest Pipeline IF-I Full Rate Demand Costs
Line INT-G.11-01 INT-G-11-01 INT-G-11.01
No. Transportation Annual Therms Prices Annual Cost
(a) (b) (c) (d)
I TF-i Demand 1 Contract #1 413,667,840 $ 0.038913 $ 16,097,001
2 IF-I Demand 1 Contract #2 25,620,000 0.053194 1,362,835
3 IF-i Demand I Contract #3 73,200,000 0.037984 2,780,430
4 IF-i Demand I Contract #4 23,607,000 0.037984 896,688
5 IF-i Demand I Contract #5 49,106,220 0.037984 1,865,251
6 IF-i Demand 1 Contract #6 36,600,000 0.037984 1,390,212
7 IF-i Demand 1 Contract #7 43,920,000 0.037984 1,668,258
8 TF-1 Demand 1 Contract #8 (1) 36,600,000 0.024690 903,642
9 IF-i Demand I Contract #9 (1) 104,782,140 0.032286 3,383,034
10 Total Annual Cost 807,103,200 $ 0.037600 $ 30,347,351
Line INT-G..1 2-01 INT-G-12-01 INT-G-12-01
No. Transportation Annual Therms Prices Annual Cost
(a) (b) (c) (d)
11 IF-i Demand I Contract #1 412,537,600 $ 0.041064 $ 16,940,550
12 IF-i Demand 1 Contract #2 25,550,000 0.054360 1,388,910
13 IF-i Demand 1 Contract #3 73,000,000 0.040214 2,935,648
14 IF-i Demand 1 Contract #4 64,389,650 0.040214 2,589,386
15 IF-i Demand I Contract #5 46,230,900 0.040214 1,859,147
16 IF-i Demand i Contract #6 36,500,000 0.040214 1,467,823
17 IF-i Demand 1 Contract #7 (1) 87,600,000 0.040214 3,522,778
18 IF-i Demand I Contract #8 (1) 36,500,000 0.040214 1,467,823
19 IF-i Demand 1 Contract #9 (1) 104,495,850 0.040214 4,202,235
20 Total Annual Cost 886,804,000 $ 0.041017 $ 36,374,300
21 Total Annual Cost Difference (Row 20 minus Row 10)
$ 6,026,949 (2)
This contract was included on Workpaper No. 2 in lNI-G-1 i-Oi as a discounted contract. The contract is now priced at full rate.
(2) See Exhibit 4, Line 3, Column (h)
Workpaper No. 2
Case No. INT-G-12-01
Intermountain Gas Company
Page 1 of I
INTERMOUNTAIN GAS COMPANY
Summary of Northwest Pipeline TF-1 Discounted Demand Costs
Line INT-G-1 1-01 INT-G-1 1-01 INT-G-1 1-01
No. Transportation Annual Therms Prices Annual Cost
(a) (b) (c) (d)
I TF-1 Demand 1 Contract #2 28,548,000 $ 0.020895 $ 596,508
2 IF-i Demand I Contract #3 29,484,960 0.020147 594,030
3 TF-1 Demand 1 Contract #4 58,560,000 0.018992 1,112,171
4 IF-i Demand I Contract #5 36,600,000 0.024690 903,642
5 Total Annual Cost 153,192,960 0.020930 3,206,351
Line INT-G-1 2-01 INT-G-1 2-01 INT-G-1 2-01
No. Transportation Annual Therms Prices Annual Cost
(a) (b) (C) (d)
6 IF-I Demand I Contract #1 14,052,500 $ 0.020107 $ 282,559
7 TF-i Demand 1 Contract #2 29,404,400 0.021330 627,190
8 TF-1 Demand 1 Contract #3 58,400,000 0.022118 1,291,685
9 IF-i Demand I Contract #4 36,500,000 0.0261 39 954,085
10 TF-i Demand I Contract #5 32,850,000 0.008503 279,320
ii Total Annual Cost 171,206,900 0.020063 3,434,839
12 Total Annual Cost Difference (Row 11 minus Row 5)
$ 228,488 (1)
(1) See Exhibit 4, Line 4, Column (h)
Workpaper No. 3
Case No. INT-G-12-01
Intermountain Gas Company
Page lofI
INTERMOUNTAIN GAS COMPANY
Summary of Upstream Capacity Costs
Line INT-G-11-01 INT-G-1 1-01 INT-G-1 1-01
No. Transportation Annual Therms Prices Annual Cost
(a) (b) (c) (d)
1 Upstream Agreement #1 190,217,520 $ 0.016760 $ 3,188,101
2 Upstream Agreement #2 149,664,020 0.009681 1,448,863
3 Upstream Agreement #3 155,553,660 0.017336 2,696,640
4 Upstream Agreement #4 301,155,780 0.016760 5,047,459
5 Upstream Agreement #5 293,524,680 0.009674 2,839,559
6 Upstream Agreement #6 160,127,480 0.01 3891 2,224,408
7 Total Annual Cost $ 17,445,030
8 Estimated Upstream Capacity Release Credits $ (500,000)
9 Total Annual Cost Including Capacity Release Credits $ 16,945,030
Line INT-G-12-01 INT-G-12-01 lNT-G-1201
No. Transportation Annual Therms Prices Annual Cost
(a) (b) (c) (d)
10 Upstream Agreement #1 - $ - $ -
11 Upstream Agreement #2 25,933,250 0.009924 257,359
12 Upstream Agreement #3 155,025,220 0.017735 2,749,310
13 Upstream Agreement #4 477,215,600 0.017201 8,208,667
14 Upstream Agreement #5 378,465,810 0.009930 3,758,103
15 Upstream Agreement #6 164,786,200 0.011090 1,827,558
16 Total Annual Cost $ 16,800,997
17 Estimated Upstream Capacity Release Credits $ (500,000)
18 Total Annual Cost Including Capacity Release Credits $ 16,300,997
19 Total Annual Cost Difference (Row 18 minus Row 9) $ (644,033) (1)
(1) See Exhibit 4, Line 5, Column (h)
Workpaper No. 4
Case No. INT-G-12-01
Intermountain Gas Company
Page 1 of 1
INTERMOUNTAIN GAS COMPANY
Summary of Other Storage Facility Costs
INT-G-11-01
Line Monthly INT-G-11.01 INT-G-11-01 INT-0-11-01
No. Storage Facilities Billing Determinant Prices Monthly Cost Annual Cost
(a) (b) (c) (d) (e)
1 Demand Costs -
2 Clay Basin I Reservation 266,250 > $ 0.285338 $ 75,971 $ 911,652
3 Clay Basin II Reservation 221,840 (1) 0.285338 63,299 759,588
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 0.002378 63,314 759,768
7 Clay Basin Ill Capacity 25,560,000 0.002378 60,782 729,384
8 Total Demand Costs 84,135,000 $ 400,123 $ 4,801,476
9 Cycling Costs -
10 Clay Basin Cycling Costs 84,135,000 0.000741 $ 62,305 $ 747,665
11 Rexburg LNG Facility
12 Transportation Reservation $ 17,813 $ 213,750
13 Variable Transportation 21,000
14 Total Rexburg LNG Facility Costs $ 234,750
15 Storage Demand Charge Credit $ (2,700,000)
16 Total Costs Including Storage Credit $ 3,083,891
INT-G-12-01
Line Monthly INT-G-12-01 INT-G-12-01 INT-G-12-01
No. Storage Facilities Billing Determinant Prices Monthly Cost Annual Cost
(a) (I,) (c) (d) (e)
17 Demand Costs -
18 Clay Basin I Reservation 266,250 (1) $ 0.285338 $ 75,971 $ 911,652
19 Clay Basin II Reservation 221,840 0.285338 63,299 759,588
20 Clay Basin Ill Reservation 213,010 0.285338 60,780 729,360
21 Clay Basin I Capacity 31,950,000 0.002378 75,977 911,724
22 Clay Basin II Capacity 26,625,000 0.002378 63,314 759,768
23 Clay Basin Ill Capacity 25,560,000 > 0.002378 60,782 729,384
24 Total Demand Costs 84,135,000 $ 400,123 $ 4,801,476
25 Cycling Costs -
26 Clay Basin Cycling Costs 84,135,000 $ 0.001033 $ 86,929 $ 1,043,148
27 Rexburg LNG Facility
28 Transportation Reservation $ 7,245 $ 86,940
29 Variable Transportation 10,000
30 Total Rexburg LNG Facility Costs $ 96,940
31 Estimated Storage Demand Charge Credit $ (2,700,000)
32 Total Costs Including Storage Credit $ 3,241,564
33 Total Annual Cost Difference Including Storage Credit (Row 32 minus Row 16) $ 157,673 (4)
111 Charge Based on Maximum Daily Withdrawal
Charge Based on Maximum Contractual Capacity
' Non Additive Billing Determinants; Includes only Capacity Volumes
(4) See Exhibit 4, Line 19, Column (h)
Workpaper No. 5
Case No. INT-G-12-01
Intermountain Gas Company
Page 1 of I
INTERMOUNTAIN GAS COMPANY
Peak Day Analysis for Demand Allocators
Line Peak Firm Sales Total
No. Description RS-1 RS-2 GS-1 LVI Peak Sales
(a) (b) (c) (d) (e) (f)
1 DEMAND ALLOCATORS PER CASE NO. INT-G-11-01:
2 Peak Day Therms 457,182 2,110,168 1,298,661 14,150 3,880,161
3 Percent of Total 11.7826% 54.3E35% 33.4693% 0.3647% 100.0000%
4 PROPOSED DEMAND ALLOCATORS PER CASE NO. INT-G-12-01:
5 Peak Day Usage Per Customer 5.66 7.61 32.72
6 January 20l2ActualCustomers 65,076 220,569 30,607 316,252
7 INT-G-12-01 Peak Day Therms (LineS mulitplied by Line 6) 368,330 1,678,530 1,001,461 13,150 3,061,471
8 Percent of Total 12.0311% 54.8276% 32.7118% 0.4295% 100.0000%
(1) Contra Demand Therms
Workpaper No. 6
Case No. INT-G-12-01
Intermountain Gas Company
Page 1 of 2
INTERMOUNTAIN GAS COMPANY
Boolyolo of Moount 1880 00r0641600 (Ctedilo(
Entimoted S.ptoonbor 30,2012
Line
Dnnor80on os2 85I0/7( 3,4J/7B) hill
(o) (b) (o) (/1 (0)
1 ACCOUNT 1860 VARIABLE AMOUNTS
2Net Cronolofito 009/trod U.n 8.9/no. in 1t9O.2010 of 1011111 $ (12.210,47560)
3 Atot150lon in 1880.2020 on 016130/12 1 70,86502572
4 EAinnolnd Thenn So/on 711 through 0/30)92 29.684968
O Anortotlon 660 $ 0.03657 1,144,512.06
6 E66noledMneAzodonin 18602020o19135/12 11348,691.90
1 OoAmot.d 8o1.nn. in 18602010 01113002 $ (201,177.80)
O 0.0/tIed 5.. Cool. FromPrnd000telSopplioro 618082586901811111 8 (2,741,870.67)
O DofnnodG.nCtotoFrontPdontsUoçp6ne in 19002110 9onogh 6130/72 (9395,820.961
90 Cnn'TtnnVoel.bI.Cr.dEB.Ioroe (11,657.86 1.60)
It Eotlnoled 000/nod CAN 18602188 Son 711 8000ghS)3Wl2
52 Eotnn.t 9/no. 886in
11.022.708.18)
.d 8. In 12108 f 9/36112 )12.966,307.78(
13 DaHy GonEnoeo. 660. Onfened In 10402240 at 613502
14 Attonn.toefen.din18603310o910fffll 3 69.44
15Intnr.oioefenrodin 1860.234O9onogIt 6130112 012 (1.510.67)
76 Es* Boo,çin 9/30/92 140BA71
17 E.trn60d 8./onto in 19082340 09 9/3002 (1,81036)
If ESTIMATED ACCOUNT 1880 VARIABLE BALANCE AT 9(38(12 $ (13,224,546.48)
19 ACCOUNT 1880 LOOT AND UNACCOUNTED FOR AMOUNTS:
20 Coon Cottol66oe DefennedS.. foloonelo ll00.2l20 On of lUll/Il 9 (1.080.757.65)
25 /nA48i&Con60S.nDnlnnnnd Gas Balance in 08802120 as 01 7611111 356.047.31)
22 lInt ConrAelin. Defennod So. 899/no. itt 16602120 on 0 1011111 $ (1,440,004.50)
23 Core 0tnonbotkolnitf01120e.o1613002 $ 967.08538
24 E9Irothd 19/into Solon
7/16-0
9/30112 28,801,567 25 Monn6n.ton Rob $ 0.00347 500,253.74
26 Snlinolndferontlioo4nnl, 18662)30.t9/30/12 1,068,030.12
27 /ndooOloIOnoAANnnin 1800.2140.oA6)30112 $ 353,20566
28 Entinnolod Tlonnn Solon Ill 9nn5 9/3002 61/788,757
29 Ooon4lo4nn Onto $ 0.00100 97,742.00
30 E60rANdktotlBoOon 698002940 .09(38/12 65102518
31 En4nrolodSolonoo'o 18802120449/3302 5 72,200/20
32 Lost &Uneononnb.d For 0.. Detent.) in 18002150 at 101101 9 4.754,91
33 IotA Lost 6Unncnonrdnd For 5.. 9.0099 6130112 $ 5)39,404.65
34 Entirtofed Lo.t&Sn00000nled For Gas 711 900o09/30112 -
35 EotItANdTolnt Lost t Uo.000nntod For Gas .t8/30112 9 3.138,484.85
36 Sam Rats C040dionnf Lost 6500onon4od For Gas 4nooglrO/38112 $ 914.830.45
37 Eolitrontod 04.0 Roc Co9.n6onof Lod 0 Urnocnoeled For Gas lll 000046013W12 163.78725
30Eo8nn.t.d Bonn RoleCngorA000flo.16 I/nO8108nled FonGene00SWl2 1,078,617.70
30 Enlinetod Loon 0 Unonononle4 For Dn8.nA (lolA Son 8080 0*CA6nlon 181901 A000gb9/30U3) 596039635
45 Estimated Bad- hr 1860.2150909/30112 5065,021.88
41 Cone Aflontlion of 10.10 Un.0000ntod FoG.. Deferral 76% 1,549,21639
42 Iodootfo(Jknnloon/LoAEUn.onoonlnd For Gel DeforM 25% 578,405.46
43 En0/not.d 8.9/non In 18682150 .5 9/3802 3,065,621,85
44 CornLoot&I/n.000nl.dFnrInler.otD.fonn.d in 5606242090101101 $ 59.10
45 ConLoA&Urtnono,ntodFortonront0nf.n.d 61 l8fO24200noogb 6(30/13 144.59
46 Enton.lodcotr l46tonl)rnnn Ill th,0046r 9/30/92 66.12
47 Enliontod Bthoon In 18662423 .1 913002 249.81
48Indnobto/Lo.0000.n000nt.d Pot inboreol Defenned 6180822809016001 . 9 24.07
49 htdoollel LonlU 4n.00ntn/nd Far inB00600tonodS 1660/2300 Onnogb 0130/12 46.40
50 E.thnolodIodooOIolLontO 5noonlndForintnroot80.rt7ll 0000ghO/30'12 17.41
57 EoOrrr.b.d Bolono. in 18602160 .1 8/3403 80/70
52 ESTIMATED ACCOUNT 1880 LOST AND UNACCOUNTED FOR BALANCE AT 908)12 $ 3,138,21036
53 ACCOUNT 1860 AXED AMOUNTS
54 NotCoonlebin. DeI.nn.d S.. 6.9/no. in 68002058 ol 101101 (3,802393.72)
55 6.5.1 009/trod G.e Dolencein )860.26600t 70/I/Il $ (4,521.52)
56 Anrolotton Ito 6.3-1 611860206066/3402 693,448/70 57 600/no/nd 6$-I Ttnrno So/no 7/I 900081,9/30112 1,604,164
56 65-1 Otentt8n9on R.le 6 0.02223 36,555.84
50 Entitroled 63-1 86000. 61 1080.204069/30)12 724,482.12
80 RS-2DnfnoredG.nDAoncniol861.20706101I111 $ 15.738,38
95 MooBoobotborRS-21,18602U78.18,30/12 2,933,77735
62 600/told 65-2 Th.nor 5./en 717 900ngh 9130112 11.130,908
03 R5-2NnnSn.9onRone $ 0.01359 951,20504
64 E60n.ledRU-2 Saloom in18602070909l38112 2,300,765.17
05 GS-000letred Gas Balm oe/n1860.2585eOIWl)l1 5 3,008.40)
66 ArnetoobmoborSo-) 6(800398068/30112 2,307,948.94
07 Enlenold 19/non Sal. 711 thtoogh9lSUfl2 16.160.495
68US-) 0405600500 Role $ 0.02594 41924
69 Enlitrobnd 05.1 Soloonin 1800,2605 819/3002 2,783,606.98
70IndogfobnD.nr.dGenDnboroninl800iUSOeblO/UI1 5 7620
77 AnonlonlionBoLV-1 6118682090 .08130112 $12,900.05
72 EntInoled LV') 8/noR 1 t2TtnnnUnlnnl/l Onoog9/ 9/30/72 791.401
73 10-1 """'donRole $ 0.00475 3,72750
74 EotInnled0/donbt.I 0./once/n 98602090 of 9130112 16,003.09
75 En4ntotod Cnnno/ntine Solon. in 18082050 .0 9/3002 $ (36,85580)
Workpaper No. 6
Case No. INT-G-12-01
Intermountain Gas Company
Page 2 of 2
(NTERS8MN GAS COMPANY 00NT
M.Iy.In of A0000rnt1860 Sonohongo. (Credit.)
Eotbn.t.d September 30, 2012
U.
115- Oo.00hbon Detod P46U M25601, O9i89/( 12)4) (8) (8) (o) ( (.1 07
I FIneA Cut C00050f.od1o19892205.11000I $ 480191I
2 Food ContCnfootoe De40ned 6/19502200 8,,00gh 6130/12 (7,672,526.46)
3 0860,09.4 Food Cn.tCoNe0(oo Dotonned boo, 1/I 60o46h9/30/lZ 8,793,402.62
4 E.tinotod 8o(enno in 18902200 .598052 (673,3011.87
5 Cep.oftyRolooeedlPo,nloned Sefeood In 18802320.510051 $ (1,035,804.14) 6 C460055ReIn.eeAP,0A000d Dnlnnned'e (S6O232/ thorough 8/34/l2 (3,848)(12123)
7E09no95dCeyR08.ee/5Poloned0eIenod (man 7/l 0800gb 9/30(12 (1231,75454) 8 Eollne.todSOI0000initfg.2320ot$130/72 (5,216,580.31)
U l//t.oe.5)n186S.2430.11959/7f $ (50.44)
10 Interest OeIe,nndle 1860.24308000g6830/12 (msa)
II Eofinotod lntonoolSoo, 7/7 80oogh 9/30/12 (74951)
12 Eo9ted 9/done. in 18802430 t 839112 (1.87323)
13 M000g.nonlo(FOpo9nole.00pod2)oe Capacity Dakned in (86025(00(10901 $ (87.062.86) 74 M-9-4 of 750(e. Tr.o.po80ion CgootyDefenod in 186225309noog56,30/12 (4.785,75248)
15E09jo.9.d Do" 6 1840.2530 boo //I 800h 9/30/12 (571.703.00)
IS EefroeIodSoJ.000le 7840,253049/34/13 $ (4,818,569.35)
7755.1 Ano60.loe i 18802550.5830112 8 466,22131
1886001 23 0..402.7 .00 Sotenfrom 71)0461,512012 1,600.164
7900-1 AnolIno9on Rot 5 0.51323 21,15417
20 0850051405-I Mo,,8oe9.o on 18002540019/30112 427,385.48
21 RS-2 kool/oo9on in (860.254646/30112 $ 7,835,535.77
22 E85ootd RS-2 Thor. S.boofron 71I loo.gh95812 17,730,908
23 RS-20884i.0IonR0O $ 0.01157 729.78467 34 EetmoI.d RS-2Monlo86000 78502540 859/30/12 3,544,320.38
25 /354 M,o,006o 1,18002540.10135112 $ 1,050,66852
26 081,0,10455-1 Thono 54.. Iron 1/1 tvongIr 9139112 16,163,405
21 05.7 9/nootobon Rot $ 0.08189 (92.309.88
28 009.0.9.455-I Mon8oedon I. 18802540 009/30112 7342,978.41
29 0.91.084 Coo. UnoolSoton 6,10602510.18130/12 3.834.68427
30 LV-14onoo8no600o18552550e96/30/12 $ 14,938.32 31 0.6/no/ed 87-I BInd, 152 ThonnSal. 90,0 Ill 500099 8130112 781,401
32 1(7.1 Anortooton Rote $ 0.86504 3,888.60
33 E4600hd LV-I MonSoho on (6002550 .19/30/12 55,328.96
34 0860864 k,donOidAnol.o9or, 1o1860,2550.59/30172 13,326.91
35 Eo6o.tod 88080. In 18002320 at 9/30(12 (1,165,557.10)
36 ESTIMATES ACCOUNT 1860 FOXED BALANCE AT 9)30/12 8 (4,864,025 9/75
37 TOTAL DEFERRED ACCOUNT 1860 BALANCE $ (15,689,852,19)
Workpaper No. 7
Case No. INT-G-12-01
Intermountain Gas Company
Page 1 of I
INTERMOUNTAIN GAS COMPANY
Analysis of LVI Tariff Block 1, Block 2, and Block 3 Adjustments
Line Block I Block 2
No. Description Therm Sales Therm Sales
(a) (b) (c)
I LV-1 Therm Sales (I/I/li - 12/31/11) 3,238,019 0
2 Blocks I and 2 Therm Sales 3,238,019 0
3 Percent Therm Sales between Blocks I and 2 100.000% 0.000%
Block 3
Therm Sales
(d)
Total
(e)
0 3,238,019
3,238,019
100.000%
4 Proposed Adjustment to LV-1 Tariff (1)
5 LV-1 Therm Sales (Ill/il - 12/31/11)
6 Annualized Adjustment (Line 4 multiplied by Line 5)
7 Annualized Adjustment (Line 4 multiplied by Line 5)
8 Percent Annualized Sales included in Block I and Block 2
9 Adjustment to Block 1 and 2 (Line 7 multiplied by Line 8)
10 Block 1 and 2 Therms
11 Price Adjustment/Therm Block 1 and 2 (Line 9 divided by Line 10)
12 WACOG Commodity Charge Change (2)
13 Total Price Adjustment/Therm Block 1 and Block 2
14 Price Adjustment/Therm Block 3 (3)
15 WACOG Commodity Charge Change (2)
16 Eliminate INT-G-1 1-01 Variable Temporary
17 Total Price Adjustment/Therm Block 3
(1)See Exhibit No. 4; Line 30, Column (I) minus the difference of Line 21, Column (f) minus Line 21, Column (c)
(2)See Exhibit No. 4; Line 21, Column (f) minus Line 21, Column (c)
(3)See Exhibit No. 6, Line 3, Column (e)
$ 0.03197
3,238,019
$ 103,519
$ 103,519
100.000%
$ 103,519
3,238,019
$ 0.03197
(0.08323)
$ (0.05126)
$ (0.00136)
(0.08323)
0.04017
$ (0.04442)
Workpaper No. 8
Case No. INT-G-12-01
Intermountain Gas Company
Page 1 of I
INTERMOUNTAIN GAS COMPANY
Analysis of Lost and Unaccounted for Gas ("L&U")
Line
No. Description
(a)
1 Lost and Unaccounted for Gas INT-G-12-01 (Therms)
2 Projected Oct 11 - Sep 12 L&U (Therms)
3 Estimated Oct 11 - Sep 12 Sales
4 Oct 11 - Sep 12 L&U Factor (line 2 divided by line 3)
Detail Amount
(b) (c)
4,497,955
592,647,090
0.759%
5 Lost and Unaccounted for Gas INT-G-12-01 (Dollars)
6 Lost & Unaccounted for Gas (1860-2150) 2
7 Estimated Oct 11 - Sep 12 Sales 1
8 L&U rate per therm embedded in base rates
9 Oct 11 - Sep 12 Collection of Lost & Unaccounted for Gas
592,647,090
$ 0.00182
$ 3,139,485
1,078,618
10 Projected L&U (Over)/Under Collection (Line 6 minus Line 9) $ 2,060,867
1 Estimated Oct 11 - Sep 12 Sales (Therms)
RS-1
RS-2
GS-1
Industrial
Total Sales
2 See Workpaper No. 6, Page 1, Line 34, Column (c)
32,937,650
169,920,320
109,074,634
280.714.486
592,647,090