20160812Application.pdf

EXECUTIVE OFFICES
INTERMOUNTAIN GAS COMPANY
555 SOUTH COLE ROAD • P.O. BOX 7608 • BOISE, IDAHO 83707 • [phone] • FAX: [phone]
August 12, 2016
Ms. Jean Jewell
Commission Secretary
Idaho Public Utilities Commission
472 W. Washington St.
P.O. Box 83720
Boise, ID 83720-0074
RE: Case No. INT-G-16-03
Dear Ms. Jewell:
R .:cEIVED
2ulfi r,U G l 2 PM 3: 37
I~' l ( • .. ~ U ~) L.11..1
( ·:1) .. 1 r,1 !SSION
Attached for consideration by this Commission are the original and seven (7) copies of Intermountain Gas
Company's Application for Authority to Change Its Prices on October I, 2016.
If you should have any questions regarding this Application please contact me at 377-6168.
Intermountain Gas Company
Enclosure
cc: Scott Madison
Mark Chiles
Ronald L. Williams
INTERMOUNTAIN GAS COMPANY
CASE NO. INT-G-16-03
APPLICATION,
EXHIBITS,
AND
WORKPAPERS
In the Matter of the Application of INTERMOUNT AIN GAS COMP ANY
For Authority to Change Its Prices on October 1, 2016
(October 1, 2016 Purchased Gas Cost Adjustment Filing)
Ronald L. Williams, ISB 3034
Williams Bradbury PC
1015 W. Hays St.
Boise, Idaho 83 702
Telephone: [phone]
Attorney for Intermountain Gas Company
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
In the Matter of the Application of
INTERMOUNT AIN GAS COMP ANY
Case No. INT-G-16-03
APPLICATION
Intermountain Gas Company ("lntermountain" or "Company"), a subsidiary of MDU
Resources Group, Inc. with general offices located at 555 South Cole Road, Boise, Idaho, pursuant
to the Rules of Procedure of the Idaho Public Utilities Commission ("Commission"), hereby requests
authority, pursuant to Idaho Code Sections 61-307 and 61-622, to place into effect October 1, 2016
new rate schedules which will decrease its annualized revenues by $17.2 million. Because of changes
in Intermountain's gas related costs, as described more fully in this Application, Intermountain's
earnings will not be impacted as a result of the proposed changes in prices and revenues.
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:
Michael P. McGrath
Director -Regulatory Affairs
Intermountain Gas Company
Post Office Box 7608
Boise, ID 83707
and
Ronald L. Williams
Williams Bradbury PC
1015 W. Hays St.
Boise, Idaho 83 702
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 Commission, engaged in the
sale of and distribution of natural gas within the State of Idaho under authority of Commission
Certificate No. 219 issued December 2, 1955, as amended and supplemented by Order No. 6564,
dated October 3, 1962.
Intermountain provides natural gas service to the following Idaho communities and counties
and adjoining areas:
Ada County -Boise, Eagle, Garden City, Kuna, Meridian, and Star;
Bannock County-Arimo, Chubbuck, Inkom, Lava Hot Springs, McCammon, and Pocatello;
Bear Lake County -Georgetown, and Montpelier;
Bingham County -Aberdeen, Basalt, Blackfoot, Firth, Fort Hall, Moreland/Riverside, and Shelley;
Blaine County-Bellevue, Hailey, Ketchum, and Sun Valley;
Bonneville County -Ammon, Idaho Falls, Iona, and Ucon;
Canyon County -Caldwell, Greenleaf, Middleton, Nampa, Parma, and Wilder;
Caribou County -Bancroft, Grace, and Soda Springs;
Cassia County-Burley, Declo, Malta, and Raft River;
Elmore County -Glenns Ferry, Hammett, and Mountain Home;
Fremont County -Parker, and St. Anthony;
Gem County -Emmett;
Gooding County -Gooding, and Wendell;
Jefferson County -Lewisville, Menan, Rigby, and Ririe;
Jerome County-Jerome;
Lincoln County -Shoshone;
Madison County -Rexburg, and Sugar City;
Minidoka County -Heyburn, Paul, and Rupert;
Owyhee County -Bruneau, and Homedale;
Payette County -Fruitland, New Plymouth, and Payette;
Power County -American Falls;
Twin Falls County -Buhl, Filer, Hansen, Kimberly, Murtaugh, and Twin Falls;
Washington County -Weiser.
Intermountain's properties in these locations consist of transmission pipelines, liquefied
natural gas storage facilities, a compressor station, distribution mains, services, meters and regulators,
and general plant and equipment.
II.
Intermountain seeks with this Application to pass through to each of its customer classes
changes in gas related costs resulting from: 1) costs billed to Intermountain from firm transportation
providers including Northwest Pipeline LLC ("Northwest" or "Northwest Pipeline"), 2) a decrease in
Intermountain's Weighted Average Cost of Gas, or "WA COG", 3) an updated customer allocation of
gas related costs pursuant to the Company's Purchased Gas Cost Adjustment ("PGA") provision, 4)
APPLICATION - 3
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 ofits 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 Case No. INT-G-15-02.
The aforementioned changes would result in a price decrease to Intermountain's RS-I, RS-2, GS-I,
L V-1 and T-3 customers, and a price increase to Intermountain' s T-4 and T-5.
These price changes are applicable to service rendered under rate schedules affected by and
subject to Intermountain's PGA, initially approved by this Commission in Order No. 26109, Case No.
INT-G-95-1, and additionally approved through subsequent proceedings.
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. 33386, Case No. INT-G-15-02.
IV.
Intermountain's proposed prices incorporate all changes in costs relating to the Company's
firm interstate transportation capacity including, but not limited to, any price changes or projected
cost adjustments implemented by the Company's pipeline suppliers as well as any volumetric
adjustments in contracted transportation agreements which have occurred since Intermountain's
PGA filing in Case No. INT-G-15-02.
The permanent transportation and storage costs included with this Application reflect a net
decrease of approximately $160,000 as compared to those same costs included in Case No. INT­
G-15-02. The Company's Application includes the benefits of the renegotiation of a previously
full-rate contract which was converted to a discounted rate contract. Additionally, Northwest
Pipeline transportation and storage costs reflect the removal of the extra day from the 2015 leap
year included in Case No. INT-G-15-02 resulting in a reduction in annual transportation and storage
costs to the Company's customers. The Company's upstream transportation charges also had a net
APPLICATION - 4
decline resulting from rate changes from all three of the Company's upstream transportation
providers.
Intermountain continues to effectively manage its natural gas storage assets at Northwest's
Jackson Prairie and Questar Pipeline's Clay Basin storage facilities. Supporting documents
relating to Line 20 of Exhibit No. 4 include $1.8 million in savings from Intermountain's
management of these storage assets.
Exhibit No. 4, Lines 1 through 20, details the proposed changes to Intermountain's prices
resulting from Intermountain's cost of storage, and interstate and upstream capacity from its
various suppliers.
V.
The WACOG reflected in Intermountain's proposed prices is $0.29695 per therm, as shown
on Exhibit No. 4, Line 22, Col. (f). This compares to $0.32764 per therm currently included in the
Company's tariffs, or a 9.4% reduction in the customer's WACOG.
Advanced drilling technologies continue to increase drilling efficiencies resulting in even
higher production in shale gas wells. Deliverable shale gas reserves in North America are abundant
and supplies, in the face of growing demand for natural gas, have continued to outpace the demand
for this natural resource. This supply/demand imbalance has contributed greatly to the decrease in the
Company's WACOG. From a historical perspective, robust natural gas supplies combined with
significant storage balances have kept natural gas prices lower as compared to just a year ago.
Additionally, the proposed WACOG includes benefits to Intermountain's customers
generated by the Company's management of its significant natural gas storage assets. Because gas
added to storage is procured during the summer season when prices are typically lower than during
the winter, the cost of Intermountain's storage gas is normally less than what could be obtained on
the open market in winter months. Additionally, in an effort to further stabilize the prices paid by our
customers during the upcoming winter period, Intermountain has entered into various fixed price
agreements to lock-in the price for portions of its underground storage and other winter "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 2016-201 7 PGA period. Intermountain will employ, in addition to those
fixed price agreements already in place, cost effective price arrangements to further secure the price
APPLICATION - 5
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
make informed and appropriate energy use decisions. The Company is committed to alert customers
to any significant impending price changes before their winter natural gas usage occurs. By
employing the 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 any pending natural gas price
changes.
VI.
Pursuant to the Commission's Order in Case No. INT-G-15-02, Intermountain included
temporary credits in its October 1, 2015 prices for the principal reason of passing back to its customers
deferred gas cost benefits. Line 27 of Exhibit No. 4 reflects the elimination of these temporary credits.
VII.
Intermountain's PGA tariff includes provisions whereby Intermountain's proposed prices will
be adjusted for updated customer class sales volumes and purchased gas cost allocations, 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
25. The price impact of this adjustment is included on Exhibit No. 4, Line 28. The Fixed Cost
Collection Rate resulting from the adjustment plus the annual difference in demand charges from
Exhibit No. 4, Lines 1 -20, Col. (h) is shown on Exhibit No. 5, Line 29. 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 $3.9 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. 191 balance to its
customers through temporary price adjustments to be effective during the 12-month period ending
September 30, 2017, as follows:
1) Intermountain has deferred fixed gas costs in its Account No. 191. The credit amount
shown on Exhibit No. 8, Line 7, Col. (b) of $7.3 million is attributable to a true-up of the collection
of interstate pipeline capacity costs, the true-up of expense issues previously ruled on by this
Commission, and mitigating capacity release credits generated from the incremental release of
Intermountain's pipeline capacity. Intermountain proposes to true-up these balances via the per therm
debits and credits, as detailed on Exhibit No. 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. 191 a variable gas cost credit of $1.9
million, as shown on Exhibit No. 9, Line 2, Col. (b). This deferred credit is attributable to
Intermountain's variable gas costs since October 1, 2015. Intermountain proposes to pass back this
balance via a per therm credit, as shown on Exhibit No. 9, Line 4, Col. (b) and included on Exhibit
No. 6, Line 3.
3) Finally, Intermountain has deferred in its Account No. 191 deferred gas costs related to
Lost and Unaccounted for Gas as shown on Exhibit No. 9, Lines 5 through 20, Col. (b ). This deferral
results in net per therm decreases 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
results in a per therm decrease 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.
X.
Pursuant to Commission Order No. 33386, Case No. INT-G-15-02, Intermountain has
deferred in its Account No. 191 variable gas cost credits associated with sales of liquefied natural gas
at its Nampa, Idaho facility. Intermountain proposes to pass back this $236,805 sales credit as outlined
on Exhibit No. 10, Line 7. Exhibit No. 10 is attached hereto and incorporated herein by reference.
APPLICATION - 7
XI.
Intermountain has allocated the proposed price decreases 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 L V-1 tariff as no fixed costs are currently recovered in the tail block of the L V-1 tariff.
The proposed changes in the W ACOG, and variable deferred debits and credits as outlined on Exhibit
No.' s 9 and 10, are applied to all three blocks of the L V-1 tariff. However, all adjustments relating to
fixed costs are applied only to the first two blocks of the L V-1 tariff.
XII.
As outlined on Exhibit No. 1, Page 1, Lines 33 through 44, the T-3, T-4 and T-5 tariffs
include the following adjustments: a) removal of existing temporary price changes; b) the uniform
Lost and Unaccounted For Gas decrease from Exhibit No. 9, Line 20, Col. (b) is applied to each tariff;
and c). the LNG Sales Credits are applied to T-4 and T-5 as illustrated on Exhibit No. 10, Line 7,
Cols. (g-h). The net change from these aforementioned adjustments result in a rate decrease for the
Company's T-3 Customers and rate increase for the Company's T-4 and T-5 customers.
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 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 has been brought to the attention of Intermountain's customers through a
Customer Notice and by a Press Release sent to daily and weekly newspapers, and major radio and
television stations in Intermountain's service area. The Press Release and Customer Notice are
attached hereto and incorporated herein by reference. Copies of this Application, its Exhibits, and
Workpapers have been provided to those parties regularly intervening in Intermountain's rate
proceedings.
APPLICATION - 8
XVI.
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.
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, 2016 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 12th day of August, 2016.
INTERMOUNTAIN GAS COMP ANY Williams Bradbury PC
By RA rv~
Ronald L. Williams
Attorney for Intermountain Gas Company
APPLICATION - 9
CERTIFICATE OF MAILING
I HEREBY CERTIFY that on this 12th day of August, 2016, I served a copy of the
foregoing Case No. INT-G-16-03 upon:
Ed Finklea
Northwest Industrial Gas Users
545 Grandview Drive
Ashland, OR 97520
Don Sturtevant
J. R. Simplot Company
PO Box 27
Boise, ID 83707
Chad Stokes
Cable Huston et al.
1001 SW Fifth Avenue, Suite 2000
Portland, Oregon 97204-1136
by depositing true copies thereof in the United States Mail, postage prepaid, in envelopes addressed
to said persons at the above addresses.
APPLICATION -10
EXHIBIT NO. 1
CASE NO. INT-G-16-03
INTERMOUNTAIN GAS COMPANY
CURRENT TARIFFS
Showing Proposed Price Changes
(12 pages)
Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
INTERMOUNTAIN GAS COMPANY
Comparison of Proposed October 1, 2016 Prices
To October 1, 2015 Prices
Prices per Proposed
Rate Class INT -G-15-02 Adjustment
(a) (b) (c)
RS-1
April . November $ 0.87267 $ (0.05776)
December· March 0.76011 (0.05776)
RS-2
April -November 0.71185 (0.05678)
December -March 0.67822 (0.05678)
GS-1
April -November
Block 1 0.72918 (0.05071)
Block 2 0.70745 (0.05071)
Block 3 0.68643 (0.05071)
December -March
Block 1 0.67833 (0.05071)
Block 2 0.65713 (0.05071)
Block 3 0.63667 (0.05071)
CNG Fuel 0.63667 (0.05071)
1S-R111
April -November 0.67822 (0.05678)
December -March 0.67822 (005678)
is-c121
April -November
Block 1 0.67833 (0.05071)
Block 2 0.65713 (0.05071)
Block 3 0.63667 (0.05071)
December -March
Block 1 0.67833 (0.05071)
Block 2 0.65713 (0.05071)
Block 3 0.63667 (0.05071)
LV-1
Block 1 0.49512 (0.08739) 131
Block 2 0.45663 (0.08739) (3)
Block 3 0.33442 (0.03798) 1'1
T-3
Block 1 0.05465 (0.00002) (5)
Block 2 0.02205 (0.00002) (5)
Block 3 0.00792 (0.00002) (5)
T-4
Block 1 0.05777 0.00086 161
Block 2 0.01928 0.00086 161
Block 3 0.00455 0.00086 161
T·S
Demand Charge 0.84253
Commodity Charge 0.00111 0.00022 161
Over-Run Service 0.04370 0.00022 l5l
Proposed
October 1, 2016
Prices
(d)
$ 0.81491
0.70235
0.65507
0.62144
0.67847
0.65674
0.63572
0.62762
0.60642
0.58596
0.58596
0.62144
0.62144
0.62762
0.60642
0.58596
0.62762
0.60642
0.58596
0.40773
0.36924
0.29644
0.05463
0.02203
0.00790
0.05863
0.02014
0.00541
0.84253
0.00133
0.04392
l'lThe IS-R price is based on the RS-2 December-March price and receives the same PGA adjustments.
l'IThe IS-C price is based on the GS-1 December-March price and receives the same PGA adjustments.
131 See Workpaper No. 6, Line 13, Column (e)
1'1 See Workpaper No. 6, Line 17, Column (e)
151 Remove INT-G-15-02 temporary and add the temporary from Exhibit No. 9, Line 20.
1'1 Remove INT-G-15-02 temporary and add the temporaries from Exhibit No. 9, Line 20 and Exhibit No. 10, Line 7.
Exhibit No. 1
Case No. INT-G-16-03
lntermountain Gas Company
Page 1 of 12
Line
No.
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
INTERMOUNTAIN GAS COMPANY
Summary of Proposed Tariff Components
Description RS-1 RS-2
(a) (b) (c)
Cost of Gas:
Temporary purchased gas cost adjustment '1l $ (0.04254) $ (0.04388)
Weighted Average Cost of Gas '2l 0.29695 0.29695
Gas Transportation Cost C3> 0.24372 0.20600
Total Proposed Cost of Gas $ 0.49813 $ 0.45907
Distribution Cost: C4l
April through November
Block 1 $ 0.31678 $ 0.19600
Block 2
Block 3
December through March
Block 1 $ 0.20422 $ 0.16237
Block 2
Block 3
Proi;iosed Prices
April through November
Block 1 $ 0.81491 $ 0.65507
Block 2
Block 3
December through March
Block 1 $ 0.70235 $ 0.62144
Block 2
Block 3
'1l See Exhibit No. 6, Line 5, Columns (b) -(e)
'2l See Exhibit No. 4, Line 22, Column (D
C3l See Exhibit No. 5, Line 29, Columns (e) -(h)
C4l See Case No. U-1034-122
C5l LV-1 Block 3 is Exhibit No. 6, Column (e); Line 3 plus Line 4 only. A credit of ($0.00712).
C5> LV-1 Block 3 Cost of Gas only includes ($0.00712) from Footnote 5, plus Line 2, Column (e).
$
$
$
$
$
$
Exhibit No. 1
Case No. INT-G-16-03
lntermountain Gas Company
Page 2 of 12
GS-1 LV-1
(d) (e)
(0.05144) $ (0.02443) (5)
0.29695 0.29695
0.21545 0.07065
0.46096 $ 0.34317
0.21751 $ 0.06456
0.19578 0.02607
0.17476 0.00661
0.16666 $ 0.06456
0.14546 0.02607
0.12500 0.00661
0.67847 $ 0.40773
0.65674 0.36924
0.63572 0.29644 (5)
0.62762 $ 0.40773
0.60642 0.36924
0.58596 0.29644 (5)
I.P.U.C. Gas Tariff
Rate Schedules
~ Revised Fifty-First Sheet No. 01 (Page 1 of 1)
Name
of Utility lntermountain Gas Company
APPLICABILITY:
Rate Schedule RS-1
RESIDENTIAL SERVICE
Exhibit No. 1
Case No. INT-G-16-03
lntermountain Gas Company
Page 3 of 12
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
June 29, 2916 July 1, 2916
Jean D. Jewell Secretary
Applicable to any customer using natural gas for residential purposes, who does not have both natural gas
water heating and natural gas space heating.
RATE:
Monthly minimum charge is the customer charge.
For billing periods ending April through November
Customer Charge -$2.50 per bill
Per Therm Charge -$0.87267* $0.81491
For billing periods ending December through March
Customer Charge -$6.50 per bill
Per Therm Charge -$0.76011* $0.70235
*Includes the following:
Cost of Gas:
Distribution Cost:
1) Temporary purchased gas cost adjustment
2) Weighted average cost of gas
3) Gas transportation cost
April through November
December through March
PURCHASED GAS COST ADJUSTMENT:
($0.0008§)
$0.32764
$0.22910
$0.31678
$0.20422
($0.04254)
$0.29695
$0.24372
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company's Purchased
Gas Cost Adjustment Schedule.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the Company's Tariff, of
which this rate schedule is a part.
issued by: lntermountain Gas Company
By: Michael P. McGrath Title: Director -Regulatory Affairs
Effective: .My-+, 2016 October 1, 2016
I.P.U.C. Gas Tariff
Rate Schedules
RflielR Revised Fifty-First Sheet No. 02 (Page 1 of 1)
Name
of Utility lntermountain Gas Company
Rate Schedule RS-2
Exhibit No. 1
Case No. INT-G-16-03
lntermountain Gas Company
Page 4 of 12
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
June 20, 2016 July 1, 2016
Jean D. Jewell Secretary
RESIDENTIAL SERVICE-SPACE AND WATER HEATING
APPLICABILITY:
Applicable to any customer using natural gas for residential purposes, which must include at a minimum,
both natural gas water heating and natural gas space heating.
RATE:
Monthly minimum charge is the customer charge.
For billing periods ending April through November
Customer Charge -$2.50 per bill
Per Therm Charge -$Q.71186* $0.65507
For billing periods ending December through March
Customer Charge -$6.50 per bill
Per Therm Charge -$G.e7822* $0.62144
*Includes the following:
Cost of Gas:
Distribution Cost:
1) Temporary purchased gas cost adjustment
2) Weighted average cost of gas
3) Gas transportation cost
April through November
December through March
PURCHASED GAS COST ADJUSTMENT:
($G.GG9e8)
$G.327e4
$Q.1Q78Q
$0.19600
$0.16237
($0.04388)
$0.29695
$0.20600
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company's
Purchased Gas Cost Adjustment Schedule.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the Company's Tariff, of
which this rate schedule is a part.
issued by: lntermountain Gas Company
By: Michael P. McGrath Title: Director -Regulatory Affairs
Effective: ..My+,-2016 October 1. 2016
Exhibit No. 1
Case No. INT-G-16-03
lntermountain Gas Company
Page 5 of 12
I.P.U.C. Gas Tariff
Rate Schedules IDAHO PUBLIC UTILITIES COMMISSION
Fifi) Second Revised Fifty-Third Sheet No. 03 ( Page 1 of 2)
Name
of Utility lntermountain Gas Company
APPLICABILITY:
Rate Schedule GS-1
GENERAL SERVICE
Approved Effective
Jtme 28, 2816 Jttly 1, 2816
Jean D. Jewell Secretary
Applicable to customers whose requirements for natural gas do not exceed 2,000 therms per day, at any point
on the Company's distribution system. Requirements in excess of2,000 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 -$2.00 per bill
Per Therm Charge -First
Next
Over
200 therms per bill@ $0.72916* $0.67847
1,800 therms per bill @ $0. 70745* S0.65674
2,000 therms per bill @ $9.68643* $0.63572
For billing periods ending December through March
Customer Charge -$9.50 per bill
Per Therm Charge -First 200 therms per bill @ $0.67633* $0.62762
Next 1,800 therms per bill@ $0.65713* $0.60642
Over 2,000 therms per bill@ $9.63667* $0.58596
*Includes the following:
Cost of Gas:
Distribution Cost:
1) Temporary purchased gas cost adjustment
2) Weighted average cost of gas
3) Gas transportation cost
April through November:
First 200 therms per bill @
Next 1,800 therms per bill @
Over 2,000 therms per bill @
December through March
First 200 therms per bill @
Next 1,800 therms per bill @
Over 2,000 therms per bill @
Issued by: lntermountain Gas Company
By: Michael P. McGrath Title: Director -Regulatory Affairs
Effective: dttly 1, 2016 October 1• 2016
($0.01323) ($0.05144)
$9.32764 $0.29695
$0. 19726 $0.21545
$0.21751
$0.19578
$0.17476
$0.16666
$0.14546
$0.12500
I.P.U.C. Gas Tariff
Rate Schedules
Fift9-Seco11d Revised Fifty-Third Sheet No. 03 ( Page 2 of 2)
Name • G C ot utility lntermountam as ompany
Rate Schedule GS-1
GENERAL SERVICE
(Continued)
Exhibit No. 1
Case No. INT-G-16-03
lntermountain Gas Company
Page 6 of 12
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Jolie 26, 2618 .:l1:1ly 1, 2816
Jean D. Jewell Secretary
For separately metered deliveries of gas utilized solely as Compressed Natural Gas Fuel in vehicular internal
combustion engines.
Customer Charge -$9.50 per bill
Per Thenn Charge -$0.63667 * $0.58596
*Includes the following:
Cost of Gas: 1) Temporary purchased gas cost adjustment
2) Weighted average cost of gas
3) Gas transportation cost
Distribution Cost:
PURCHASED GAS COST ADJUSTMENT:
($0.01323) ($0.05144)
$8.32764 $0.29695
$8.19726 $0.21545
$0.12500
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company's Purchased
Gas Cost Adjustment Schedule.
SERVICE CONDITIONS:
1. All natural gas service hereunder is subject to the General Service Provisions of the Company's Tariff,
of which this rate schedule is a part.
BILLING ADJUSTMENTS:
1. Any GS-1 customer who leaves the GS-1 service will pay to lntermountain Gas Company, upon exiting
the GS-1 service, all gas and transportation related costs incurred to serve the customer during the GS-
1 service period not paid by the customer during the time the customer was using GS-1 service. Any
GS-1 customer who leaves the GS-1 service will have refunded to them, upon exiting the GS-1 service,
any excess gas commodity or transportation payments made by the customer during the time they were
a GS-1 customer.
Issued by: lntermountain Gas Company
By: Michael P. McGrath Title: Director-Regulatory Affairs
Effective: dtil~ 1, 2016 October 1, 2016
I.P.U.C. Gas Tariff
Rate Schedules
Niffll't Revised Tenth Sheet No. 4 /Page 1 of 2)
Name
of Utility lntermountain Gas Company
Rate Schedule IS-R
Exhibit No. 1
Case No. INT-G-16-03
lntermountain Gas Company
Page 7 of 12
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
dtme 28, 2846 July 1, 2018
Jean D. Jewell Secretary
RESIDENTIAL INTERRUPTIBLE SNOWMEL T SERVICE
APPLICABILITY:
Applicable to any residential customer otherwise eligible to receive service under Rate Schedule RS-1 or
RS-2 who has added natural gas snowmelt equipment after 6/1/2010. The intended use of the snowmelt
equipment is to melt snow and/or ice on sidewalks, driveways or any other similar appurtenances. Any and
all such applications meeting the above criteria will be subject to service under Rate Schedule IS-R and will
be separately and individually metered. All service hereunder is interruptible at the sole discretion of the
Company.
FACILITY REIMBURSEMENT CHARGE:
All new interruptible Snowmelt service customers are required to pay for the cost of the Snowmelt meter set
and other related facility and equipment costs, prior to the installation of the meter set. Any request to alter
the physical location of the meter set and related facilities from Company's initial design may be granted
provided, however, the Company can reasonably accommodate said relocation and Customer agrees to
pay all related costs.
RATE:
Monthly minimum charge is the Customer Charge.
For billing periods ending April through November
Customer Charge -$2.50 per bill
Per Therm Charge -$0.67822* $0.62144
For billing periods ending December through March
Customer Charge -$6.50 per bill
Per Therm Charge -$0.67622* $0.62144
*Includes the following:
Cost of Gas: 1) Temporary purchased gas cost adjustment
2) Weighted average cost of gas
3) Gas transportation cost
Distribution Cost:
PURCHASED GAS COST ADJUSTMENT:
($0.00966) ($0.04388)
$0.3276-4 $0.29695
$0.19769 $0.20600
$0.16237
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company's Purchased
Gas Cost Adjustment Schedule.
Issued by: lntermountain Gas Company
By: Michael P. McGrath Title: Director -Regulatory Affairs
Effective: July 1, 2016 October 1, 2016
Exhibit No. 1
Case No. INT-G-16-03
lntermountain Gas Company
Page 8 of 12
1.P.U.C. Gas Tariff
Rate Schedules
-Niffitt Revised Tenth Sheet No. 5 {Paae 1 of 2) IDAHO PUBLIC UTILITIES COMMISSION
Name
of Utility
Approved Effective
lntermountain Gas Company .:l1:1ne 28, 2816 July 1, 2018
Jean D. Jewell Secretary
Rate Schedule IS-C
SMALL COMMERICAL INTERRUPTIBLE SNOWMEL T SERVICE
APPLICABILITY:
Applicable to any customer otherwise eligible to receive gas service under Rate Schedule GS-1 who has
added natural gas snowmelt equipment after 6/1/2010. The intended use of the snowmelt equipment is to
melt snow and/or ice on sidewalks, driveways or any other similar appurtenances. Any and all such
applications meeting the above criteria will be subject to service under Rate Schedule IS-C and will be
separately and individually metered. All service hereunder is interruptible at the sole discretion of the
Company.
FACILITY REIMBURSEMENT CHARGE:
All new interruptible Snowmelt service customers are required to pay for the cost of the Snowmelt meter set
and other related facility and equipment costs, prior to the installation of the meter set. Any request to alter
the physical location of the meter set and related facilities from Company's initial design may be granted
provided, however, the Company can reasonably accommodate said relocation and Customer agrees to pay
all related costs.
RATE:
Monthly minimum charge is the Customer Charge.
For billing periods ending April through November
Customer Charge -$2.00 per bill
Per Therm Charge -First
Next
Over
200 therms per bill @ $0.67633*
1,800 therms per bill @ $0.65713*
2,000 therms per bill @ $0.63667*
For billing periods ending December through March
Customer Charge -$9.50 per bill
Per Therm Charge -First 200 therms per bill @ $0.67833*
Next 1,800 therms per bill @ $0.65713*
Over 2,000 therms per bill @ $0.63667*
*Includes the following:
$0.62762
$0.60642
$0.58596
$0.62762
$0.60642
$0.58596
Cost of Gas: 1) Temporary purchased gas cost adjustment ($0.01323) ($0.05144)
Distribution Cost:
2) Weighted average cost of gas
3) Gas transportation cost
First
Next
Over
200 therms per bill @
1,800 therms per bill @
2,000 therms per bill @
Issued by: lntermountain Gas Company
By: Michael P. McGrath Title: Director -Regulatory Affairs
Effective: July 1, 2016 October 1. 2016
$0.3276,4 $0.29695
$0.19726 $0.21545
$0.16666
$0.14546
$0.12500
Exhibit No. 1
Case No. INT-G-16-03
lntermountain Gas Company
Page 9 of 12
I.P.U.C. Gas Tariff
Rate Schedules ~ Revised Sixty-First Sheet No. 7 ( Paae 1 of 2) IDAHO PUBLIC UTILITIES COMMISSION
Name
of Utilitv
Approved Effective
lntermountain Gas Company June 26, 2618 dtily 1, 2816
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 customer not previously served
under this schedule whose usage does not exceed 500,000 therms annually, upon execution of a one-year
minimum written service contract for firm sales service in excess of 200,000 therms per year.
MONTHLY RATE:
Per Therm Charge:
Block One: First
Block Two: Next
Block Three: Amount Over
250,000 therms per bill@ $0.49512* $0.40773
500,000 therms per bill @ $0.45663* $0.36924
750,000 therms per bill @ $0.33442* $0.29644
*Includes the following:
Cost of Gas: 1) Temporary purchased gas cost adjustment
Block One and Two
Block Three
2) Weighted average cost of gas
3) Gas transportation cost (Block One and Two only)
Distribution Cost: Block One
Block Two
Block Three
PURCHASED GAS COST ADJUSTMENT:
($0.02707)
$0.00017
$0.32r64
$0.12999
$0.06456
$0.02607
$0.00661
($0.02443)
{$0.00712)
$0.29695
$0.07065
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company's Purchased
Gas Cost Adjustment Schedule.
SERVICE CONDITIONS:
1. All natural gas service hereunder is subject to the General Service Provisions of the Company's
Tariff, of which this Rate Schedule is a part.
2. The customer shall negotiate with the Company, a Maximum Daily Firm Quantity (MDFQ) amount,
which will be stated in and will be in effect throughout the term of the service contract.
In the event the Customer requires daily usage in excess of the MDFQ, and subject to the
availability of firm interstate transportation to serve lntermountain's system, all such usage may
be transported and billed under either secondary rate schedule T-3 or T-4. The secondary rate
schedule to be used shall be predetermined by negotiation between the Customer and Company,
and shall be included in the service contract. All volumes transported under the secondary rate
schedule are subject to the provisions of the applicable rate schedule T-3 or T-4.
Issued by: lntermountain Gas Company
By: Michael P. McGrath Title: Director -Regulatory Affairs
Effective: dttl) 1, 2016 October 1. 2016
I.P.U.C. Gas Tariff
Rate Schedules
Efe'lfe1'ltl, Revised lYil!J.f1b... Sheet No. 8 ( Paoe 1 of 2)
Name
of Utilitv lntermountain Gas Company
Rate Schedule T-3
Exhibit No. 1
Case No. INT-G-16-03
lntermountain Gas Company
Page 10 of 12
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Sept. 29, 2815 Oct. 1, 2815
Per O.N. 33386
Jean D. Jewell Secretary
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@ $0.05465* $0.05463
Block Two: Next 50,000 therms transported@ $0.02205* ~
Block Three: Amount over 150,000 therms transported @ $0.00:792* S0.00790
*Includes temporary purchased gas cost adjustment of $(0.00095) $(0.00097)
ANNUAL MINIMUM BILL:
The customer shall be subject to the payment of an annual minimum bill of $30,000 during each annual
contract period, unless a higher minimum is required under the service contract to cover special
conditions.
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company's Purchased
Gas Cost Adjustment Schedule.
SERVICE CONDITIONS:
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 immediately curtail or interrupt its
operations during periods of capacity constraints on the Company's 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 lntermountain'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: lntermountain Gas Company
By: Michael P. McGrath Title: Director -Regulatory Affairs
Effective: Oetober 1, 2015 October 1, 2016
I.P.U.C. Gas Tariff
Rate Schedules
"Tent!, Revised ~ Sheet No. 9 ( PaQe 1 of 2)
Name
of Utilitv lntermountain Gas Company
Rate Schedule T-4
Exhibit No. 1
Case No. INT-G-16-03
lntermountain Gas Company
Page 11 of 12
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Sept. 29, 2815 Oct. 1, 2815
Per 0.N. 33386
Jean D. Jewell Secretary
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:
Block Two:
Block Three:
First
Next
Amount over
250,000 therms transported @ $0.05777* S0.05863
500,000 therms transported @ $0.01928* so.02014
750,000 therms transported @ $0.00-455* $0.00541
*Includes temporary purchased gas cost adjustment of $(0.00zOO) $(0.00120)
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company's Purchased
Gas Cost Adjustment Schedule.
SERVICE CONDITIONS:
1. This service excludes the service and cost of firm interstate pipeline charges.
2. The customer is responsible for procuring its own supply of natural gas and interstate
transportation under this Rate Schedule. The customer understands and agrees that the Company
is not responsible to deliver gas supplies to the customer which have not been nominated,
scheduled, and delivered by the interstate pipeline to the designated city gate.
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:
1. In the event that total deliveries to any existing T-4 customer within the most recent 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 1 rate. The customer's future eligibility for the T -4 Rate Schedule will be
renegotiated with the Company.
Issued by lntermountain Gas Company
By: Michael P. McGrath Title: Director -Regulatory Affairs
Effective: Oeteber 1, 2015 October 1, 2016
I.P.U.C. Gas Tariff
Rate Schedules
-NifflA Revised ~ Sheet No. 1 O /Paae 1 of 2)
Name
of Utility lntermountain Gas Company
Rate Schedule T-5
Exhibit No. 1
Case No. INT-G-16-03
lntermountain Gas Company
Page 12 of 12
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Sept. 29, 2815 Oct. 1, 2815
Per O.N. 33386
Jean D. Jewell Secretary
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
$0.00111* $0.00133
$0.04370* $0.04392
*Includes temporary purchased gas cost adjustment of $(e.ee135) $(0.00113)
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company's Purchased
Gas Cost Adjustment Schedule.
SERVICE CONDITIONS:
1. 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.
5. All therms not billed at the commodity charge for firm therms transported rate will be billed
at the Overrun Service rate.
issued by: lntermountain Gas Company
By: Michael P. McGrath Title: Director -Regulatory Affairs
Effective: Oetobe1 1, 2015 October 1, 2016
EXHIBIT NO. 2
CASE NO. INT-G-16-03
INTERMOUNTAIN GAS COMPANY
PROPOSED TARIFFS
(10 pages)
I.P.U.C. Gas Tariff
Rate Schedules
Fifty-First Revised Sheet No. 01 (Page 1 of 1)
Name
of Utility lntermountain Gas Company
APPLICABILITY:
Rate Schedule RS-1
RESIDENTIAL SERVICE
Exhibit No. 2
Case No. INT-G-16-03
lntermountain Gas Company
Page 1 of 10
Applicable to any customer using natural gas for residential purposes, who does not have both natural gas
water heating and natural gas space heating.
RATE:
Monthly minimum charge is the customer charge.
For billing periods ending April through November
Customer Charge -$2.50 per bill
Per Therm Charge -$0.81491 *
For billing periods ending December through March
Customer Charge -$6.50 per bill
Per Therm Charge -$0. 70235*
*Includes the following:
Cost of Gas:
Distribution Cost:
1) Temporary purchased gas cost adjustment
2) Weighted average cost of gas
3) Gas transportation cost
April through November
December through March
PURCHASED GAS COST ADJUSTMENT:
($0.04254)
$0.29695
$0.24372
$0.31678
$0.20422
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company's Purchased
Gas Cost Adjustment Schedule.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the Company's Tariff, of
which this rate schedule is a part.
Issued by: lntermountain Gas Company
By: Michael P. McGrath Title: Director -Regulatory Affairs
Effective: October 1, 2016
I.P.U.C. Gas Tariff
Rate Schedules
Fifty-First Revised Sheet No. 02 (Page 1 of 1)
Name
of Utility lntermountain Gas Company
Rate Schedule RS-2
Exhibit No. 2
Case No. INT-G-16-03
lntermountain Gas Company
Page 2 of 10
RESIDENTIAL SERVICE-SPACE AND WATER HEATING
APPLICABILITY:
Applicable to any customer using natural gas for residential purposes, which must include at a minimum,
both natural gas water heating and natural gas space heating.
RATE:
Monthly minimum charge is the customer charge.
For billing periods ending April through November
Customer Charge -$2.50 per bill
Per Therm Charge -$0.65507*
For billing periods ending December through March
Customer Charge -$6.50 per bill
Per Therm Charge -$0.62144*
*Includes the following:
Cost of Gas:
Distribution Cost:
1) Temporary purchased gas cost adjustment
2) Weighted average cost of gas
3) Gas transportation cost
April through November
December through March
PURCHASED GAS COST ADJUSTMENT:
($0.04388)
$0.29695
$0.20600
$0.19600
$0.16237
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company's
Purchased Gas Cost Adjustment Schedule.
SERVICE CONDITIONS:
All natural gas service hereunder is subject to the General Service Provisions of the Company's Tariff, of
which this rate schedule is a part.
Issued by: lntermountain Gas Company
By: Michael P. McGrath Title: Director-Regulatory Affairs
Effective: October 1, 2016
I.P.U.C. Gas Tariff
Rate Schedules
Fifty-Third Revised Sheet No. 03 ( Page 1 of 2)
Name
of Utility lntermountain Gas Company
APPLICABILITY:
Rate Schedule GS-1
GENERAL SERVICE
Exhibit No. 2
Case No. INT-G-16-03
lntermountain Gas Company
Page 3 of 10
Applicable to customers whose requirements for natural gas do not exceed 2,000 therms per day, at any point
on the Company's distribution system. Requirements in excess of 2,000 therms per day may be served under
this rate schedule upon execution of a one-year written service contract.
RATE:
Monthly minimum charge is the customer charge.
For billing periods ending April through November
Customer Charge -$2.00 per bill
Per Therm Charge -First 200 therms per bill@ $0.67847*
Next 1,800 therms per bill @$0.65674*
Over 2,000 therms per bill@ $0.63572*
For billing periods ending December through March
Customer Charge -$9.50 per bill
Per Therm Charge -First 200 therms per bill @ $0.62762*
*Includes the following:
Cost of Gas:
Distribution Cost:
Next 1,800 therms per bill @ $0.60642*
Over 2,000 therms per bill@ $0.58596*
1) Temporary purchased gas cost adjustment
2) Weighted average cost of gas
3) Gas transportation cost
April through November:
First 200 therms per bill @
Next 1,800 therms per bill @
Over 2,000 therms per bill@
December through March
First 200 therms per bill @
Next 1,800 therms per bill @
Over 2,000 therms per bill @
Issued by: lntermountain Gas Company
By: Michael P. McGrath Title: Director-Regulatory Affairs
Effective: October 1, 2016
($0.05144)
$0.29695
$0.21545
$0.21751
$0.19578
$0.17476
$0.16666
$0.14546
$0.12500
I.P.U.C. Gas Tariff
Rate Schedules
Fifty-Third Revised Sheet No. 03 ( Page 2 of 2)
Name
of Utility lntermountain Gas Company
Rate Schedule GS-1
GENERAL SERVICE
(Continued)
Exhibit No. 2
Case No. INT-G-16-03
lntermountain Gas Company
Page 4 of 10
For separately metered deliveries of gas utilized solely as Compressed Natural Gas Fuel in vehicular internal
combustion engines.
Customer Charge -$9.50 per bill
Per Therm Charge -$0.58596*
*Includes the following:
Cost of Gas: 1) Temporary purchased gas cost adjustment
2) Weighted average cost of gas
3) Gas transportation cost
Distribution Cost:
PURCHASED GAS COST ADJUSTMENT:
($0.05144)
$0.29695
$0.21545
$0.12500
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company's Purchased
Gas Cost Adjustment Schedule.
SERVICE CONDITIONS:
1. All natural gas service hereunder is subject to the General Service Provisions of the Company's Tariff,
of which this rate schedule is a part.
BILLING ADJUSTMENTS:
1. Any GS-1 customer who leaves the GS-1 service will pay to lntermountain Gas Company, upon exiting
the GS-1 service, all gas and transportation related costs incurred to serve the customer during the GS-
1 service period not paid by the customer during the time the customer was using GS-1 service. Any
GS-1 customer who leaves the GS-1 service will have refunded to them, upon exiting the GS-1 service,
any excess gas commodity or transportation payments made by the customer during the time they were
a GS-1 customer.
Issued by: lntermountain Gas Company
By: Michael P. McGrath Title: Director-Regulatory Affairs
Effective: October 1, 2016
I.P.U.C. Gas Tariff
Rate Schedules
Tenth Revised Sheet No. 4 (Paoe 1 of 2)
Name
of Utility lntermountain Gas Company
Rate Schedule IS-R
Exhibit No. 2
Case No. INT-G-16-03
lntermountain Gas Company
Page 5 of 10
RESIDENTIAL INTERRUPTIBLE SNOWMEL T SERVICE
APPLICABILITY:
Applicable to any residential customer otherwise eligible to receive service under Rate Schedule RS-1 or
RS-2 who has added natural gas snowmelt equipment after 6/1/2010. The intended use of the snowmelt
equipment is to melt snow and/or ice on sidewalks, driveways or any other similar appurtenances. Any and
all such applications meeting the above criteria will be subject to service under Rate Schedule IS-R and will
be separately and individually metered. All service hereunder is interruptible at the sole discretion of the
Company.
FACILITY REIMBURSEMENT CHARGE:
All new interruptible Snowmelt service customers are required to pay for the cost of the Snowmelt meter set
and other related facility and equipment costs, prior to the installation of the meter set. Any request to alter
the physical location of the meter set and related facilities from Company's initial design may be granted
provided, however, the Company can reasonably accommodate said relocation and Customer agrees to
pay all related costs.
RATE:
Monthly minimum charge is the Customer Charge.
For billing periods ending April through November
Customer Charge -$2.50 per bill
Per Therm Charge -$0.62144*
For billing periods ending December through March
Customer Charge -$6.50 per bill
Per Therm Charge -$0.62144*
*Includes the following:
Cost of Gas: 1) Temporary purchased gas cost adjustment
2) Weighted average cost of gas
3) Gas transportation cost
Distribution Cost:
PURCHASED GAS COST ADJUSTMENT:
($0.04388)
$0.29695
$0.20600
$0.16237
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company's Purchased
Gas Cost Adjustment Schedule.
Issued by: lntermountain Gas Company
By: Michael P. McGrath Title: Director-Regulatory Affairs
Effective: October 1, 2016
I.P.U.C. Gas Tariff
Rate Schedules
Tenth Revised Sheet No. 5 (PaQe 1 of 2)
Name
of Utility lntermountain Gas Company
Rate Schedule IS-C
Exhibit No. 2
Case No. INT-G-16-03
lntermountain Gas Company
Page 6 of 10
SMALL COMMERICAL INTERRUPTIBLE SNOWMEL T SERVICE
APPLICABILITY:
Applicable to any customer otherwise eligible to receive gas service under Rate Schedule GS-1 who has
added natural gas snowmelt equipment after 6/1/2010. The intended use of the snowmelt equipment is to
melt snow and/or ice on sidewalks, driveways or any other similar appurtenances. Any and all such
applications meeting the above criteria will be subject to service under Rate Schedule IS-C and will be
separately and individually metered. All service hereunder is interruptible at the sole discretion of the
Company.
FACILITY REIMBURSEMENT CHARGE:
All new interruptible Snowmelt service customers are required to pay for the cost of the Snowmelt meter set
and other related facility and equipment costs, prior to the installation of the meter set. Any request to alter
the physical location of the meter set and related facilities from Company's initial design may be granted
provided, however, the Company can reasonably accommodate said relocation and Customer agrees to pay
all related costs.
RATE:
Monthly minimum charge is the Customer Charge.
For billing periods ending April through November
Customer Charge -$2.00 per bill
Per Therm Charge -First 200 therms per bill @ $0.62762*
Next 1,800 therms per bill@ $0.60642*
Over 2,000 therms per bill@ $0.58596*
For billing periods ending December through March
Customer Charge -$9.50 per bill
Per Therm Charge -First 200 therms per bill @ $0.62762*
*Includes the following:
Cost of Gas:
Distribution Cost:
Next 1,800 therms per bill @ $0.60642*
Over 2,000 therms per bill@ $0.58596*
1) Temporary purchased gas cost adjustment
2) Weighted average cost of gas
3) Gas transportation cost
First
Next
Over
200 therms per bill @
1,800 therms per bill @
2,000 therms per bill @
Issued by: lntermountain Gas Company
By: Michael P. McGrath Title: Director-Regulatory Affairs
Effective: October 1, 2016
($0.05144)
$0.29695
$0.21545
$0.16666
$0.14546
$0.12500
I.P.U.C. Gas Tariff
Rate Schedules
Sixtv-First Revised Sheet No. 7 ( PaQe 1 of 2)
Name
of Utility lntermountain Gas Company
Rate Schedule LV-1
LARGE VOLUME FIRM SALES SERVICE
AVAILABILITY:
Exhibit No. 2
Case No. INT-G-16-03
lntermountain Gas Company
Page 7 of 10
Available at any mutually agreeable delivery point on the Company's distribution system to any existing
customer receiving service under the Company's rate schedule LV-1 or any customer not previously served
under this schedule whose usage does not exceed 500,000 therms annually, upon execution of a one-year
minimum written service contract for firm sales service in excess of 200,000 therms per year.
MONTHLY RATE:
Per Therm Charge:
Block One: First
Block Two: Next
Block Three: Amount Over
250,000 therms per bill @ $0.40773*
500,000 therms per bill@ $0.36924*
750,000 therms per bill@ $0.29644*
*Includes the following:
Cost of Gas: 1) Temporary purchased gas cost adjustment
Block One and Two
Block Three
2) Weighted average cost of gas
3) Gas transportation cost (Block One and Two only)
Distribution Cost: Block One
Block Two
Block Three
PURCHASED GAS COST ADJUSTMENT:
($0.02443)
($0.00712)
$0.29695
$0.07065
$0.06456
$0.02607
$0.00661
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company's Purchased
Gas Cost Adjustment Schedule.
SERVICE CONDITIONS:
1. All natural gas service hereunder is subject to the General Service Provisions of the Company's
Tariff, of which this Rate Schedule is a part.
2. The customer shall negotiate with the Company, a Maximum Daily Firm Quantity (MDFQ) amount,
which will be stated in and will be in effect throughout the term of the service contract.
In the event the Customer requires daily usage in excess of the MDFQ, and subject to the
availability of firm interstate transportation to serve lntermountain's system, all such usage may
be transported and billed under either secondary rate schedule T-3 or T-4. The secondary rate
schedule to be used shall be predetermined by negotiation between the Customer and Company,
and shall be included in the service contract. All volumes transported under the secondary rate
schedule are subject to the provisions of the applicable rate schedule T-3 or T-4.
Issued by: lntermountain Gas Company
By: Michael P. McGrath Title: Director-Regulatory Affairs
Effective: October 1, 2016
I.P.U.C. Gas Tariff
Rate Schedules
Twelfth Revised Sheet No. 8 ( PaQe 1 of 2)
Name
of Utility lntermountain Gas Company
Rate Schedule T-3
Exhibit No. 2
Case No. INT-G-16-03
lntermountain Gas Company
Page 8 of 10
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@ $0.05463*
Block Two: Next 50,000 therms transported@ $0.02203*
Block Three: Amount over 150,000 therms transported@ $0.00790*
*Includes temporary purchased gas cost adjustment of $(0.00097)
ANNUAL MINIMUM BILL:
The customer shall be subject to the payment of an annual minimum bill of $30,000 during each annual
contract period, unless a higher minimum is required under the service contract to cover special
conditions.
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company's Purchased
Gas Cost Adjustment Schedule.
SERVICE CONDITIONS:
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 immediately curtail or interrupt its
operations during periods of capacity constraints on the Company's 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 lntermountain'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: lntermountain Gas Company
By: Michael P. McGrath Title: Director -Regulatory Affairs
Effective: October 1, 2016
I.P.U.C. Gas Tariff
Rate Schedules
Eleventh Revised Sheet No. 9 ( Paqe 1 of 2)
Name
of Utility lntermountain Gas Company
Rate Schedule T-4
FIRM DISTRIBUTION ONLY TRANSPORTATION SERVICE
AVAILABILITY:
Exhibit No. 2
Case No. INT-G-16-03
lntermountain Gas Company
Page 9 of 10
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:
Block Two:
Block Three:
First
Next
Amount over
250,000 therms transported@ $0.05863*
500,000 therms transported@ $0.02014*
750,000 therms transported@ $0.00541 *
*Includes temporary purchased gas cost adjustment of $(0.00120)
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company's Purchased
Gas Cost Adjustment Schedule.
SERVICE CONDITIONS:
1. This service excludes the service and cost of firm interstate pipeline charges.
2. The customer is responsible for procuring its own supply of natural gas and interstate
transportation under this Rate Schedule. The customer understands and agrees that the Company
is not responsible to deliver gas supplies to the customer which have not been nominated,
scheduled, and delivered by the interstate pipeline to the designated city gate.
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:
1. In the event that total deliveries to any existing T-4 customer within the most recent 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 1 rate. The customer's future eligibility for the T-4 Rate Schedule will be
renegotiated with the Company.
Issued by: lntermountain Gas Company
By: Michael P. McGrath Title: Director-Regulatory Affairs
Effective: October 1, 2016
1.P.U.C. Gas Tariff
Rate Schedules
Tenth Revised Sheet No. 1 O (Paae 1 of 2)
Name
of Utilitv lntermountain Gas Company
Rate Schedule T-5
Exhibit No. 2
Case No. INT-G-16-03
lntermountain Gas Company
Page 10 of 10
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
S 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
$0.00133*
$0.04392*
*Includes temporary purchased gas cost adjustment of $(0.00113)
PURCHASED GAS COST ADJUSTMENT:
This tariff is subject to an adjustment for cost of purchased gas as provided for in the Company's Purchased
Gas Cost Adjustment Schedule.
SERVICE CONDITIONS:
1. 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.
5. All therms not billed at the commodity charge for firm therms transported rate will be billed
at the Overrun Service rate.
Issued by: lntermountain Gas Company
By: Michael P. McGrath Title: Director -Regulatory Affairs
Effective: October 1, 2016
EXHIBIT NO. 3
CASE NO. INT-G-16-03
INTERMOUNTAIN GAS COMPANY
PERTINENT EXCERPTS PERTAINING TO INTERSTATE PIPELINES AND RELATED
FACILITIES
(46 pages)
NORTHWEST PIPELINE LLC
LEAP-YEAR RATES
(11 pages)
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 1 of 46
20151210-3036 FERC PDF (Unofficial) 12/10 /2015
FEDERAL ENERGY REGULATORY COMMISSION
WASHINGTON, D.C. 20426
OFFICE OF ENERGY MARKET REGULATION
In Reply Refer To:
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 2 of 46
Letter Order Pursuant to § 375.307
Northwest Pipeline LLC
Docket No. RP16-210-000
Issued: December 10, 2015
Northwest Pipeline LLC
P.O. Box 58900
Salt Lake City, Utah 84158-0900
Attention: David J. Madsen
Director, Rates and Tariff
Reference: Revised Tariff Records to Reflect Leap Year Rates
Dear Mr. Madsen:
On November 20, 2015, Northwest Pipeline LLC (Northwest) filed revised tariff
records to change its daily reservation/demand rates to reflect leap year rates for calendar
year 2016 computed on the basis of 366 days. Northwest states that the proposed 2016
daily leap year rates are based upon the daily reservation/demand rates previously
approved by the Commission in Docket No. RP12-490-000. Northwest requests an
effective date of effective January 1, 2016. The Commission accepts Northwest's tariff
records effective January 1, 2016, as proposed.
Public notice of the filing was issued on November 24, 2015. Interventions and
protests were due as provided in section 154.210 of the Commission's regulations (18
C.F.R. § 154.210 (2015)). Pursuant to Rule 214 (18 C.F.R. § 385.214 (2015)), all timely
filed motions to intervene and any unopposed motion to intervene out-of-time filed
before the issuance date of this order are granted. Granting late intervention at this stage
of the proceeding will not disrupt the proceeding or place additional burdens on existing
parties. No protests or adverse comments were filed.
This acceptance for filing shall not be construed as a waiver of the requirements of
section 7 of the Natural Gas Act, as amended; nor shall it be construed as constituting
approval of the referenced filing or of any rate, charge, classification, or any rule,
Exhibit No. 3
20151210-3036 FERC PDF (Unoffic ial) 12 /10/2015
Case No. INT-G-16-03
lntermountain Gas Company
Page 3 of 46
Docket No. RP16-210-000
regulation, or practice affecting such rate or service contained in your tariff; nor shall
such acceptance be deemed as recognition of any claimed contractual right or obligation
associated therewith; and such acceptance is without prejudice to any findings or orders
which have been or may hereafter be made by the Commission in any proceeding now
pending or hereafter instituted by or against your company.
This order constitutes final agency action. Requests for rehearing by the
Commission may be filed within 30 days of the date this order issues, pursuant to
18 C.F.R. § 385.713 (2015).
Sincerely,
Nils Nichols, Director
Division of Pipeline Regulation
2
20151210-3036 FERC PDF (Unofficial) 12 /10/201 5
Docket No. RP16-210-000
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 4 of 46
3
Appendix
Northwest Pipeline LLC
FERC NGA Gas Tariff
Fifth Revised Volume No. l
Tariff Records Accepted Effective January 1, 2016
Sheet No. 5, Statement of Rates: TF-l, TF-2, TJ-1, TFL-1 and TJL-1, 6.0.0
Sheet No. 5-B, Statement of Rates: TF-1, TF-2, TI-1, TFL-1 and TIL-1, 8.0.0
Sheet No. 5-C, Statement of Rates: TF-1, TF-2, TI-1, TFL-1 and TIL-1, 4.0.0
Sheet No. 7, Statement of Rates: SGS-2F and SGS-21. 6.0.0
Sheet No. 8, Statement of Rates: LS-1, 6.0.0
Sheet No. 8-A, Statement of Rates: LS-2F and LS-21, 6.0.0
Sheet No. 9, Statement of Rates: LS-2F and LS-2I, 4.0.0
l
NWP -Leap Year Rates Filing -RP16-210
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. 1
STATEMENT OF RATES
Effective Rates Applicable to
Rate Schedules TF-1, TF-2, TI-1 , TFL-1 and TIL-1
(Dollars per 0th)
Rate Schedule and
Type of Rate
Rate Schedule TF-1 (4) (5)
Reservation
(Large Customer)
System-Wide
15 Year Evergreen Exp .
25 Year Evergreen Exp .
Volumetric (2)
(Large Customer)
System-Wide
15 Year Evergreen Exp .
25 Year Evergreen Exp .
(Small Customer) (6)
Scheduled Overrun (2)
Rate Schedule TF-2 (4) (5)
Reservation
Volumetric
Scheduled Daily Overrun
Annual Overrun
Rate Schedule TI-1 (2)
Volumetric (7)
Rate Schedule TFL-1 (4) (5)
Reservat i on
Volumetric (2)
Scheduled Overrun (2)
Rate Schedule TIL-1 (2)
Volumetric
Base
Tariff Rate(l), (3)
Minimum Maximum
.00000
.00000
.00000
.00813
.00813
.00813
.00813
. 00813
.00000
.008 13
.00813
.00813
.00813
.40888
.3 6164
.34140
.03000
.00813
.00813
.72155
. 44000
.40 888
.03000
.44000
. 44000
. 44000
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 5 of 46
Sixth Revised Sheet No. 5
Superseding
Fifth Revised Sheet No. 5
NWP -Leap Year Rates Filing -RP16-210
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. 1
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 6 of 46
Sixth Revised Sheet No. 7
Superseding
Fifth Revised Sheet No. 7
STATEMENT OF RATES (Continued)
Effective Rates Applicable to Rate Schedules SGS-2F and SGS-2I
(Dollars per Dth)
Rate Schedule and
Type of Rate
Rate Schedule SGS-2F (2) (3) (4) (5)
Demand Charge
Pre-Expansion Shipper
Expansion Shipper
Capacity Demand Charge
Pre-Expansion Shipper
Expansion Shipper
Volumetric Bid Rates
Withdrawal Charge
Pre-Expansion Shipper
Expansion Shipper
Storage Charge
Pre-Expansion Shipper
Expansion Shipper
Rate Schedule SGS-2I
Volumetric
Footnotes
Base
Tariff Rate (1)
Minimum
0 .00000
0 .00000
0 .00000
0 .00000
0 .00000
0 .00000
0.00000
0 .00000
0 .00000
Maximum
0 .01558
0.04045
0 .00057
0 .00347
0 .01558
0 .04045
0.00057
0.00347
0 .00224
(1) Shippers receiving service under these rate schedules are required to
furnish fuel reimbursement in-kind at the rates specified on Sheet
No. 14 .
NWP -Leap Year Rates Filing -RP16-210
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. I
STATEMENT OF RATES (Continued)
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 7 of 46
Sixth Revised Sheet No. 8-A
Superseding
Fifth Revised Sheet No. 8-A
Effective Rates Applicable to Rate Schedules LS-2F and LS-2I
(Dollars per Dth)
Rate Schedule and
Type of Rate
Rate Schedule LS -2F (3)
Demand Charge (2)
Capacity Demand Charge (2)
Volumetric Bid Rates
Vaporization Demand-Related Charge (2)
Storage Capacity Charge (2)
Liquefaction
Vaporization
Rate Schedule LS-2I
Volumetric
Liquefaction
Vaporization
Footnotes
Base
Tariff Rate (1)
Minimum
0.00000
0 .00000
0.00000
0 .00000
0 .90855
0 .03386
0.00000
0.90855
0.03386
Maximum
0.02580
0.00330
0 .02580
0.00330
0.90855
0.03386
0 .00662
0 .90855
0 .03386
(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 .
(3) Rates are also applicable to capacity release service except for short­
term capacity release transactions for a term of one year or less that
take effect on or before one year from the date on which Transporter is
notified of the release, which are not subject to the stated Maximum
Base Tariff Rate . (Section 22 of the General Terms and Conditions
describes how bids for capacity release will be evaluated .) The
Vaporization Demand-Related Charge and Storage Capacity Charge are
applicable to Replacement Shippers bidding for capacity released on a
one-part volumetric bid basis.
RP16-1106 -Filed on July 26, 2016.
July 26, 2016
Ms. Kimberly D. Bose, Secretary
Federal Energy Regulatory Commission
888 First Street, N .E.
Washington, D.C. 20426
Re: Northwest Pipeline LLC
Docket No. RP16-__
Dear Ms. Bose:
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 8 of 46
1.111.ir11-~ ,,,,,,,,ams
~
NORTHWEST PIPEUNE LLC
P.O. Box 58900
Salt Lake City, UT 84158-0900
Phone: [phone]
FAX: [phone]
Pursuant to Part 154 of the regulations of the Federal Energy Regulatory Commission
("Commission" or "FERC"), Northwest Pipeline LLC ("Northwest") tenders for filing and
acceptance the following tariff sheets as part of its FERC Gas Tariff, Fifth Revised Volume No.
1 ("Tariff'):
Third Revised Sheet No. 1
Seventh Revised Sheet No. 8
Seventeenth Revised Sheet No. 14
Third Revised Sheet No. 15
Fourth Revised Sheet No. 70
Fourth Revised Sheet No. 71
Fourth Revised Sheet No. 72
Third Revised Sheet No. 73
Fifth Revised Sheet No. 74
Third Revised Sheet No. 75
Fifth Revised Sheet No. 83
Third Revised Sheet No. 84
Fifth Revised Sheet No. 85
Fifth Revised Sheet No. 91
Sixth Revised Sheet No. 92
Fourth Revised Sheet No. 93
Fifth Revised Sheet No. 94
First Revised Sheet No. 97-F
First Revised Sheet No. 97-H
First Revised Sheet No. 97-I
Fourth Revised Sheet No. 109
Seventh Revised Sheet No. 219-A
Fourth Revised Sheet No. 222-A
Fifth Revised Sheet No. 222-B
Fourth Revised Sheet No. 231
First Revised Sheet No. 232-M
Third Revised Sheet No. 300
Third Revised Sheet No. 310
Fourth Revised Sheet No. 337
Fourth Revised Sheet No. 338
Third Revised Sheet No. 339
Statement of Nature, Reasons and Basis for the Filing
The purpose of this filing is, in accordance with Part 154.602 of the regulations of the FERC, to
propose changes to Northwest's Tariff to remove Rate Schedule LS-1, the associated Form of
Rate Schedule LS-1 Service Agreement, and all references to Rate Schedule LS-1 from the
RP16-1106 -Filed on July 26, 2016.
Tariff.
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 9 of 46
Starting in 2006, Northwest's customers began requesting conversion of Part 157 service under
Rate Schedule LS-I to Part 284 service under Rate Schedule LS-2F. Subpart F of Part 157 of the
regulations grants certificate holders automatic authorization to permit existing customers, at the
customer's request and subject to certain conditions, to convert from individually certificated
transportation or storage service to Part 284 transportation or storage service, and abandon the
Part 157 service. 1
Northwest previously offered storage services under Part 157 of the Commissions regulations
under Rate Schedule LS-I. Since conversion requests began in 2006, Northwest has filed these
rate schedule conversions in its Annual Reports, as specified in Section 18 C.F.R. l 57.2 l 7(b):
• Contract No. 100604 was converted in 2006 (filed April 30, 2007, Docket No. CP07-
228)2
• Contract Nos. 10060 I, I 00602 and I 00607 were converted in 2007 (filed April 29, 2008,
Docket No. CP08-204)3
• Contract No. 100603 was converted in 2014 (filed April 27, 2015, Docket No. CPI 5-
266)4
• Contract Nos. 100605 and 100606 were converted in 2015 (filed April 25, 2016, Docket
No. CP16-244)5
With the 2015 contract conversions, Northwest no longer has any Rate Schedule LS-I contracts,
and Northwest does not plan to execute anymore contracts under Rate Schedule LS-I. Future
services of this type will be contracted under Rate Schedule LS-2F. All aspects of the LS-I
service are made available in Rate Schedule LS-2F and no services are being taken off the market
for potential future customers. Because Rate Schedule LS-I is no longer in use and with no plans
for future use, Northwest is proposing to remove from its Tariff Rate Schedule LS-I, the
associated Form of Rate Schedule LS-I Service Agreement, and all references to Rate Schedule
LS-I.
Filings Pending Before the Commission
In compliance with 18 CFR § 154.204(£), Northwest states that it has no other tariff filings
1 18 C.F.R. Section 157.217
2 LS-I Contract No. I 00604 was converted to LS-2F Contract No. I 00604
3 LS-I Contract No. 100601 was converted to LS-2F Contract No. 100601 ;
LS-I Contract No. 100602 was converted to LS-2F Contract No. I 00602;
LS-I Contract No. I 00607 was converted to LS-2F Contract No. I 00607 4 LS-1 Contract No. 100603 was converted to LS-2F Contract No. 140427
5 LS-I Contract No. 100605 was converted to LS-2F Contract No. 140777;
LS-I Contract No. I 00606 was converted to LS-2F Contract No. 140975
RP16-11 06 -Filed on July 26, 2016.
pending before the Commission that may significantly impact this filing.
Effective Date and Waiver Request
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 10 of 46
Northwest hereby moves that the proposed Tariff sheets be made effective August 26, 2016, or at
the end of any suspension period which may be imposed by the Commission. Northwest requests
that the Commission grant any waivers it may deem necessary for the acceptance of this filing.
Procedural Matters
Pursuant to the applicable provisions in Section 154 of the Commission's regulations, Northwest
submits an eTariff .xml filing package, containing the following items:
• Proposed tariff sheets,
• Marked tariff sheets, and
• Transmittal letter.
Service and Communications
In compliance with 18 CFR § 154.?(b), Northwest certifies that copies of this filing have been
served electronically upon Northwest's customers and upon interested state regulatory
commissions.
All communications regarding this filing should be served by e-mail to:
Laren Gertsch
Director, Rates and Tariffs
[phone]
Northwest Pipeline LLC
P.O. Box 58900
Salt Lake City, Utah 84158-0900
[e-mail]
Stewart J. Merrick
Senior Attorney
[phone]
Northwest Pipeline LLC
P.O. Box 58900
Salt Lake City, Utah 84158-0900
[e-mail]
RP16-1106 -Filed on July 26, 2016.
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 11 of 46
The undersigned certifies that the contents of this filing are true and correct to the best of his
knowledge and belief; that the paper and electronic versions of the submitted tariff sheets contain
the same information; and that he possesses full power and authority to sign this filing.
Respectfully submitted,
NORTHWEST PIPELINE LLC
Laren Gertsch
Director, Rates and Tariffs
Enclosures
RP16-1106-Filed on July 26, 2016.
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. 1
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 12 of 46
Seventeenth Revised Sheet No. 14
Superseding
Sixteenth 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-A are exclusive of
fue l use requirements. Shipper shall reimburse Transporter in-kind for its
fuel use requirements in accordance with Section 14 of the General Terms and
Conditions contained herein .
The fuel use reimbursement furnished by Shippers shall be as follows
for the applicable Rate Schedules included in this Tariff:
Rate Schedules TF-1, TF-2, TI -1, and DEX-1
Rate Schedule TF-1 -Evergreen Expansion
Incremental Surcharge (1)
Rate Schedule TFL-1
Rate Schedule TIL-1
Rate Schedules SGS-2F and SGS-2I
Rate Schedules LS-2F, LS-3F and LS-2I
Liquefaction
Vaporization
Rate Schedule LD-4I
Liquefaction
1. 36%
0.50 %
0 .23 %
0.71 %
0 .34 %
0 .71 %
The fuel use factors set forth above shall be calculated and adjusted
as explained in Section 14 of the General Terms and Conditions . Fuel
reimbursement quantities to be supplied by Shippers to Transporter shall be
determined by applying the factors set forth above to the quantity of gas
nominated for receipt by Transporter from Shipper for transportation ,
Jackson Prairie injection, Plymouth liquefaction, Plymouth vaporization, or
for deferred exchange, as applicable .
Footnote
(1) In addition to the Rate Schedule TF-1 fuel use requirements factor, the
Evergreen Expansion Incremental Surcharge will apply to the quantity of gas
nominated for receipt at the Sumas , SIP! or Pacific Pool receipt points under
Evergreen Expansion service agreements .
NORTHWEST PIPELINE LLC
NORMAL-YEAR RA TES
(11 pages)
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 13 of 46
20121220-3040 FERC PDF (Unofficial) 12/20/2012
FEDERAL ENERGY REGULA TORY COMMISSION
WASHINGTON, D.C. 20426
OFFICE OF ENERGY MARKET REGULATION
Northwest Pipeline GP
P.O. Box 58900
Salt Lake City, UT 84158-0900
Attention: Ms. Pam Barnes
In Reply Refer To:
Letter Order Pursuant to § 375.307
Northwest Pipeline GP
Docket No. RP12-490-001
Issued: December 20, 2012
Manager, Certificates and Tariffs
Reference: Filing to Place Settlement Rates into Effect
Dear Ms. Barnes:
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 14 of 46
On November 27, 2012, Northwest Pipeline GP (Northwest) filed revised tariff
records1 to comply with an April 26, 2012, Commission Letter Order approving a rate
settlement filed by Northwest in Docket No. RP12-490-000 (April 2012 order).2 The
April 2012 order directed Northwest to file tariff records consistent with the pro form a
tariff records set forth in Appendix F of the settlement, to be effective January 1, 2013.
The tariff records identified in the Appendix are accepted effective January 1, 2013, in
compliance with the April 2012 order.
Public notice of the filing was issued on November 28, 2012, allowing for protests
to be filed as provided in section 154.210 of the Commission's regulations. No protests
or adverse comments were filed.
This acceptance for filing shall not be construed as a waiver of the requirements of
section 7 of the Natural Gas Act, as amended; nor shall it be construed as constituting
approval of the referenced filing or of any rate, charge, classification, or any rule,
regulation, or practice affecting such rate or service contained in your tariff; nor shall
1 See Appendix for identification of tariff records.
2 Northwest Pipeline GP, 139 FERC ,r 61,071 (2012).
201212 20-3040 FERC PDF (Unoffi ci a l) 12 /20 /20 12
Docket No. RP12-490-001
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 15 of 46
-2 -
such acceptance be deemed as recognition of any claimed contractual right or obligation
associated therewith; and such acceptance is without prejudice to any findings or orders
which have been or may hereafter be made by the Commission in any proceeding now
pending or hereafter instituted by or against your company.
This order constitutes final agency action. Requests for rehearing by the
Commission may be filed within 30 days of the date of issuance of this order, pursuant to
18 C.F.R. § 385.713 (2012).
Sincerely,
Nils Nichols, Director
Division of Pipeline Regulation
20121220-3040 FERC PDF (Uno fficial ) 12/20/2012
Docket No. RP12-490-001
Northwest Pipeline GP
Fifth Revised Volume No. 1
FERC NGA Gas Tariff
Tariff Records Accepted Effective January 1, 2013
Sheet No. 5, Statement of Rates: TF-1, TF-2, TI-1. TFL-1 and TIL-1, 4.0.0
Sheet No. 5-B, Statement of Rates: TF-1, TF-2, TI-1. TFL-1 and TIL-1, 3.0.0
Sheet No. 5-C, Statement of Rates: TF-1, TF-2, TI-I, TFL-l and TIL-1, 3.0.0
Sheet No. 5-D. Statement of Rates: TF-1, TF-2, TI-I, TFL-1 and TIL-1, 2.0.0
Sheet No. 6. Statement of Rates: DEX-1 and PAL, 3.0.0
Sheet No. 7. Statement of Rates: SGS-2F and SGS-2I. 4.0.0
Sheet No. 8, Statement of Rates: LS-1, 3.0.0
Sheet No. 8-A, Statement of Rates: LS-2F and LS-21, 3.0.0
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 16 of 46
- 3 -
Appendix
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 17 of46
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. 1
Fifth Revised Sheet No. 5
Superseding
Fourth Revised Sheet No. 5
STATEMENT OF RATES
Effective Rates Applicable to
Rate Schedules TF-1, TF-2 , TI-1, TFL-1 and TIL-1
(Doll ars per Dth)
Rate Schedule and
Type of Rate
Rate Schedule TF-1 (4 ) (5)
Res ervation
(Large Customer)
System-Wide
15 Year Evergreen Exp.
25 Year Evergreen Exp .
Volumetric (2)
(Large Customer)
System-Wide
15 Year Evergreen Exp .
25 Year Evergreen Exp.
(Small Customer) (6)
Scheduled Overrun (2)
Rate Schedule TF-2 (4) (5)
Reservation
Volumetric
Scheduled Daily Over run
Annua l Overrun
Rate Schedule TI-1 (2)
Volumetric (7)
Rate Schedule TFL-1 (4) (5)
Reservation
Vol umetric (2)
Scheduled Overrun (2)
Rate Schedule TIL-1 (2)
Volumetric
Base
Tariff Rate (1), (3)
Minimum Maximum
.00000
.00000
.00000
.00813
.00813
.00813
.00813
.00813
.00000
.00813
.00813
.00813
.00813
. 41000
.36263
.34234
.03000
. 00813
. 00813
. 72155
. 44000
. 41000
.03000
.44000
.44000
.44 000
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. 1
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 18 of 46
Fifth Revised Sheet No. 7
Superseding
Fourth Revised Sheet No. 7
STATEMENT OF RATES (Continued)
Effective Rates Applicable to Rate Schedules SGS-2F and SGS-2 I
(Dollars per 0th)
Rate Schedule and
Type of Rate
Rate Schedule SGS-2F (2) (3) (4) (5)
Demand Charge
Pre-Expansion Shipper
Expansion Shipper
Capacity Demand Charge
Pre-Expansion Shipper
Expansion Shipper
Volumetric Bid Rates
Withdrawal Charge
Pre -Expansion Shipper
Expansion Shipper
Storage Charge
Pre-Expansion Shipper
Expansion Shipper
Rate Schedule SGS-2I
Volumetric
Footnotes
Base
Tariff Rate (l)
Minimum
0 .00000
0 .00000
0 .00000
0 .00000
0 .00000
0.00000
0.00000
0 .00000
0 .00000
Maximum
0.01562
0.04056
0.00057
0 .00348
0.01562
0.04056
0 .00057
0.00348
0.00224
(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 LLC
FERC Gas Tariff
Fifth Revised Volume No. I
STATEMENT OF RATES (Continued)
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 19 of 46
Fifth Revised Sheet No. 8-A
Superseding
Fourth Revised Sheet No. 8-A
Effecti ve Rates Applicable to Rate Schedules LS-2F and LS-2I
(Dollars per Dth)
Rate Schedule and
Type of Rate
Rate Schedul e LS-2F (3)
Demand Charge (2)
Capacity Demand Charge (2)
Volumetric Bid Rates
Vaporization Demand-Related Charge (2)
Storage Capacity Charge (2)
Liquefaction
Vaporization
Rate Schedule LS-2I
Volumetric
Liquefacti on
Vaporization
Footnotes
Base
Tariff Rate (1)
Minimum
0.00000
0.00000
0 .00000
0.00000
0.90855
0 .03386
0 .00000
0.90855
0.03386
Maximum
0.02587
0 .00331
0 .02587
0 .00331
0.90855
0.03386
0 .00662
0 .90855
0 .03386
(1) Shi ppers 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 .
(3) Rates are also applicable to capacity release service except for short­
term capacity release transactions for a term of one year or less that
take effect on or before one year from the date on which Transporter is
notified of the release , which are not subject to the stated Maximum
Base Tariff Rate. (Section 22 of the General Terms and Conditions
describes how bids for capacity release will be evaluated.) The
Vaporization Demand-Re l ated Charge and Storage Capacity Charge are
applicable to Replacement Shippers bidding for capacity released on a
one-part volumetric bid basis.
RP16-1106 -Filed on July 26, 2016.
July 26, 2016
Ms. Kimberly D. Bose, Secretary
Federal Energy Regulatory Commission
888 First Street, N.E.
Washington, D.C. 20426
Re: Northwest Pipeline LLC
Docket No. RP16-
Dear Ms. Bose:
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 20 of 46
Ull."rl .. ~ ,,,,,.,,ams
~
NORTHWEST PIPEUNE LLC
P.O. Box 58900
Salt Lake City, UT 84158-0900
Phone: [phone]
FAX: [phone]
Pursuant to Part 154 of the regulations of the Federal Energy Regulatory Commission
("Commission" or "FERC''), Northwest Pipeline LLC ("Northwest") tenders for filing and
acceptance the following tariff sheets as part of its FERC Gas Tariff, Fifth Revised Volume No.
1 ("Tariff'):
Third Revised Sheet No. 1
Seventh Revised Sheet No. 8
Seventeenth Revised Sheet No. 14
Third Revised Sheet No. 15
Fourth Revised Sheet No. 70
Fourth Revised Sheet No. 71
Fourth Revised Sheet No. 72
Third Revised Sheet No. 73
Fifth Revised Sheet No. 74
Third Revised Sheet No. 75
Fifth Revised Sheet No. 83
Third Revised Sheet No. 84
Fifth Revised Sheet No. 85
Fifth Revised Sheet No. 91
Sixth Revised Sheet No. 92
Fourth Revised Sheet No. 93
Fifth Revised Sheet No. 94
First Revised Sheet No. 97-F
First Revised Sheet No. 97-H
First Revised Sheet No. 97-1
Fourth Revised Sheet No. 109
Seventh Revised Sheet No. 219-A
Fourth Revised Sheet No. 222-A
Fifth Revised Sheet No. 222-B
Fourth Revised Sheet No. 231
First Revised Sheet No. 232-M
Third Revised Sheet No. 300
Third Revised Sheet No. 310
Fourth Revised Sheet No. 337
Fourth Revised Sheet No. 338
Third Revised Sheet No. 339
Statement of Nature, Reasons and Basis for the Filing
The purpose of this filing is, in accordance with Part 154.602 of the regulations of the FERC, to
propose changes to Northwest's Tariff to remove Rate Schedule LS-1, the associated Form of
Rate Schedule LS-1 Service Agreement, and all references to Rate Schedule LS-1 from the
RP16-1 106 -Filed on July 26, 2016.
Tariff.
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 21 of 46
Starting in 2006, Northwest's customers began requesting conversion of Part 157 service under
Rate Schedule LS-1 to Part 284 service under Rate Schedule LS-2F. Subpart F of Part 157 of the
regulations grants certificate holders automatic authorization to permit existing customers, at the
customer's request and subject to certain conditions, to convert from individually certificated
transportation or storage service to Part 284 transportation or storage service, and abandon the
Part 157 service. 1
Northwest previously offered storage services under Part 157 of the Commissions regulations
under Rate Schedule LS-1 . Since conversion requests began in 2006, Northwest has filed these
rate schedule conversions in its Annual Reports, as specified in Section 18 C.F.R. 157.217(b):
• Contract No. 100604 was converted in 2006 (filed April 30, 2007, Docket No. CP07-
228)2
• Contract Nos. 100601, 100602 and 100607 were converted in 2007 (filed April 29, 2008,
Docket No. CP08-204)3
• Contract No. 100603 was converted in 2014 (filed April 27, 2015, Docket No. CP15-
266)4
• Contract Nos. 100605 and 100606 were converted in 2015 (filed April 25, 2016, Docket
No. CP16-244)5
With the 2015 contract conversions, Northwest no longer has any Rate Schedule LS-1 contracts,
and Northwest does not plan to execute anymore contracts under Rate Schedule LS-1. Future
services of this type will be contracted under Rate Schedule LS-2F. All aspects of the LS-1
service are made available in Rate Schedule LS-2F and no services are being taken off the market
for potential future customers. Because Rate Schedule LS-1 is no longer in use and with no plans
for future use, Northwest is proposing to remove from its Tariff Rate Schedule LS-1, the
associated Form of Rate Schedule LS-1 Service Agreement, and all references to Rate Schedule
LS-1.
Filings Pending Before the Commission
In compliance with 18 CFR § l 54.204(f), Northwest states that it has no other tariff filings
1 18 C.F.R. Section 157.217 2 LS-1 Contract No. 100604 was converted to LS-2F Contract No. 100604
3 LS-1 Contract No. 10060 I was converted to LS-2F Contract No. 100601;
LS-1 Contract No. 100602 was converted to LS-2F Contract No. 100602;
LS-1 Contract No. 100607 was converted to LS-2F Contract No. 100607 4 LS-1 Contract No. 100603 was converted to LS-2F Contract No. 140427
5 LS-1 Contract No. 100605 was converted to LS-2F Contract No. 140777;
LS-1 Contract No. 100606 was converted to LS-2F Contract No. 140975
-------------------------------------------
RP16-1106 -Filed on July 26, 2016.
pending before the Commission that may significantly impact this filing.
Effective Date and Waiver Request
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 22 of 46
Northwest hereby moves that the proposed Tariff sheets be made effective August 26, 2016, or at
the end of any suspension period which may be imposed by the Commission. Northwest requests
that the Commission grant any waivers it may deem necessary for the acceptance of this filing.
Procedural Matters
Pursuant to the applicable provisions in Section 154 of the Commission's regulations, Northwest
submits an eTariff .xml filing package, containing the following items:
• Proposed tariff sheets,
• Marked tariff sheets, and
• Transmittal letter.
Service and Communications
In compliance with 18 CFR § 154.?(b), Northwest certifies that copies of this filing have been
served electronically upon Northwest's customers and upon interested state regulatory
commissions.
All communications regarding this filing should be served by e-mail to:
Laren Gertsch
Director, Rates and Tariffs
[phone]
Northwest Pipeline LLC
P.O. Box 58900
Salt Lake City, Utah 84158-0900
[e-mail]
Stewart J. Merrick
Senior Attorney
[phone]
Northwest Pipeline LLC
P.O. Box 58900
Salt Lake City, Utah 84158-0900
[e-mail]
RP16-1106 - Filed on July 26, 2016.
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 23 of 46
The undersigned certifies that the contents of this filing are true and correct to the best of his
knowledge and belief; that the paper and electronic versions of the submitted tariff sheets contain
the same information; and that he possesses full power and authority to sign this filing.
Respectfully submitted,
NORTHWEST PIPELINE LLC
Laren Gertsch
Director, Rates and Tariffs
Enclosures
RP16-1106 -Filed on July 26, 2016.
Northwest Pipeline LLC
FERC Gas Tariff
Fifth Revised Volume No. 1
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 24 of 46
Seventeenth Revised Sheet No. 14
Superseding
Sixteenth Revised Sheet No. 14
STATEMENT OF FUEL USE REQUIREMENTS FACTORS
FOR REIMBURSEMENT OF FUEL USE
Applicable to Transportation Service Rendered Under
Rate Schedul es Contained in this Tariff, Fifth Revised Volume No. 1
The rates set forth on Sheet Nos. 5, 6, 7, 8 and 8-A are exclusive of
fue l use requirements. Shipper shall reimburse Transporter in-kind for its
fuel use requirements in accordance with Section 14 of the General Terms and
Conditions contained herein.
The fuel use reimbursement furnished by Shippers shall be as follows
for the applicable Rate Schedules included in this Tariff:
Rate Schedules TF-1, TF-2, TI-1, and DEX-1
Rate Schedule TF-1 -Evergreen Expansion
Incremental Surcharge (1 )
Rate Schedule TFL-1
Rate Schedule TIL-1
Rate Schedules SGS-2F and SGS -2 I
Rate Schedules LS-2F, LS-3F and LS-2I
Liquefaction
Vaporization
Rate Schedule LD-4I
Liquefaction
1. 36%
0 .50 %
0.23 %
0. 71 %
0.34 %
0 .71 %
The fuel use factors set forth above shall be calcu lated and adjusted
as explained in Section 14 of the General Terms and Conditions . Fuel
reimbursement quantities to be supplied by Shippers to Transporter shall be
determined by applying the factors set forth above to the quantity of gas
nominated for receipt by Transporter from Shipper for transportation ,
Jackson Prairie injection, Plymouth liquefaction, Plymouth vaporization, or
for deferred exchange, as applicable.
Footnote
(1) In addition to the Rate Schedule TF-1 fuel use requirements factor, the
Evergreen Expansion Incremental Surcharge will apply to the quantity of gas
nominated f or receipt at the Sumas, SIPI or Pacific Pool receipt points under
Evergreen Expansion service agreements .
NOV A GAS TRANSMISSION LTD.
(7 pages)
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 25 of 46
National Energy
Board
File OF-Tolls-Groupl-N081-2016-0l 01
19 May 2016
Mr. Bernard Pelletier
Director, Regulatory Tolls and Tariffs
Canadian Gas Pipelines
NOV A Gas Transmission Ltd.
4SO-lst Street S.W.
Calgary, AB T2P SHI
Facsimile 403-920-2347
Dear Mr. Pelletier and Mr. Matheson:
Office national
de l'energie
Mr. Alan Matheson
Senior Regulatory Project Manager Tolls
and Tariffs, Canadian Gas Pipelines
NOV A Gas Transmission Ltd.
4SO-lst Street S.W.
Calgary, AB T2P SHI
Facsimile 403-920-2347
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 26 of 46
NOVA Gas Transmission Ltd. (NGTL)
Application for Approval of Final 2016 Rates, Tolls, Charges and
2016 Abandonment Surcharges for the NGTL System (Application)
The National Energy Board (Board) has examined NGTL's application dated 29 April 2016 for
approval of final 2016 rates, tolls, charges and 2016 abandonment surcharges (Final 2016 Tolls)
for the NGTL system.
NGTL requested that Final 2016 Tolls be set for the period 1 January 2016 to 31 December 2016
at the same level as the Interim 2016 Tolls approved by the Board in Order TGI-002-201 S. NGTL
advised the Board that the applied-for Final 2016 Tolls are in accordance with the 2016 and 2017
NGTL Revenue Requirement Settlement approved in Order TG-001-2016 on 7 April 2016, and
the existing rate design methodology approved in Order TG-04-2010.
NGTL proposed to dispose of the difference between the Final and Interim Revenue Requirements
in the amount of $1.9 million in the determination of the 2017 revenue requirement rather than
adjust the level of the 2016 tolls.
The Board notes that NGTL's submission that it met with the Tolls, Tariff, Facilities and
Procedures Committee (TTFP) on 8 March 2016 and presented its proposal to establish Final
2016 Tolls and its proposed treatment of the variance. NGTL indicated that no party has
expressed opposition to the proposal to NGTL.
517 Tenth Avenue SW
Calgary, Alberta T2R OAS
517, OixiemeAvenue S.-0.
Calgary (Alberta) T2R OAS Canada
.. ./2
Telephone/Telephone : [phone]
Facsimile/Telecopieur : 403-292-5503
http://www.neb-one.gc.ca
Telephone/Telephone : [phone]
Facsimile/T elecopieur : 1-877-288-8803
- 2 -
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 27 of 46
Attached Order TG-007-2016 contains the details of the approval ofNGTL's Final 2016 Tolls .
The Board directs NGTL to serve a copy of this letter on all of its shippers, interested parties and
its TTFP members.
Yours truly,
Original signed by
Sheri Young
Secretary of the Board
Attachment
National Energy
Board • Office national
de l'energie
ORDER TG-007-2016
IN THE MATTER OF the National Energy Board Act
(Act) and the regulations made thereunder; and
IN THE MATTER OF an application made by NOVA Gas
Transmission Ltd. (NGTL) dated 29 April 2016, for approval of the
Final 2016 Rates, Tolls and Charges and the 2016 Abandonment
Surcharges pursuant to Part IV of the Act filed with the National
Energy Board (Board) under File OF-Tolls-Group l-N081-2016-0l 01.
BEFORE the Board on 19 May 2016.
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 28 of 46
WHEREAS on 29 April 2016, NGTL filed an application (Application) to set Final 2016 Rates,
Tolls and Charges on the NGTL system for the period 1 January 2016 to 31 December 2016 and
2016 Abandonment Surcharges (Final 2016 Tolls) at the same level as the Interim 2016 Tolls
approved by the Board in Order TGI-002-2015;
AND WHEREAS NGTL advised the Board that the applied-for Final 2016 Tolls are in accordance
with its 2016 and 2017 Revenue Requirement Settlement approved by Board Order TG-001-2016 on
6 April 2016;
AND WHEREAS NGTL advised the Board that the Final 2016 Tolls were determined using the
existing rate design methodology approved in Order TG-04-2010;
AND WHEREAS NGTL advised the Board that it is proposing to dispose of the difference
between the Final and Interim Revenue Requirements in the determination of the 2017 revenue
requirement rather than adjust the level of the Final 2016 Tolls;
AND WHEREAS NGTL met with the Tolls, Tariff, Facilities and Procedures Committee (TTFP)
on 8 March 2016 and presented its proposal for establishing Final 2016 Tolls and its proposed
treatment of the variance;
AND WHEREAS no party has opposed the Application;
AND WHEREAS the Board has determined that applied-for tolls are just and reasonable;
THEREFORE, IT IS ORDERED, pursuant to Part IV of the Act, that Final 2016 Tolls for the
period of 1 January 20 I 6 to 31 December 2016 be set at the same level as the interim tolls in
place over that period as approved by the Board in Order TGI-002-2015.
NATIONAL ENERGY BOARD
Original signed by
Sheri Young
Secretary of the Board
Canada
NOVA Gas Transmission Ltd.
Service
I. Rate Schedule FT-R
2. Rate Schedule FT-RN
3. Rate Schedule FT-D 1
4. Rate Schedule STFT
5. Rate Schedule FT-DW
6. Rate Schedule FT-P 1
7. Rate Schedule LRS
8. Rate Schedule LRS-3
9. Rate Schedule IT-R
10. Rate Schedule IT-D 1
11. Rate Schedule FCS
12. Rate Schedule PT
13. Rate Schedule OS
14. Rate Schedule CO2
15. Monthly Abandonment
Surcharge 2
16. Daily Abandonment
Surcharge 3
Rates, Tolls and Charges
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 29 of 46
Table of Rates, Tolls and Charges
Page 1 of 1
Refer to Attachment "I" for applicable FT-R Demand Rate per month based on a three
year term (Price Point "B") & Surcharge for each Receipt Point
Average Firm Service Receipt Price (AFSRP) $ 229.87/103m3
Refer to Attachment "I" for applicable FT-RN Demand Rate per month & Surcharge
for each Receipt Point
Refer to Attachment "2" for applicable FT-D Demand Rate per month based on a one
year term (Price Point "Z") & Surcharge for each Group 1 or Group 2 Delivery Point
Average FT-D Demand Rate for Group I Delivery Points $ 5.45/GJ
FT-D Demand Rate for Group 2 Delivery Points $ 5.08/GJ
FT-D Demand Rate for Group 3 Delivery Points $ 6.09/GJ
STFT Bid Price = Minimum of I 00% of the applicable FT-D Demand Rate based on a
one year term (Price Point "Z") for each Group I Delivery Point
FT-DW Bid Price= Minimum of 125% of the applicable FT-D Demand Rate based on
a three year term (Price Point "Y") for each Group 1 Delivery Point
Refer to Attachment "3" for applicable FT-P Demand Rate per month
Contract Term Effective LRS Rate ($/l03m3/dax)
1-5 years 11.75
20 years 7.81
LRS-3 Demand Rate per month $ 129.55/103m3
Refer to Attachment "1" for applicable IT-R Rate for each Receipt Point
Refer to Attachment "2" for applicable IT-D Rate for each Delivery Point
The FCS Charge is determined in accordance with Attachment " I" to the applicable
Schedule of Service
Schedule No. PT Rate PT Gas Rate
9009-01001-1 $ 660.00/d 50.0 l03m3/d
Schedule No. Charge
2016732105 $ 143.73 /103m3 I month
2016732103 $ 143.73 /103m3 I month
2016732101 $ 143.73 /I 03m3 I month
2016732102 $ 143.73 /103m3 I month
2016732106 $ 143.73 /I 03m3 I month
2011475772 $ 9.250.00 / month
2016732104 $ 805.00 / month
2003004522 Applicable IT-Rand IT-D Rate
2011476052 I $ 0.1665 I GJ subject to
2011476054 $ 717 000.00 Minimum Annual Char!!e
2011475056 I 2011476092 I $ 0.095 I GJ and
2016721799 $ I 000.00 / month
Tier COi Rate ($/103m3)
I 544.24
2 430.63
3 279.70
$11.94/103m3/month $0.32/GJ/month
$ 0.39/103m3/day $0.0104/GJ/day
I. Service under rate Schedules FT-D, FT-P and IT-D for delivery stations identified in Attachment 2, and stations identified on rate Schedules OS No.
2011476092, are subject to the ATCO Pipelines Franchise Fees pursuant to paragraph 15.13 of the General Terms and Conditions.
2. Monthly Abandonment Surcharge applicable to Rate Schedules FT-R, FT-D, FT-P, FT-RN, FT-DW, STFT, LRS-3, and the following Rate Schedules
OS: 2016732105, 2016732103, 2016732101, 2016732102, and 2016732106.
3. Daily Abandonment Surcharge applicable to Rate Schedules IT-R, IT-D, LRS, the following Rate Schedules OS: 2011476052, 2011476054,
201 1475056, 2011476092, 2016721799, 2003004522, and if applicable Over-Run Gas.
Effective Date: January 1, 2016 (Amended March 1, 2016)
June 29, 2016
National Energy Board
517 Tenth Avenue SW
Calgary, Alberta T2R OAS
Attention: Ms. Sheri Young, Secretary of the Board
Dear Ms. Young:
Re: NOV A Gas Transmission Ltd. (NGTL)
Gas Transportation Tariff (Tariff)
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 30 of 46
TransCanada
In business to deliver
450 -I Street S.W.
Calgary, Alberta TIP SHI
Phone: ( 403) 920-2603
Fax: [phone]
Email: bemard [e-mail]
Filed Electronically
Updated Attachment 2 to the Table of Final 2016 Rates, Tolls and Charges
(Final 2016 Rates)
NGTL attaches for filing with the Board pursuant to section 60(l)(a) of the National Energy Board
Act an updated Attachment 2 (Delivery Point Specific Rates) to the Table of Final 20 16 Rates
(Table) for the Tariff, effective July 1, 2016.
The update to Attachment 2 of the Table of Final 2016 Rates is required to reflect a meter station
expected to go into service in June 2016.
Attachment 2 to the Table is being updated to include the Mazeppa Sales APS delivery point at the
existing Mazeppa APS receipt meter station and the Whitecourt Sales delivery point at the existing
Whitecourt receipt meter station. The 2016 FT-D and IT-D rates for the station are provided in the
following table:
Station FT-D Demand Rate IT-D Rate Page No. on
Number Station Name Legal Description ($/GJ/month) ($/GJ) Attachment 2
31135 Mazeppa Sales APS SW-02-020-28 W4 5.08 0.1832 3
3663 Whitecourt Sales SW-26-059-11 WS 5.08 0.1832 5
The rates were determined in accordance with NGTL's current rate design methodology approved by
the Board in Reasons for Decision RHW-1-20 IO and Order TG-04-20 IO on August 12, 2010.
June 29, 2016
Ms. S. Young
Page 2 of2
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 31 of 46
If the Board requires additional information regarding this filing, please contact Mark Manning by
phone at [phone] or by email at [e-mail].
Yours truly,
NOV A Gas Transmission Ltd.
Original Signed By
Bernard Pelletier
Director, Regulatory Tolls and Tariffs
Canadian Gas Pipelines
Attachment
cc: TIFP
NGTL System Shippers
Exhibit No. 3
Case No. INT-G-16-03
NOVA Gas Transmission Ltd. lntermountain Gas Company
Page 32 of 46
Cltoup 1 FT-0 Domand Rote IT-0 Rot. Attachment 2
per Month O.UvoryPolnl Group 1 Dellwry Point Name Price Point "Z" per Day Delivery Point Rates
Number {SIOJI {SIOJ) Page 1 of 5
2000 ALBERTA-B.C. BORDER 5.08 0.1832
31111 ALLIANCE CLAIRMONT INTERCONNECT APN 5.08 0.1832
31110 ALLIANCE EDSON INTERCONNECT APN 5.08 0.1832
31112 ALLIANCE SHELL CREEK INTERCONNECT APGC 5.08 0.1832
3002 BOUNDARY LAKE BORDER 5.08 0.1832
1958 EMPRESS BORDER 5.94 0.2141
3886 GORDONDALEBORDER 5.08 0.1832
6404 MCNEILL BORDER 5.94 0.2141
Cltoup z FT-0 Demand Rot. IT-0 Rot. Subject to
Delivery Point Group Z O.Uvory Point Nome per Month per Doy ATCDPlpelinH
Number PrtcePointT (SIOJ) Franchise FHa 1 (SIGJ)
31000 A.T. PLASTICS SALES APN 5.08 0.1832 Yes
31001 ADM AGRI INDUSTRIES SALES APN 5.08 0.1832 Yes
3880 AECO INTERCONNECTION 5.08 0.1832
31003 AGRIUM CARSELAND SALES APS 5.08 0.1832
31002 AGRIUM FT. SASK SALES APN 5.08 0.1832 Yes
31004 AGRIUM REDWATER SALES APN 5.08 0.1832
31005 AINSWORTH SALES APGP 5.08 0.1832
31006 AIR LIQUIDE SALES APN 5.08 0.1832
3214 AKUINU RIVER WEST SALES 5.08 0.1832
31007 ALBERTA ENVIROFUELS SALES APN 5.08 0.1832 Yes2
31008 ALBERTA HOSP IT AL SALES APN 5.08 0.1832 Yes
3868 ALBERT A-MONT ANA BORDER 5.08 0.1832
3297 ALDER FLATS SOUTH NO 2 SALES 5.08 0.1832
3059 ALLISON CREEK SALES 5.08 0.1832
31009 ALTASTEELSALESAPN 5.08 0.1832 Yes2
3562 AMOCO SALES (BP SALES TAP) 5.08 0.1832
31012 APL JASPER SALES APN 5.08 0.1832 Yes
3488 ARDLEY SALES 5.08 0.1832
3237 ASPEN SALES 5.08 0.1832
3662 ATUSIS CREEK EAST SALES 5.08 0.1832
3216 AURORA NO 2 SALES 5.08 0.1832
3135 AURORA SALES 5.08 0.1832
3288 BANTRY SALES 5.08 0.1832
3423 BASHAW WEST SALES 5.08 0.1832
31013 BAYMAG SALES APS 5.08 0.1832
31014 BEAR CREEK COGEN SALES APGP 5.08 0.1832
3299 BEAR RIVER WEST SALES 5.08 0.1832
3068 BEAVER HILLS SALES 5.08 0.1832
3268 BENBOW SOUTH SALES 5.08 0.1832
3933 BIG EDDY INTERCONNECTION 5.08 0.1832
3655 BIG PRAIRIE SALES 5.08 0.1832
3067 BIGSTONE SALES 5.08 0.1832
3285 BILBO SALES 5.08 0.1832
3468 BLEAK LAKE SALES 5.08 0.1832
3295 BOOTIS HILL SALES 5.08 0.1832
3225 BOTHA SALES 5.08 0.1832
3259 BOULDER CREEK SALES 5.08 0.1832
3164 BRAINARD LAKE SALES 5.08 0.1832
3289 BRAZEAU EAST SALES 5.08 0.1832
3918 BUFFALO CREEK INTERCONNECTION 5.08 0.1832
31015 BURDETI COGEN SALES APS 5.08 0.1832
3265 BURNT TIMBER SALES 5.08 0.1832
3204 CABIN SALES 5.08 0.1832
3293 CADOGAN SALES 5.08 0.1832
3109 CALDWELL SALES 5.08 0.1832
31016 CALGARY ENERGY CENTRE SALES APS 5.08 0.1832 Yes
3262 CALUMET RIVER SALES 5.08 0.1832
3634 CANOE LAKE SALES 5.08 0.1832
3165 CANOE LAKE SALES NO 2 5.08 0.1832
3866 CARBON INTERCONNECTION 5.08 0.1832
3484 CARIBOU LAKE SALES 5.08 0.1832
3157 CARIBOU LAKE SOUTH SALES 5.08 0.1832
3106 CARMON CREEK SALES 5.08 0.1832
3248 CARMON CREEK EAST SALES 5.08 0.1832
3101 CAROLINE SALES 5.08 0.1832
31017 CARSELAND COGEN SALES APS 5.08 0.1832
3275 CARSON CREEK SALES 5.08 0.1832
3495 CAVALIER SALES 5.08 0.1832
31018 CHAIN LAKES COOP SALES APS 5.08 0.1832
3907 CHANCELLOR INTERCONNECTION 5.08 0.1832
3151 CHEECHAM WEST NO 2 SALES 5.08 0.1832
3622 CHEECHAM WEST SALES 5.08 0.1832
6014 CHEVRON AURORA SALES 5.08 0.1832
31019 CHEVRON FT. SASK SALES APN 5.08 0.1832 Yes
3097 CHICKADEE CREEK SALES 5.08 0.1832
3305 CHIGWELL NORTH SALES 5.08 0.1832
TARIFF Effective: January 1, 2016 (Amended July 1, 2016)
FOOTHILLS PIPE LINES LTD.
(3 pages)
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 33 of 46
October 30, 2015
National Energy Board
517 Tenth Avenue SW
Calgary, Alberta T2R OA8
Attention: Ms. Sheri Young, Secretary of the Board
Dear Ms. Young:
Re: Foothills Pipe Lines Ltd. (Foothills)
Statement of Rates and Charges effective January 1, 2016
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 34 of 46
TransCanada
In business to deliver
450 -I Street SW
Calgary, Alberta T2P 5H I
Tel: [phone]
Fax: [phone]
Email: robert_ [e-mail]
Filed Electronically
Foothills encloses for filing pursuant to section 60(l)(a) of the National Energy Board Act1 rates
and charges for transportation service on Foothills Zones 6, 7, 8 and 9 to be effective
January 1, 2016 (Effective 2016 Rates).
The following attachments are included with this letter:
• Attachment 1 consists of supporting Schedules A through G
• Attachments 2 and 3 are black-lined and clean copies, respectively, of the relevant section of
the Tariff showing the Effective 2016 Rates
The rates and charges are based on the methodology approved by the Board in
Decision TG-8-2004, as amended by Order TG-03-2007.
The filing is also made in accordance with the MH-001-2013 Decision2 with respect to Foothills'
Abandonment Surcharges effective January I, 2016, which are also included in the Table of
Effective 2016 Rates. The supporting information on the Abandonment Surcharges calculation is
provided in the attached Schedule G.
Foothills met with shippers and interested parties on October 14, 2015, and presented the
preliminary 2016 revenue requirement and preliminary Effective 2016 Rates. On the basis of this
consultation, Foothills is not aware of any objections to its proposal for establishing the Effective
2016 Rates.
1 R.S.C. 1985, c. N-7, as amended, and the regulations made thereunder.
2 See MH-001-2013 Decision, page 75.
October 30, 2015
Ms. S. Young
Page 2 of2
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 35 of 46
Foothills understands that any party that is opposed to the rates and charges will advise the
Board accordingly.
Foothills will notify its shippers and interested parties of this filing and post a copy of it on
TransCanada's Foothills System website at:
http://www.transcanada.com/customerexpress/934.html
Communication regarding this application should be directed to:
Mark Manning
Senior Project Manager, Tolls and Tariffs
Canadian Gas Pipelines
TransCanada PipeLines Limited
450 -1 Street SW
Calgary, Alberta T2P SHI
Telephone: ( 403) 920-6098
Facsimile: [phone]
Emai I: mark_ [e-mail]
Yours truly,
Foothills Pipe Lines Ltd.
Original signed by
Robert Tarvydas
Joel Forrest
Director Canadian Law
Natural Gas Pipelines
TransCanada PipeLines Limited
450 - 1 Street SW
Calgary, Alberta T2P SHI
Telephone: [phone]
Facsimile: ( 403) 920-2308
Emai I: joel _ [e-mail]
Vice-President, Regulatory, Canadian Gas Pipelines
Attachments
cc: Foothills Firm Shippers
Interruptible Shippers and Interested Parties
Foothills Pipe Lines Ltd.
TABLE OF EFFECTIVE RATES
1. Rate Schedule FT, Firm Transportation Service
Zone6
Zone 7
Zone 8*
Zone 9
Demand Rate
($/OJ/Km/Month)
0.0065420922
0.0036177806
0.0145216983
0.0086057582
2. Rate Schedule OT, Overrun Transportation Service
Commodity Rate
($/OJ/Km)
Zone6
Zone7
0.0002359443
0.0001304773
3. Rate Schedule IT, Interruptible Transportation Service
Commodity Rate
($/OJ/Km)
Zone 8*
Zone 9
4. Monthly Abandonment Surcharge**
All Zones
5. Daily Abandonment Surcharge***
All Zones
* For Zone 8, Shippers Haul Distance shall be 170.7 km.
0.0005237334
0.0003103716
0.1047843362 ($/OJ/Month)
0.0034355520 ($/OJ/Day)
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 36 of 46
Page 1
**Monthly Abandonment Surcharge applicable to Rate Schedule Firm Transportation Service, and Short Term Firm
Transportation Service for all zones.
***Daily Abandonment Surcharge applicable to Rate Schedule Overrun Transportation Service for zone 6 & 7,
Interruptible Transportation Service for zone 8 & 9, and Small General Service for zone 9.
TARIFF -PHASE I Effective Date: January I, 2016
GAS TRANSMISSION NORTHWEST LLC
(3 pages)
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 37 of 46
20151230-3008 FERC PDF (Unofficial) 12/30/2015
FEDERAL ENERGY REGULATORY COMMISSION
WASHINGTON, D.C. 20426
OFFICE OF ENERGY MARKET REGULATION
Gas Transmission Northwest LLC
700 Louisiana Street, Suite 700
Houston, TX 77002-2700
Attention: John A. Roscher, Director
Rates, Tariffs, and Certificates
In Reply Refer To:
Letter Order Pursuant to
§ 375.307(a)(7)(i)
Gas Transmission Northwest LLC
Docket No. RP16-235-000
December 30, 2015
Reference: Tariff Changes Necessitated by Leap Year
Ladies and Gentlemen:
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 38 of 46
On November 25, 2015, Gas Transmission Northwest LLC (GTN) filed tariff
records1 to modify the Medford Daily Negotiated Reservation Charges for service under
Rate Schedules FTS-l(E-2)(Diamond 1) and FTS-l(E-2)(Diamond 2) to reflect daily
charges computed on the basis of 366 days for leap years. GTN states that the proposed
reservation charges are calculated by multiplying the currently effective daily reservation
charges by 365, dividing the results by 366, and rounding to six decimal places. The
proposed reservation charges will remain in effect from January 1, 2016 through
December 31 , 2016, as 2016 is a leap year. Further, GTN is a) relocating the leap year
reference from footnote (I) to footnote (h) within Section 4.3 of its tariff, b) adding leap
year charges to footnote (h) to eliminate the need for similar filings in future leap years,
c) removing a now-inapplicable reference to the Medford Extension annual revenue
requirement in footnote (h), and d) removing the reference to footnote (I), which will be
reserved for future use, from the E-2 (Diamond 1) and E-2 (Diamond 2) Rate Schedules
in Section 4.1. GTN proposes that the referenced tariff records become effective on
January 1, 2016. We accept the referenced tariff records, effective January 1, 2016, as
proposed.
1 Gas Transmission Northwest LLC, FERC NGA Gas Tariff, GTN Tariffs: 4.1 -
Statement of Rates, FTS-1 and LFS-1 Rates. 15 .0.0 and 4.3 -Statement of Rates,
Footnotes to Statement of Effective Rates and Charges, 12.0.0.
20151230-3008 FERC PDF (Unofficial) 12/30/2015
Docket No. RPI 6-235-000
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 39 of 46
- 2 -
Public notice of the filing was issued on December 1, 2015. Interventions and
protests were due as provided in section 154.210 of the Commission's regulations (18
C.F.R. § 154.210 (2015)). Pursuant to Rule 214 (18 C.F.R. § 385.214 (2015)), all timely
filed motions to intervene and any unopposed motion to intervene out-of-time filed
before the issuance date of this order are granted. Granting late intervention at this stage
of the proceeding will not disrupt the proceeding or place additional burdens on existing
parties. No protests or adverse comments were filed.
This acceptance for filing shall not be construed as a waiver of the requirements of
section 7 of the Natural Gas Act, as amended; nor shall it be construed as constituting
approval of the referenced filing or of any rate, charge, classification, or any rule,
regulation, or practice affecting such rate or service contained in your tariff; nor shall
such acceptance be deemed as recognition of any claimed contractual right or obligation
associated therewith; and such acceptance is without prejudice to any findings or orders
which have been or may hereafter be made by the Commission in any proceeding now
pending or hereafter instituted by or against your company.
This order constitutes final agency action. Requests for rehearing by the
Commission may be filed within 30 days of the date this order issues, pursuant to
18 C.F.R. § 385.713 (2015).
Sincerely,
Nils Nichols, Director
Division of Pipeline Regulation
Gas Transmission Northwest LLC
FERC Gas Tariff
Fourth Revised Volume No. 1-A
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 40 of46
PART4.1
4.1 -Statement of Rates
FTS-1 and LFS-1 Rates
v.15.0.0 Superseding v.14.0.0
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) DELNERY (c) FUEL (d)
(Dth-MILE) (Dth) (Dth-MILE) (Dth-MILE)
Max. Min. Max. Min. Max. Min. Max. Min.
BASE 0.000434 0.000000 0.034393 0.000000 0.000016 0.000016 0.0050% 0.0000%
STF (e) (e) 0.000000 (e) 0.000000 0.000016 0.000016 0.0050% 0.0000%
EXTENSION CHARGES
MEDFORD
E-1 (t) 0.002759 0.000000 0.004641 0.000000 0.000026 0.000026
E-2 (h) 0.002972 0.000000 0.000000 0.000000
(Diamond 1)
E-2 (h) 0.001166 0.000000 0.000000 0.000000
(Diamond 2)
COYOTE SPRINGS
E-3 (i) 0.001282 0.000000 0.001283 0.000000 0.000000 0.000000
CARTY LATERAL
E-4 (p)
OVERRUN CHARGE U)
SURCHARGES
ACA (k)
Issued: November 24, 2015
Effective: January 1, 2016
0.166475 0.000000 0.000000 0.000000
(k) (k)
Docket No. RP16-235-000
Accepted: December 30, 2015
QUESTAR PIPELINE COMPANY
(3 pages)
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 41 of 46
20151223-3009 FERC PDF (Unofficial) 12/23/2015
FEDERAL ENERGY REGULA TORY COMMISSION
WASHING TON, D.C. 20426
OFFICE OF ENERGY MARKET REGULATION
In Reply Refer To:
Questar Pipeline Company
333 South State Street
P.O. Box 45360
Salt Lake City, UT 84145-0360
Letter Order Pursuant to
§ 375.307(a)(7)(i)
Questar Pipeline Company
Docket No. RP16-239-000
December 23, 2015
Attention: L. Bradley Burton, General Manager
Federal Regulatory Affairs and FERC Compliance Officer
Reference: Fuel Gas Reimbursement Percentage Filing
Ladies and Gentlemen:
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 42 of 46
On November 25, 2015, Questar Pipeline Company (Questar) filed a tariff record 1
to reflect a change in its Fuel Gas Reimbursement Percentage (FGRP) as provided by
section 12.15 of the General Terms & Conditions of its Tariff. The proposed tariff record
decreases Questar's FGRP from the currently effective 1.86 percent to 1.37 percent.
Questar requests that the tariff record be permitted to become effective January 1, 2016.
Questar's tariff record is accepted effective January I, 2016, as proposed.
Public notice of the filing was issued on December 1, 2015. Interventions and
protests were due as provided in section 154.2 l O of the Commission's regulations (18
C.F.R. § 154.210 (2015)). Pursuant to Rule 214 (18 C.F.R. § 385.214 (2015)), all timely
filed motions to intervene and any unopposed motions to intervene out-of-time filed
before the issuance date of this order are granted. Granting late interventions at this stage
of the proceeding will not disrupt the proceeding or place additional burdens on existing
parties. No protests or adverse comments were filed.
1 Questar Pipeline Company, FERC NGA Gas Tariff, Tariffs, Statement of Rates.
Statement of Rates, 10.0.0.
20151223-3009 FERC PDF (Unofficial) 12 /23/2 015
Docket No. RPI6-239-000 -2-
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 43 of 46
This acceptance for filing shall not be construed as constituting approval of the
referenced filing or of any rate, charge, classification, or any rule, regulation, or practice
affecting such rate or service contained in your tariff; nor shall such acceptance be
deemed as recognition of any claimed contractual right or obligation associated
therewith; and such acceptance is without prejudice to any findings or orders which have
been or any which may hereafter be made by the Commission in any proceeding now
pending or hereafter instituted by or against your company.
This order constitutes final agency action. Requests for rehearing by the
Commission may be filed within 30 days of the date of issuance of this order, pursuant to
18 C.F.R. § 385.713 (2015).
Sincerely,
Nils Nichols, Director
Division of Pipeline Regulation
Questar Pipeline Company
FERC Gas Tariff
Second Revised Volume No. 1
Rate Schedule/
Type of Charge
(a)
PEAKING STORAGE
Firm Peaking Storage Service -PKS
Monthly Reservation Charge
STATEMENT OF RATES
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 44 of 46
Statement of Rates
Section Version: 10.0.0
Base
Tariff
Rate ($)
(b)
Maximum 4/ ................................................................................................................................ 2.87375
Minimum ..................................................................................................................................... 0.00000
Usage Charge
Injection ..................................................................................................................................... 0.03872
Withdrawal .................................................................................................................................. 0.03872
CLAY BASIN STORAGE
Firm Storage Service -FSS
Monthly Reservation Charge
Deliverability
Maximum 4/ .............................................................................................................................. 2.85338
Minimum ................................................................................................................................... 0.00000
Capacity
Maximum .................................................................................................................................. 0.02378
Minimum ................................................................................................................................... 0.00000
Usage Charge
Injection!/ .................................................................................................................................. 0.01049
Withdrawal .................................................................................................................................. 0.01781
Authorized Overrun Charge ........................................................................................................................ .
Maximuml/ ................................................................................................................................. 0.30315
Minimuml/ .................................................................................................................................. 0.01781
Interruptible Storage Service -ISS
Usage Charge
Inventory 5/
Maximum .................................................................................................................................. 0.05927
Minimum ................................................................................................................................... 0.00000
Injection!/ .................................................................................................................................. 0.01049
Withdrawal .................................................................................................................................. 0.01781
OPTIONAL VOLUMETRIC RELEASES /
Peaking Storage Service -PKS
Maximum 4/ .................................................................................................................................. 3.40890
Minimum ....................................................................................................................................... 0.00000
Firm Storage Service -FSS
Maximum 4/ .................................................................................................................................. 0.57068
Minimum ....................................................................................................................................... 0.00000
Storage Usage Charges Applicable to Volumetric Releases 6/
Peaking Storage Service -PKS: ..................................................................................................................... .
Injection ....................................................................................................................................... 0.03872
Withdrawal .................................................................................................................................... 0.03872
Clay Basin Storage Service -FSS :
Injection!/ .................................................................................................................................... 0.01049
Withdrawal .................................................................................................................................... 0.01781
PARK AND LOAN SERVICE -PALl
Daily Charge
Maximum ..................................................................................................................................... 0.30315
Minimum ...................................................................................................................................... 0.00000
Delivery Chargel/ ............................................................................................................................ 0.02830
FUEL REIMBURSEMENT -2.0% (0.2% utility and 1.8% compressor fuel) for Rate Schedule PALl
Filed On: November 25, 2015 Effective On: January 1, 2016
FEDERAL ENERGY REGULATORY COMMISSION
ANNUAL CHARGES UNIT CHARGE
(1 pages)
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 45 of 46
FEDERAL ENERGY REGULATORY COMMISSION
WASHINGTON, D.C. 20426
FY 2016 GAS ANNUAL CHARGES
CORRECTION FOR ANNUAL CHARGES UNIT CHARGE
June 24, 2016
Exhibit No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 46 of 46
The annual charges unit charge (ACA) to be applied to in fiscal year 2017 for recovery of
FY 2016 Current year and 2015 True-Up is $0.0013 per Dekatherm (Dth). The new ACA
surcharge will become effective October 1, 2016.
The following calculations were used to determine the FY 2016 unit charge:
2016 CURRENT:
Estimated Program Cost $60,356,000 divided by 46,470,081,828 0th
2015 TRUE-UP:
Debit/Credit Cost ($892,042) divided by 44,588,799,565 0th
TOTAL UNIT CHARGE
0.0012988142
(0. 0000200060)
0.0012788082
If you have any questions, please contact Norman Richardson at [phone] or e-mail
at [e-mail].
PUBLIC
EXHIBIT NOS. 4-11
CASE NO. INT-G-16-03
INTERMOUNTAIN GAS COMPANY
(8 pages)
INTERMOUNTAJN GAS COMPANY
Summary of Gas Cost Changes
Annual Therms/ 10/1/2015 Total Annual AnnuaJ Therms/ 10/1/2016 Total Annual Cost of Service Allocation of Gas Cost Adjustment"'
Line
No. Description
(a)
DEMAND CHARGES:
Transportation:
NWP TF-1 ReSEJ\latioo (Full Rate) m
NWP TF-1 Resavatioo (Discounted) tJJ
Upstream Capacity (Full Rate) <4>
Upstream Capacity (Discounted) <5>
Storage:
SGS-2F
Demand
10 Capacity Demand
11 TF-2 Reser,ation
12 TF-2 Red~ivsy Charge
13 LS-2F
14 Demand
15 Capacity
16 Liquefaction
17 Vaporization
18 TF-2 Reservation
19 TF-2 Redelivery Charge
20 Other Storage Facilities
21 COMMODITY CHARGES:
22 Total Producertsupp~er Pll"Chases lncludflg Storage
23 TOTAL ANNUAL COST DIFFERENCE
24 Noonalized Sales Volumes (111115 -12/31115)
25 Av.,.age Base Rate Change (Line 23 divided by Line 24)
26 Other Pennanent Chang• Proposed:
Billing Oetenninants
ltfT-G-15-02
(b)
901.768,740
187,413,960
676,070,280
590,358,000
303,370 "'
10,920,990 "1
10,920,990 "1
I 0,920,990 "'
1,551,750 "'
14,751,350 "1
14.751,350 "1
14.751,350 "1
14,751,350 "1
14,751,350 {bJ
314,515,799
27 Biminatiooof TempaaryOedits(Slmlarges) fromCaseNo. lNT-G-15-02
28 Adjustment to Ftxed Cost Collection Rate <Kl)
29 Total Pennanent Changes Proposed (Lines 25 through 28)
30 T emponry Surtharge (Credit) Proposed 1"1
Prices
ltfT-G-15-02
(c)
$ 0.04170
0.02305
O.QI089
0.01629
0.00156
0.00006
0.04111
0.00300
0.00259
0.00033
0.09086
0.00339
0.04111
0.00300
0.32764
31 Proposed Average Per Thenn Change In lntennountaln Gas Company Tariff (Lines 29 through 30)
1'1 See WOl!<paper No. 4, Li1e 5, Coumns (b)-(e)
ro See WOl!<pap..-No. I, Page 1
fJJ See Wakpaper No. 1, Page 2
t•> See Wori<pap..-No. 2, Page I
f.ll See Wakpaper No. 2, Page 2
(ti) Represents Non-Additive Demand Charge Determinants
Cost Billing Debmnlnants Prices
ltfT-G-15-02 ltfT-G-16--03 ltfT-G-16-03
(d) (e) 1n
$ 37,607,152 894,757,350 $ 0.04177
4.319,523 191,431,900 0.02358
7,362,973 673,955,380 0.01067
9,614,818 589,022.400 0.01644
173,436 f7J 303,370 (S) 0.00156
227,831 f7J 10,920,990 ,. 0.00006
448.979 10,920,990 "' 0.04097
32,763 10.920,990 "' 0.00300
1,469,262 f7J 1,551.750 "1 0.00259
1,787.066 f7J 14,751,350 (5) 0.00033
1,340,234 14,751,350 ,. 0.09086
49,948 14,751,350 ,. 0.00339
606,395 14,751,350 ,. 0.04097
44,254 14,751,350 (b) 0.00300
103,047,956 314,515,799 0.29695
1'1 Price Rellecls Daily Charge; Annual Ch.-ge (Coumn (d)) equals Price (Coumn (c)) times Annual Thenns/Billing Determ~anls (Column (b)) times 366. Actual prices include 6 decimals
Cost Annual
ltfT-G-16--03 DlffMence RS-1 RS-2 GS-1
(g) (h) ~) 0) (k)
$ 37.372,602 $ (234,550) $ (26,647) $ (129,024) $ (77,364)
4,513,063 193,540 21,988 106,465 63,837
7,188,914 (174,059) (19,775) (95,748) (57,412)
9,686,336 71,518 8,125 39,342 23,589
172,850 (S) (586) (67) (322) (193)
227,209 (!) (622) (71) (342) (205)
447,443 (l2) (1.536) (175) (844) (507)
32,763
1,464,252 {S) (5,010) (569) (2,757) (1,652)
1,780,828 (S) (6,238) (709) (3,431) (2,058)
1,340,234
49,948
604,318 (l2} (2,077) (236) (1,143) (685)
44,254
"'
93,395,467 (9,652,489) (974,667) (5,360,678) (3,141,935)
(9,812,1091 $ (992,803) $ (5,448,482) $ (3,194,585)
31.758,444 174,671,830 102,376,520
(0.03126) $ (0.03119) $ (0.03120)
0.00085 0.00968 0.01323
0.01519 0.00861 0.01870
(0.01522) (0.01290) 0.00073
(0.04254) (0.04388) (0.05144)
(0.05776) $ (0.05678) $ (0.05071)
(8J Price Reflects Dail)' Cha-ge; Annual Cha-ge (Column (g)) equals Price {Column (f)) times Annual Therms/Billing Determinants (Column & {e)) times 365. Includes Northwest Pipeline cha-ges for three months at leap year rates and for nine months at non-leap year rates. Actual prices indude 6 decimals.
•> See Wori<pap..-No. 3, line 29, Coumn (e)
<10! See Exhibit No. 5, Line 25, Cdumns (eHh)
!11l See Exhibit No. 6, Line 5, Cciumns (b)-(e)
(I<'! lndudes Northwest Pipeline charges for three moolhs at leap year rates and for nine mooths at non-leap year rates.
LV-1
--(I)
$ (1,515)
1,250
(1,124)
462
(4)
(4)
(10)
(32)
(40)
(13)
(175,209)
$ (176,239)
5,709,005
$ (0.03087)
0.02707
(0.05916)
(0.06296)
(0.02443)
$ (0.08739)
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Line
No. --
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
INTERMOUNTAIN GAS COMPANY
Summary of Gas Transportation Cost
Annual Therms/ 10/1/2015 Annual
Billing Determinants Prices Cost
Description INT·G-15-02 INT·G-15-02 INT -G-15-02
(a) (b) (c) (d)
DEMAND CHARGES:
Transportation:
NWP TF-1 Reservation (Full Rate) 901,768,740 $ 0.04170 $ 37,607,152
NWP TF-1 Reservation (Discounted) 187,413,960 0.02305 4,319,523
Upstream Capacity (Full Rate) 676,070,280 0.01089 7,362,973
Upstream Capacity (Discounted) 590,358,000 0.01629 9,614,818
Storage:
SGS-2F
Demand 303,370 0.00156 173,436 i2l
Capacity Demand 10,920,990 0.00006 227,831 i2l
TF-2 Reservation 10,920,990 0.04111 448,979
TF-2 Redelivery Charge 10,920,990 0.00300 32,763
LS-2F
Demand 1,551,750 0.00259 1,469,262 i2l
Capacity 14,751,350 0.00033 1,787,066 i2l
Liquefaction 14,751,350 0.09086 1,340,234
Vaporization 14,751 ,350 0.00339 49,948
TF-2 Reservation 14,751,350 0.04111 606,395
TF-2 Redelivery Charge 14,751 ,350 0.00300 44,254
Other Storage Facilities 3,080,420
Total Fixed Gas Cost Charges $ 68,165,054
Normalized Sales Volumes (INT-G-16-03 Estimated Volumes)
Fixed Cost Collection per Therm (Line 21 divided by Line 22)
I NT -G-15-02 Fixed Cost Collection per Therm
Adjustment to Fixed Cost Collection (Line 23 minus Line 24)
GAS TRANSPORTATION COST CALCULATION:
Adjusted Fixed Cost Collection Per Therm (Line 23)
Incremental Fixed Cost Collection (3)
INT·G-16-03 Gas Transportation Cost (Lines 27 through 28)
1,1 See Workpaper No. 4, Line 5, Columns (b)-(e)
~1 Price Reflects Daily Charge; Annual Charge (Column (d)) equals Price (Column (c)) times Annual Therms (Column (b)) times 366
131 See Exhibit No. 4, (Sum of Lines 1-20 divided by Line 24)
Cost of Service Allocation of Gas Cost Adjustment 111
RS-1 RS-2 GS-1 LV-1
(e) (f) (g) (h)
$ 4,272,586 $ 20,687,318 $ 12,404,343 $ 242,905
490,745 2,376,127 1,424,751 27,900
836,515 4,050,298 2,428,603 47,557
1,092,349 5,289,015 3,171,352 62,102
19,704 95,406 57,206 1,120
25,884 125,327 75,148 1,472
51,009 246,979 148,091 2,900
3,722 18,022 10,807 212
166,924 808,227 484,621 9,490
203,030 983,047 589,446 11,543
152,265 737,249 442,063 8,657
5,675 27,475 16,475 323
68,893 333,572 200,013 3,917
5,028 24,343 14,597 286
349,970 1,694,508 1,016,046 19,896 - -
$ 7,744,299 $ 37,496,913 $ 22,483,562 $ 440,280 =
31,701,705 181,580,987 104,110,285 6,216,145 ---
$ 0.24429 $ 0.20650 $ 0.21596 $ 0.07083
0.22910 0.19789 0.19726 0.12999 ---
$ 0.01519 $ 0.00861 $ 0.01870 $ (0.05916)
$ 0.24429 $ 0.20650 $ 0.21596 $ 0.07083
(0.00057) (0.00050) (0.00051) (0.00018)
1 0.24372 $ 0.20600 $ 0.21545 $ 0.07065
;;? a ~ ~
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No.
2
3
4
5
INTERMOUNT AIN GAS COMPANY
Summary of Proposed Temporary Surcharges (Credits)
Cost of Service Allocation of Deferred Gas Costs
Description
(a)
Management of Pipeline Transportation Capacity '1l
Proposed Temporary Surcharge (Credit) -Fixed Deferral '2l
Proposed Temporary Surcharge (Credit) -Variable Deferral
LNG Sales Credits t5l
Total Proposed Temporary Surcharges (Credits)
t1l See Exhibit No. 7, Line 5, Columns (c) -(D
t2l See Exhibit No. 8, Line 9, Columns (c) -(D
Pl See Exhibit No. 9; Line 4, Column (b) plus Line 12, Column (b)
t4l See Exhibit No. 9; Line 4, Column (b) plus Line 20, Column (b)
l5l See Exhibit No. 10, Line 7, Columns (c) -(D
RS-1
(b)
$ (0.01409)
(0.01817)
(0.00965) (J)
(0.00063)
$ (0.04254)
RS-2 GS-1
(c) (d)
$ (0.01241) $ (0.01269) $
(0.02126) (0.02853)
(0.00965) (3) (0.00965) (3)
(0.00056) (0.00057)
$ (0.04388) $ (0.05144) $
LV-1
(e)
(0.00446)
(0.01285)
(0.00692) (4)
(0.00020)
(0.02443)
""05"0m
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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 Total RS-1 RS-2 GS-1
(a) (b) (c) (d) (e)
Long Term Northwest Pipeline Capacity Releases $ (3,600,000) $ (409,000) $ (1,980,324) $ (1 ,187,424) $
2 Upstream Pipeline Capacity Releases (340,000) (38,628) (187,030) (112,146)
3 Total Management of Pipeline Transportation Capacity $ (3,940,000) $ (447,628) $ (2,167,354) $ (1,299,570) $
4 Normalized Sales Volumes (1/1/15-12/31/15) 31,758,444 174,671,830 102,376,520 -
5 Proposed Price Adjustment Per Therm $ (0.01409) $ (0.01241) $ (0.01269) $
'1l See Workpaper No. 4, Line 5, Columns (b)-(e)
LV-1
(f)
(23,252)
(2,196)
(25,448)
5,709,005
(0.00446)
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INTERMOUNTAIN GAS COMPANY
Proposed Temporary Surcharges (Credits)· Fixed Costs
Deferred
Account1910
Estimated
Line Sept. 30, 2016
No. Description Balance 111 RS-1
(a) (b) (c)
1 From INT -G-15-02 (Accounts 1910.2050 -2090) $ 97,635 $ 34,079 $
2 Fixed Cost Collection Adjustment (Account 1910.2200) (1,217,719) 111,905
3 Capacity Releases (Account 1910.2320) '21 (6,071,397) (689,777)
4 Interest (Account 1910.2430) '21 (1,567) (178)
5 Management of Pipeline Transportation Capacity (Account 1910.2530) (3,940,000) (460,172)
6 Amortization of 1910.2530 (Accounts 1910.2540 -1910.2550) 3,849,282 426,975
7 Total Fixed Costs $ (7,283,766) $ (577,168) $
8 Normalized Sales Volumes (1/1/15 -12/31/15) 31,758,444
9 Proposed Temporary Surcharge (Credit)-Fixed Costs $ (0.01817) $
'11 See Workpaper No. 5, Pages 3 and 4
'21 See Workpaper No. 4, Line 5 Columns (b)-(e)
RS-2 GS-1
(d) (e)
21,199 $ 44,796
(340,440) (957,124)
(3,339,815) (2,002,590)
(862) (517)
(2,156,256) (1,278,664)
2,103,347 1,273,678
(3,712,827) $ (2,920,421)
174,671,830 102,376,520
(0.02126) $ (0.02853)
LV-1
(f)
$ (2,439)
(32,060)
(39,215)
(10)
(44,908)
45,282
$ (73,350)
5,709,005
$ (0.01285)
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Line
No.
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
INTERMOUNTAIN GAS COMPANY
Proposed Temporary Surcharges (Credits). Variable Costs
Description
(a)
Account 1910 Variable Amounts Which Apply to RS-1, RS-2, GS-1, and LV-1:
Account 1910 Variable Costs
Normalized Sales Volumes (1/1/15-12/31/15)
Proposed Temporary Surcharge (Credit)· Variable Costs
Lost and Unaccounted For Gas Amounts Which Apply to RS-1, RS-2, and GS-1:
Lost and Unaccounted For Gas Amounts from INT-G-15-02 (Account 1910-2120)
Lost and Unaccounted For Gas Amortization (Account 1910-2130)
(Over)/Under Collection of Lost and Unaccounted For Gas from INT-G-15-02
Lost and Unaccounted For Gas INT-G-16-03
Total Lost and Unaccounted For Gas Amounts Which Apply to RS-1, RS-2, and GS-1
Normalized Sales Volumes (1/1/15 -12/31/15)
Proposed Temporary Surcharge (Credit)· Lost and Unaccounted For Gas Costs
Lost and Unaccounted For Gas Amounts Which Apply to LV-1, T-3, T-4, and T-5:
Lost and Unaccounted For Gas Amounts from INT-G-15-02 (Account 1910-2120)
Lost and Unaccounted For Gas Amortization (Account 1910-2140)
(Over)/Under Collection of Lost and Unaccounted For Gas from INT-G-15-02
Lost and Unaccounted For Gas INT-G-16-03
Total Lost and Unaccounted For Gas Amounts Which Apply to LV-1, T-3, T-4 and T-5
Normalized Sales Volumes (1/1/15 -12/31/15)
Proposed Temporary Surcharge (Credit)· Lost and Unaccounted For Gas Costs
(ll See Workpaper No. 5, Page 1, Line 17, Column (n
'2l See Workpaper No. 5, Page 2, Line 2, Column (c)
(3l See Workpaper No. 5, Page 2, Line 8, Column (d)
(4l See Workpaper No. 5, Page 2; Line 23, Column (d) plus Line 29, Column (e)
(5l See Workpaper No. 5, Page 2, Line 3, Column (c)
(5l See Workpaper No. 5, Page 2, Line 12, Column (d)
(7) See Workpaper No. 5 Page 2; Line 24, Column (d) plus Line 33, Column (e)
Exhibit No. 9
Case No. INT-G-16-03
lntermountain Gas Company
Page 1 of 1
Amount
(b)
$ (1,871,097) (l)
314,515,799
$ (0.00595)
$ (730,031) (2)
710,745 (3)
(19,286)
(1 ,124,746) (4)
$ (1 ,144,032)
308,806,794
$ (0.00370)
$ (259,753) (5)
319,712 (5)
59,959
(374,889) (?)
$ (314,930)
325,388,772
$ (0.00097)
Line
No. Description
(a)
1 From INT-G-15-02 (Accounts 1910.2800 -2810)
2 Interest (Account 1910.2815)
3 LNG Sales Deferral -Margin Sharing (Account 1910.2820)
4 LNG Sales Deferral -O&M Recovery (Account 1910.2825)
5 Total LNG Sales Credits
6 Normalized Sales Volumes (1/1/15 -12/31/15)
7 Proposed Price Adjustment Per Therm
111 See Wor1<paper No. 5, Page 5, Lines 1 -12, Column (d)
121 See Wor1<paper No. 8, Line 5, Columns (b)-(g)
INTERMOUNTAIN GAS COMPANY
Allocation of LNG Sales Credits
Deferred
Account 1910
Estimated
Sept. 30, 2016
Balance(1> RS-1
(b) (c)
$ 96,990 $ 8,240 $
10 1
(271 ,969) (23,106)
(61,836) (5,253)
$ (236,805) $ (20,118) $
31,758,444 -
$ (0.00063) $
Cost of Service Allocation of Deferred Gas Costs (2>
RS-2 GS-1 LV-1 T-4
(d) (e) (f) (g)
39,897 $ 23,923 $ 468 $ 22,938
5 2 2
(111,874) (67,082) (1,314) (64,320)
(25,436) (15,252) (299) (14,624)
(97,408) $ (58,409) $ (1,145) $ (56,004)
174,671,830 102,376,520 5,709,005 248,823,322
(0.00056) $ (0.00057) $ (0.00020) $ (0.00023)
T-5
(h)
$ 1,524
(4,273)
(972)
$ (3,721)
23,457,195
$ (0.00016)
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INTERMOUNTAIN GAS COMPANY
Analysis of Annualized Price Change by Class of Service
Normalized Volumes for Twelve Months Ended December 31, 2015
Average Prices Effective Proposed
per Case No. INT-G-15-02 Adjustments Effective
Commission Order No. 33386 10/1/2016
Line Annual
No. Descrietion Therms/CD Vols. Revenue $fTherm Revenue $(Therm
(a) (b) (c) (d) (e) (f)
Gas Sales:
2 RS-1 Residential 31,758,444 $ 28,209,438 $ 0.88825 $ (1,834,368) $ (0.05776)
3 RS-2 Residential 174,671,830 131,347,976 0.75197 (9,917,867) (0.05678)
4 GS-1 General Service 102,376,520 70,718,629 0.69077 (5,191,513) (0.05071)
5 LV-1 Large Volume 5 709 005 2,826,643 0.49512 (498,910) (0.08739)
6 Total Gas Sales 314,515,799 233,102,686 0.74115 (17,442,658) (0.05546)
7 T-3 Transportation 47,399,250 848,447 0.01790 (948) (0.00002)
8 T-4 Transportation 248,823,322 7,651,317 0.03075 213,988 0.00086
10 T-5 Transportation 23,457,195 775 964 0.03308 5,161 0.00022
11 Total Transportation 319 679 767 9,275,728 0.02902 218 201 0.00068
12 Total flJ!t m ~flfl $ 2~2mm $ oaam $ (lZ22H~Zl $ (Q Q2Zlfll
Proposed Average Prices
Effective 10/1/2016
Revenue $(Therm
(g) (h)
$ 26,375,070 $ 0.83049
121,430,109 0.69519
65,527,116 0.64006
2,327,733 0.40773
215,660,028 0.68569
847,499 0.01788
7,865,305 0.03161
781125 0.03330
9,493,929 0.02970
$ 22~ l~J ~~z $ o a~~o2
Percent
~e
(i)
-6.50%
-7.55%
-7.34%
-17.65%
-7.48%
-0.11%
2.80%
0.67%
2.34%
-7.11%
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NEWS RELEASE
and
CUSTOMER NOTICE
CASE NO. INT-G-16-03
INTERMOUNTAIN GAS COMPANY
(4 Pages)
~
A INTERMOUNTAIN® f} GAS COMPANY
A SUbsidi9fY of MDU R8SOUfces Group, Inc.
555 S. Cole Rd.
Boise, ID 83709
[phone]
Intermountain Gas Company files for an overall decrease to its prices
BOISE, IDAHO-August 12, 2016-Intermountain Gas Company made two filings with the Idaho Public
Utilities Commission that, if approved, will affect the rate customers pay for natural gas. The company filed its
annual Purchase Gas Adjustment (PGA) and an additional application requesting an increase to its general base
rates. If both applications are approved, the net effect to its customers is an overall average decrease of 3.05
percent or $7 million less annually as compared to the company's current rates.
"Intermountain Gas prides itself on keeping expenses low and finding the best options possible in acquiring
natural gas to ensure our customers have safe and reliable service at the lowest price possible," said Scott
Madison, executive vice president of Intermountain Gas. "We are happy to provide a significant discount in our
natural gas prices as outlined in our PGA. We also believe our general rate request is reasonable in order to
continue to provide a safe and reliable distribution system for our growing customer base. We have been able to
hold our underlying rates stable for more than 30 years but our investment in and replacement of infrastructure,
combined with costs associated with mandated federal regulations, is driving the need for our requested general
rate increase."
The PGA request is an overall decrease in prices of7. l l percent or $17.2 million in annual revenues. The
primary reason for the proposed decrease is a decline in the price of natural gas that Intermountain purchases for
its customers. The cost of natural gas makes up the largest segment of a customer's bill and is a straight pass­
through cost to customers. lntermountain Gas does not make a return on the cost of gas.
If the PGA is approved residential customers using natural gas for space heating and water heating will save an
average of $3.48 or 7.55 percent per month, while customers using natural gas only for space heating will see an
average decrease of $2.31 or 6.5 percent per month, based on average weather and usage. Commercial
customers, on average, would see a decrease of$14.23 per month or 7.34 percent.
Intermountain's request for a general rate increase is seeking $10.2 million annually over current rates, or 4.06
percent. This is the first general rate case filing by Intermountain Gas since 1985. Over the past 31 years,
Intermountain has worked diligently to keep customers' rates at the lowest levels in the region while continuing
to provide quality service.
If approved, customers using natural gas for space and water heating will experience an average increase of
$2.31 per month, or 4.93 percent; customers using natural gas for space heating only will realize an increase of
$1.16 per month, or 3.26 percent. Commercial customers, on average, would see an increase of$12.16 per
month or 6.29 percent.
"Since the acquisition by MDU Resources Group, lntermountain has found synergistic savings in a number of
areas," said Nicole Kivisto, president and CEO of Intermountain Gas, as well as its three sister utility
companies, all of which are under the MDU Resources Group umbrella. "We have found savings in joint senior
management, a combined customer service center located in Meridian, as well as joint billing and payment
processing, also located in Idaho.
"Even with these savings, however, Intermountain 's customer growth and related expenses over the last 31
years necessitates the requested general rate increase."
If both of the company's applications are approved, residential customers using natural gas for space heating
and water heating will save an average of $1.17 or 2.62 percent per month, while customers using natural gas
only for space heating will save an average of $1.15 or 3.24 percent per month, based on average weather and
usage. Commercial customers, on average, would see a decrease of $2.07 per month or 1.05 percent.
Intermountain continues to urge all its customers to use energy wisely. As part of the general rate case
application, the company is proposing to implement several "Demand Side Management" (DSM) programs to
better enable its customers to conserve energy. Conservation tips and information on government payment
energy assistance are provided through bill inserts and on the company's website www.intgas.com. The website
also outlines a number of programs and tips to help our customers' level out their energy bills over the year, and
stabilize the potential impact that cold weather will have during periods of higher natural gas usage.
A Purchased Gas Cost Adjustment application is filed each year to reflect the gas costs Intermountain incurs on
behalf of its customers in its sales prices. A general rate change application is filed as needed to recover changes
in the cost of delivering natural gas to the customer's home or business. Both requests are subject to public
review and approval by the Idaho Public Utilities Commission. A copy of the applications are available for
review at the commission, the company's website at W\vw.intgas.com as well as the commission's homepage at
www.puc.idaho.gov. Customers may also subscribe to the commission's RSS feed to receive periodic updates
via email.
lntermountain Gas Company is a natural gas distribution company serving approximately 339,000 residential,
commercial and industrial customers in 75 communities in southern Idaho. lntermountain is a subsidiary of
MDU Resources Group, Inc., a diversified natural resources enterprise traded on the New York Stock Exchange
as "MDU" For more iriformation about MDU Resources, visit the company's website at www.mdu.com. For
more information about lntermountain, visit www.intgas.com
***********
Media Contact: Cheryl Imlach at [phone]
Customer Notice
lntermountain Gas Company files for an overall decrease to its prices
On August 12, 2016, -lntermountain Gas Company made two filings with the Idaho Public Utilities Commission
that, if approved, will affect the rate customers pay for natural gas. The company filed its annual Purchase Gas
Adjustment (PGA) and an additional application requesting an increase to its general base rates. If both
applications are approved, the net effect to its customers is an overall average decrease of 3.05 percent or $7
million less annually as compared to the company's current rates.
"lntermountain Gas prides itself on keeping expenses low and finding the best options possible in acquiring
natural gas to ensure our customers have safe and reliable service at the lowest price possible," said Scott
Madison, executive vice president of lntermountain Gas. "We are happy to provide a significant discount in our
natural gas prices as outlined in our PGA. We also believe our general rate request is reasonable in order to
continue to provide a safe and reliable distribution system for our growing customer base. We have been able to
hold our underlying rates stable for more than 30 years but our investment in and replacement of infrastructure,
combined with costs associated with mandated federal regulations, is driving the need for our requested general
rate increase."
The PGA request is an overall decrease in prices of 7.11 percent or $17.2 million in annual revenues. The primary
reason for the proposed decrease is a decline in the price of natural gas that lntermountain purchases for its
customers. The cost of natural gas makes up the largest segment of a customer's bill and is a straight pass­
through cost to customers. lntermountain Gas does not make a return on the cost of gas.
If the PGA is approved residential customers using natural gas for space heating and water heating will save an
average of $3.48 or 7.55 percent per month, while customers using natural gas only for space heating will see an
average decrease of $2.31 or 6.5 percent per month, based on average weather and usage. Commercial
customers, on average, would see a decrease of $14.23 per month or 7.34 percent.
lntermountain's request for a general rate increase is seeking $10.2 million annually over current rates, or 4.06
percent. This is the first general rate case filing by lntermountain Gas since 1985. Over the past 31 years,
lntermountain has worked diligently to keep customers' rates at the lowest levels in the region while continuing to
provide quality service.
If approved, customers using natural gas for space and water heating will experience an average increase of
$2.31 per month, or 4.93 percent; customers using natural gas for space heating only will realize an increase of
$1 .16 per month, or 3.26 percent. Commercial customers, on average, would see an increase of $12.16 per
month or 6.29 percent.
"Since the acquisition by MDU Resources Group, lntermountain has found synergistic savings in a number of
areas," said Nicole Kivisto, president and CEO of lntermountain Gas, as well as its three sister utility companies,
all of which are under the MDU Resources Group umbrella. "We have found savings in joint senior management,
a combined customer service center located in Meridian, as well as joint billing and payment processing, also
located in Idaho.
"Even with these savings, however, lntermountain's customer growth and related expenses over the last 31 years
necessitates the requested general rate increase."
If both of the company's applications are approved, residential customers using natural gas for space heating and
water heating will save an average of $1 .17 or 2.62 percent per month, while customers using natural gas only for
space heating will save an average of $1 .15 or 3.24 percent per month, based on average weather and usage.
Commercial customers, on average, would see a decrease of $2.07 per month or 1.05 percent.
lntermountain continues to urge all its customers to use energy wisely. As part of the general rate case
application, the company is proposing to implement several "Demand Side Management" (DSM) programs to
better enable its customers to conserve energy. Conservation tips and information on government payment
energy assistance are provided through bill inserts and on the company's website www.intgas.com. The website
also outlines a number of programs and tips to help our customers' level out their energy bills over the year, and
stabilize the potential impact that cold weather will have during periods of higher natural gas usage.
A Purchased Gas Cost Adjustment application is filed each year to reflect the gas costs lntermountain incurs on
behalf of its customers in its sales prices. A general rate change application is filed as needed to recover changes
in the cost of delivering natural gas to the customer's home or business. Both requests are subject to public
review and approval by the Idaho Public Utilities Commission. A copy of the applications are available for review
at the commission, the company's website at www.intgas.com as well as the commission's homepage at
www.puc.idaho.gov . Customers may also subscribe to the commission's RSS feed to receive periodic updates
via email.
WORKPAPERNOS.1-8
CASE NO. INT-G-16-03
INTERMOUNTAIN GAS COMPANY
(15 pages)
INTERMOUNTAIN GAS COMPANY
Summary of Northwest Pipeline TF-1 Full Rate Demand Costs
Line INT-G-15-02
No. Transportation Annual Therms (1l
(a) (b)
TF-1 Reservation Contract #1 413,667,840
2 TF-1 Reservation Contract #2 25,620,000
3 TF-1 Reservation Contract #3 73,200,000
4 TF-1 Reservation Contract #4 26,502,060
5 TF-1 Reservation Contract #5 32,940,000
6 TF-1 Reservation Contract #6 36,600,000
7 TF-1 Reservation Contract #7 87,840,000
8 TF-1 Reservation Contract #8 18,300,000
9 TF-1 Reservation Contract #9 104,782,140
10 TF-1 Reservation Contract #10 26,535,000
11 TF-1 Reservation Contract #11 51,221 ,700
12 TF-1 Reservation Contract #12 4,560,000
13 Total 901,768,740
Line INT-G-16-03
No. Transportation Annual Therms (3l
(a) (b)
14 TF-1 Reservation Contract #1 412,537,600
15 TF-1 Reservation Contract #2 25,550,000
16 TF-1 Reservation Contract #3 73,000,000
17 TF-1 Reservation Contract #4 26,429,650
18 TF-1 Reservation Contract #5 32,850,000
19 TF-1 Reservation Contract #6 36,500,000
20 TF-1 Reservation Contract #7 87,600,000
21 TF-1 Reservation Contract #8 18,250,000
22 TF-1 Reservation Contract #9 104,495,850
23 TF-1 Reservation Contract #10 26,462,500
24 TF-1 Reservation Contract #11 51 ,081 ,750
25 TF-1 Reservation Contract #12 0
26 Total 894,757,350
27 Total Annual Cost Difference (Line 26 minus Line 13)
(ll Daily Contract Demand multiplied by 366 days
(2l See Workpaper No. 1, Page 2, Lines 7 and 15, Column (d)
(Jl Daily Contract Demand multiplied by 365 days
INT-G-15-02
Prices
(c)
$ 0.041816
0.052596
0.041000
0.041000
0.041000
0.041000
0.041000
0.041000
0.041000
0.041000
0.041000
0.041000
INT-G-16-03
Prices (4l
(c)
$ 0.041977
0.052637
0.040972
0.040972
0.040972
0.040972
0.040972
0.040972
0.040972
0.040972
0.040972
0.000000
(4l Includes Northwest Pipeline charges for three months at leap year rates and for nine months at non-leap year rates.
(Sl See Exhibit No. 4, Line 3, Column (h)
$
$
$
$
$
Workpaper No. 1
Case No. INT-G-16-03
lntermountain Gas Company
Page 1 of 2
INT-G-15-02
Annual Cost
(d)
17,297,914
1,347,516
3,001 ,200
1,086,582
1,350,540
1,500,600
3,601,440
750,300
4,296,072
1,087,939
2,100,089
186,960 (2)
37,607,152
INT-G-16-03
Annual Cost
(d)
17,317,140
1,344,885
2,990,940
1,082,869
1,345,924
1,495,470
3,589,128
747,734
4,281 ,384
1,084,218
2,092,910
0 (2)
37,372,602
(234,550) (S)
INTERMOUNTAIN GAS COMPANY
Workpaper No. 1
Case No. INT-G-16-03
lntermountain Gas Company
Page 2 of 2
Summary of Northwest Pipeline TF-1 Discounted Demand Costs
Line INT-G-15-02
No. Transportation Annual Therms 11l
(a) (b)
TF-1 Reservation Contract #1 18,300,000
2 TF-1 Reservation Contract #2 29,484,960
3 TF-1 Reservation Contract #3 58,560,000
4 TF-1 Reservation Contract #4 36,600,000
5 TF-1 Reservation Contract #5 32,940,000
6 TF-1 Reservation Contract #6 11 ,529,000
7 TF-1 Reservation Contract #7 0
8 Total 187,413,960
Line INT-G-16-03
No. Transportation Annual Therms l3l
(a) (b)
9 TF-1 Reservation Contract #1 18,250,000
10 TF-1 Reservation Contract #2 29,404,400
11 TF-1 Reservation Contract #3 58,400,000
12 TF-1 Reservation Contract #4 36,500,000
13 TF-1 Reservation Contract #5 32,850,000
14 TF-1 Reservation Contract #6 11,497,500
15 TF-1 Reservation Contract #7 4,530,000
16 Total 191,431,900
17 Total Annual Cost Difference (Line 16 minus Line 8)
(1) Daily Contract Demand multiplied by 366 days
(2) See Workpaper No. 1, Page 1, Lines 12 and 25, Column (d)
(3) Daily Contract Demand multiplied by 365 days
INT-G-15-02 INT-G-15-02
Prices Annual Cost
(c) (d)
$ 0.026650 $ 487,699
0.022698 669,240
0.024600 1,440,576
0.027776 1,016,595
0.008500 279,990
0.036900 425,423
0.000000 0 (2)
$ 4,319,523
INT-G-16-03 INT-G-16-03
Prices l4l Annual Cost
(c) (d)
$ 0.026632 $ 486,031
0.024583 722,849
0.024583 1,435,651
0.027861 1,016,920
0.008500 279,225
0.036875 423,967
0.032764 148 420 (2) J
$ 4,513,063
$ 193,540 (5)
(4) Includes Northwest Pipeline charges for three months at leap year rates and for nine months at non-leap year rates.
(S) See Exhibit No. 4, Line 4, Column (h)
INTERMOUNTAIN GAS COMPANY
Summary of Upstream Capacity Full Rate Demand Costs
Line INT-G-15-02 I NT -G-15-02
No. Transportation Annual Therms (i) Prices
(a) (b) (c)
Upstream Agreement #1 26,004,300 $ 0.009016
2 Upstream Agreement #2 352,589,060 0.009019
3 Upstream Agreement #3 27,036,420 0.009016
4 Upstream Agreement #4 37,236,840 0.009016
5 Upstream Agreement #5 26,198,280 0.016504
6 Upstream Agreement #6 129,355,380 0.016633
7 Upstream Agreement #7 54,900,000 0.016504
8 Upstream Agreement #8 22,750,000 0.016661
9 Total 676,070,280
10 Estimated Upstream Capacity Release Credits
11 Total Annual Cost Including Capacity Release Credits
Line INT-G-16-03 INT-G-16-03
No. Transportation Annual Therms (2l Prices
(a) (b) (c)
12 Upstream Agreement #1 25,933,250 $ 0.008963
13 Upstream Agreement #2 351,503,260 0.008968
14 Upstream Agreement #3 26,962,550 0.008963
15 Upstream Agreement #4 37,281,100 0.008962
16 Upstream Agreement #5 26,126,700 0.016051
17 Upstream Agreement #6 128,898,520 0.016051
18 Upstream Agreement #7 54,750,000 0.016051
19 Upstream Agreement #8 22,500,000 0.016051
20 Total 673,955,380
21 Estimated Upstream Capacity Release Credits
22 Total Annual Cost Including Capacity Release Credits
23 Total Annual Cost Difference (Line 22 minus Line 11)
(1l Daily Contract Demand multiplied by 366 days
(2l Daily Contract Demand multiplied by 365 days
!3l See Exhibit No. 4, Line 5, Column (h)
$
$
$
$
$
Workpaper No. 2
Case No. INT-G-16-03
lntermountain Gas Company
Page 1 of2
I NT -G-15-02
Annual Cost
(d)
234,456
3,179,971
243,768
335,736
432,369
2,151,588
906,052
379,033
7,862,973
(500,000)
7,362,973
INT-G-16-03
Annual Cost
(d)
232,428
3,152,403
241 ,656
334,128
419,372
2,068,974
878,801
361 ,152
7,688,914
(500,000)
7,188,914
(174,059) (J)
INTERMOUNTAIN GAS COMPANY
Workpaper No. 2
Case No. INT-G-16-03
lntermountain Gas Company
Page 2 of 2
Summary of Upstream Capacity Discounted Demand Costs
Line INT-G-15-02
No. Transportation Annual Therms (1l
(a) (b)
1 Upstream Agreement #1 62,220,000
2 Upstream Agreement #3 37,009,920
3 Upstream Agreement #4 453,550,860
4 Upstream Agreement #5 37,577,220
5 Total 590,358,000
Line INT-G-16-03
No. Transportation Annual Therms (2l
(a) (b)
6 Upstream Agreement #1 62,050,000
7 Upstream Agreement #3 37,003,700
8 Upstream Agreement #4 452,311,650
9 Upstream Agreement #5 37,657,050
10 Total 589,022,400
11 Total Annual Cost Difference (Line 10 minus Line 5)
(1J Daily Contract Demand multiplied by 366 days
(2J Daily Contract Demand multiplied by 365 days
(3l See Exhibit No. 4, Line 6, Column (h)
INT-G-15-02 INT-G-15-02
Prices Annual Cost
(c) (d)
$ 0.013584 $ 845,197
0.014550 538,482
0.016749 7,596,696
0.016884 634,443
$ 9,614,818
INT-G-16-03 INT-G-16-03
Prices Annual Cost
(c) (d)
$ 0.013574 $ 842,265
0.014194 525,227
0.016979 7,679,856
0.016969 638,988
$ 9,686,336
$ 71,518 (3)
INTERMOUNT AIN GAS COMPANY
Summary of Other Storage Facility Costs
INT-G-15-02
Line Monthly
No. Storage Facilities Billing Determinant
(a) (b)
1 Demand Costs ·
2 Clay Basin I Reservation 266,250
3 Clay Basin II Reservation 221,880
4 Clay Basin Ill Reservation 213,010
5 Clay Basin I Capacity 31,950,000
6 Clay Basin II Capacity 26,625,000
7 Clay Basin Ill Capacity 25,560,000
8 Total Demand Costs 84,135,000
9 Rexburg LNG Facility·
10 Transportation Reservation
11 Variable Transportation
12 Total Rexburg LNG Facility Costs
13 Storage Demand Charge Credit
14 Total Costs Including Storage Credit
INT-G-16-03
Line Monthly
No. Storage Facilities Billing Determinant
(a) (b)
15 Demand Costs •
16 Clay Basin I Reservation 266,250
17 Clay Basin II Reservation 221 ,880
18 Clay Basin Ill Reservation 213,010
19 Clay Basin I Capacity 31,950,000
20 Clay Basin II Capacity 26,625,000
21 Clay Basin Ill Capacity 25,560,000
22 Total Demand Costs 84,135,000
23 Rexburg LNG Facility·
24 Transportation Reservation
25 Variable Transportation
26 Total Rexburg LNG Facility Costs
27 Estimated Storage Demand Charge Credit
28 Total Costs Including Storage Credit
29 Total Annual Cost Difference (Line 28 minus Line 14)
<1l Charge Based on Maximum Daily Withdrawal
<2l Charge Based on Maximum Contractual Capacity
<3l Non Additive Billing Determinants; Includes only Capacity Volumes
<•l See Exhibit No. 4, Line 20, Column (h)
INT·G-15-02
Prices
(c)
(1) $ 0.285338 $
(1) 0.285338
(1) 0.285338
(2) 0.002378
(2) 0.002378
(2) 0.002378
(3) $
INT-G-16-03
Prices
(c)
(1) $ 0.285338 $
(1) 0.285338
(1) 0.285338
(2) 0.002378
(2) 0.002378
(2) 0.002378
(3) $
INT-G-15-02
Monthll Cost
(d)
75,971 $
63,311
60,780
75,977
63,314
60,782
400,135 $
$
$
$
$
INT-G-16-03
Monthll Cost
(d)
75,971 $
63,311
60,780
75,977
63,314
60,782
400,135 $
$
$
$
$
$
Workpaper No. 3
Case No. INT-G-16-03
lntermountain Gas Company
Page 1 of 1
INT-G-15-02
Annual Cost
(e)
911 ,652
759,732
729,360
911 ,724
759,768
729,384
4,801 ,620
66,000
22,800
88,800
(1 ,810,000)
3,080,420
INT-G-16-03
Annual Cost
(e)
911,652
759,732
729,360
911,724
759,768
729,384
4,801,620
66,000
22,800
88,800
(1,810,000)
3,080,420
(4)
Line
No.
2
3
4
5
INTERMOUNTAIN GAS COMPANY
Peak Day Analysis for Demand Allocators
Peak Finn Sales
Descrietion RS-1 RS-2 GS-1
(a) (b) (c) (d)
PROPOSED DEMAND ALLOCATORS PER CASE NO. INT-G-16-03:
Peak Day Usage Per Customer 5.02 6.91 30.73
January 2016 Actual Customers 67,871 238,738 32,189
INT-G-16-03 Peak Day Therms (Line 2 mulitplied by Line 3) 340,712 1,649,680 989,168
Percent ofTotal ~ illlQm ~
LV-1
(e)
Workpaper No. 4
Case No. INT-G-16-03
lntermountain Gas Company
Page 1 of 1
Total
Peak Sales
(Q
19,369 2,998,929
~ lQQ QQQQ°tq
Line
No.
ACCOUNT 1910 VARIABLE AMOUNTS:
Description
(a)
Net Cumulative Deferred Gas Balance in 1910.2010 as of 10/1/15
Amortization in 1910.2020 as of 6/30/16
Estimated Therm Sales 7/1 through 9/30/16
Amortization Rate
Estimated Amortization in 1910.2020 at 9/30/16
Estimated Balance in 1910.2010 at 9/30/16
8 Deferred Gas Costs From Producers/Suppliers in 1910.2180 at 1011115
9 Deferred Gas Costs From Producers/Suppliers in 1910.2180 through 6130/16
10 Estimated Deferred Costs in 1910.2180 from 7/1 through 9/30/16
11 Estimated Balance in 1910.2180 at 9130116
12 Daily Gas Excess Sales Deferred in 1910.2240 at 6130116
13 Interest Deferred in 1910.2340 at 10/1/15
14 Interest Deferred in 1910.2340 through 6/30/16
15 Estimated Interest from 7/1 through 9/30/16
16 Estimated Balance in 1910.2340 at 9/30/16
17 ESTIMATED ACCOUNT 1910 VARIABLE BALANCE AT 9/30/16
INTERMOUNTAIN GAS COMPANY
Analysis of Account 1910 Surcharges (Credits)
Estimated September 30, 2016
Detail
(b)
25,694,321
(0 00209)
$
Detail
(c)
$
(641,611.23)
(53,701.13)
$
Amount Sub-Total
(d) (e)
696,360.54
(695,312.36)
$ 1,048.18
1,008,871.55
(3,371,873.07)
492,05-0.01
(1 ,870,951.51)
(279.12)
(865.69)
(49.04)
(1,19385)
Total
(I)
$ (1,871,097.18)
"U:,()~
D,) .-+ D,) 0 (0 (D (/) .... (D .... (D,_ ...... ~ z-g
0 CO "C
-::, • (D 01;-z_,
5· -;-I~
G) G).
D,) I (}1 (/) ......
() 'fl 00 3W
"C D,) ::, '<
INTERMOUNTAIN GAS COMPANY
Analysis of Account 1910 Surcharges (Credits)
Estimated September 30, 2016
Line
No.
9
10
11
12
Description
(a)
ACCOUNT 1910 LOST AND UNACCOUNTED FOR AMOUNTS:
Core Cumulative Deferred Gas Balance in 1910.2120 as of 10/1/15
Industrial Cumulative Deferred Gas Balance in 1910.2120 as of 10/1/15
Net Cumulative Deferred Gas Balance in 1910.2120 as of 10/1/15
Core Amortization in 1910.2130 as of 6/30/16
Estimated Therm Sales 7 /1 through 9/30/16
Amortization Rate
Estimated Amortization in 1910.2130 at 9/30/16
Industrial Amortization in 1910.2140 as of 6/30/16
Estimated Therm Sales 7/1 through 9/30/16
Amortization Rate
Estimated Amortization in 1910.2140 at 9/30/16
13 Estimated Balance in 1910.2120 at 9/30/16
14 Lost & Unaccounted For Gas Deferral in 1910.2150 at 10/1/15
15
16
17
18
19
20
21
22
Total Lost & Unaccounted For Gas through 6/30/16
Estimated Lost & Unaccounted For Gas 7/1 through 9/30/16
Estimated Total Lost & Unaccounted For Gas at 9/30/16
Base Rate Collection of Lost & Unaccounted For Gas through 6/30/16
Estimated Base Rate Collection of Lost & Unaccounted For Gas 7/1 through 9/30/16
Estimated Base Rate Collection of Lost & Unaccounted For Gas at 9/30/16
Estimated Lost & Unaccounted For Deferral (Line 17 minus Line 20)
Estimated Balance in 1910.2150 at 9/30/16
23 Core Allocation of Lost & Unaccounted For Gas Deferral
24 Industrial Allocation of Lost & Unaccounted For Gas Deferral
25 Estimated Balance in 1910.2150 at 9/30/16
26 Core Lost & Unaccounted For Interest Deferred in 1910.2420 at 10/1/15
27 Core Lost & Unaccounted For Interest Deferred in 1910.2420 through 6/30/16
28 Estimated Core Interest from 7/1 through 9/30/16
29 Estimated Balance in 1910.2420 at 9/30/16
30 Industrial Lost & Unaccounted For Interest Deferred in 1910.2360 at 10/1/15
31 Industrial Lost & Unaccounted For Interest Deferred in 1910.2360 through 6/30/16
32 Estimated Industrial Lost & Unaccounted For Interest from 7/1 through 9/30/16
33 Estimated Balance in 1910.2360 at 9/30/16
34 ESTIMATED ACCOUNT 1910 LOST AND UNACCOUNTED FOR GAS BALANCE AT 9/30/H
Detail
(b)
24,484,321
0.00223
64,482,520
0.00095
(530,639.89)
43,014.66
1,044,862.81
161,959.37
75%
25%
$
$
$
Detail
(c)
(730,031.38)
(259,752.58)
$
656,145.23
54,600.03
258,453.94
61,258.39
(487,625.23)
1,_2~822.18
Amount
(d)
(989,783.96)
710,745.26
319,712.34
194,878.81
(1 ,694,447.41)
(1 ,499,568.60)
(1 ,124,676.44)
(374,89215)
0.64
(36.79)
(3381)
(476)
17.92
~
Sub-Total Total
(e) (I)
40,673.64
(1,499,568.59)
(69.96)
3.22
(1,458,961.69) "'O ::i () ~ Ill r+ Ill o CC CD Cll .., CD..,CD;:i-
N ~ Z~
O C O "O -:,·co 01iiiz..,
s· -;-i ~
G) G).
Q) I CJ1 Cl) ...... 0) () I 00 3 c..>
"O Ill :, '<
Line
No. Description
(a)
ACCOUNT 1910 FIXED AMOUNTS:
Net Cumulative Deferred Gas Balance in 1910.2050 at 10/1/15
RS-1 Deferred Gas Balance in 1910.2060 at 1011115
Amortization for RS-1 in 1910.2060 at 6/30/16
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
Estimated RS-1 Therm Sales 7/1 through 9/30/16
RS-1 Amortization Rate
Estimated RS-1 Balance in 1910.2060 at 9/30/16
RS-2 Deferred Gas Balance in 1910.2070 at 10/1/15
Amortization for RS-2 in 1910.2070 at 6/30/16
Estimated RS-2 Therm Sales 7/1 through 9/30/16
RS-2 Amortization Rate
Estimated RS-2 Balance in 1910.2070 at 9/30/16
GS-1 Deferred Gas Balance in 1910.2080 at 10/1/15
Amortization for GS-1 in 1910.2080 at 6/30/16
Estimated Therm Sales 7/1 through 9/30/16
GS-1 Amortization Rate
Estimated GS-1 Balance in 1910.2080 at 9/30/16
LV-1 Deferred Gas Balance in 1910.2090 at 10/1/15
Amortization for LV-1 in 1910.2090 at 6130/16
Estimated LV-1 Block 1 & 2 Therm Sales 7/1 through 9/30/16
LV-1 Amortization Rate
Estimated LV-1 Balance in 1910.2090 at 9/30/16
23 Estimated Cumulative Balance in 1910.2050 at 9130116
24 Fixed Cost Collection Deferred in 1910.2200 at 1011/15
25 Fixed Cost Collection Deferred in 1910.2200 through 6/30/16
26 Estimated Fixed Cost Collection Deferred from 7/1 through 9/30/16
27 Estimated Balance in 1910.2200 at 9130116
28 Capacity Released/Purchased Deferred in 1910.2320 at 10/1/15
29 Capacity Released/Purchased Deferred in 1910.2320 through 6/30/16
30 Estimated Capacity Released/Purchased Deferred from 7/1 through 9/30/16
31 Estimated Balance in 1910.2320 at 9/30/16
32 Interest in 1910.2430 at 10/1/15
33 Interest Deferred in 1910.2430 through 6/30/16
34 Estimated Interest from 7/1 through 9/30/16
35 Estimated Balance in 1910.2430 at 9/30/16
INTERMOUNTAIN GAS COMPANY
Analysis of Account 1910 Surcharges (Credits)
Estimated September 30, 2016
Detail
(b)
846,864
(0 01425)
14,021,187
(0.00371)
9,616,269
0.00008
1,210,000
0.01951
$
$
$
$
Detail Amount Sub-Total Total
(c) (d) (e) (I)
$ 1,050,028.26
(5,226.14)
(441,722.61)
(12,067.81)
(459,016.56)
(24,152.11)
(582,071.02)
(52,018.60)
(658,241.73)
29,936.72
23,298.37
769.30
54,004.39
(7,758.02)
95,011.37
23,607.10
110,860.46
$ 97,634.82
$ (296,337.58)
(13,339,394.02)
12,418,012.52
(1,217,719.08)
$ (1,671,351.89)
(2,512,357.14)
(1,887,688.00)
(6,071,397.03)
$ (7.71)
(1,183.17)
"U:,0~ Ill ,.. Ill O ~~~~
(375.67)
(1,566.55)
w ~ z"fil oc:9-g _.., ::J --, oqii z z -· -l ::::J I Q GH) o,
Ill ..'... en 0)
06 0 (.,) 3 "C Ill ::::, '<
INTERMOUNTAIN GAS COMPANY
Analysis of Account 1910 Surcharges (Credits)
Estimated September 30, 2016
Line
No. Description Detail
(a) (b)
1 Management of Pipeline Transportation Capacity Deferred in 1910.2530 at 10/1/15
2 Management of Pipeline Transportation Capacity Deferred in 1910.2530 through 6/30/16
3 Estimated Deferral in 1910.2530 from 7/1 through 9/30/16
4 Estimated Balance in 1910.2530 at 9/30/16
5 RS-1 Amortization in 1910.2540 at 6/30/16
6 Estimated RS-1 Therm Sales from 7/1 through 9130/16 846,864
7 RS-1 Amortization Rate $ 0.01330
8 Estimated RS-1 Amortization in 1910.2540 at 9/30/16
RS-2 Amortization in 1910.2540 at 6130/16
10 Estimated RS-2 Therm Sales from 7/1 through 9/30/16 14,021,187
11 RS-2 Amortization Rate $ 0.01178
12 Estimated RS-2 Amortization in 1910.2540 at 9/30/16
13 GS-1 Amortization in 1910.2540 at 6/30/16
14 Estimated GS-1 Therm Sales from 7 /1 through 9/30/16 9,616,269
15 GS-1 Amortization Rate $ 0.01157
16 Estimated GS-1 Amortization in 1910.2540 at 9/30/16
17 Estimated Core Amortization in 1910.2540 at 9/30/16 (Sum of Lines 8, 12 and 16, Column (c))
18 LV-1 Amortization in 1910.2550 at 6/30/16
19 Estimated LV-1 Block 1&2 Therm Sales from 7/1 through 9/30/16 1,210,000
20 LV-1 Amortization Rate $ 0.00773
21 Estimated LV-1 Amortization in 1910.2550 at 9/30/16
22 Estimated Industrial Amortization in 1910.2550 at 9/30/16
23 Estimated Balance in 1910.2530 at 9/30/16
Detail
(c)
$
(3,940,000.00)
$
$ 415,711.98
11,263.29
426,975.27
$ 1,938,177.67
165,169.58
2,103,347.25
$ 1,162,417.54
111,260.23
1,273,677.77
$ 35,928.27
9,353.30
45,281.57
Amount Sub-Total
(d) (e)
(3,940,000.00)
3,804,000.29
45,281.57
$ (90,718.14)
Total
(I)
"'O 3" () ~ Ill..+ Q) 0 (C CD C/l ...., CD--.CD:,; ~ g z"fil
0 CO "O -:::, . CD U16iz .....
5 · -;-I~
G) G).
Ill • 01 (/) ..... 0) () . 00 3 (.,,)
"O Ill :::, '<
Line
No. Description
(a)
LNG Sales Credits Deferred in 1910.2800 at 10/1/15
2 LNG Amortization in 1910.2810 at 10/1/15
3 Amortization in 1910.2810 at 6/30/16
4 Estimated Amortization 7/1 through 9/30/16
Estimated Balance in 1910.2810 at 9/30/16
6 LNG Sales Interest Deferred in 1910.2815 at 10/1/15
7 LNG Sales Interest Deferred in 1910.2815 through 6/30/16
8 Estimated LNG Sales Interest from 7/1 through 9/30/16
9 Estimated Balance in 1910.2815 at 9/30/16
10 LNG Sales Deferral -Margin Sharing Deferred in 1910.2820 through 6/30/16
11 LNG Sales Deferral -O&M Recovery Deferred in 1910.2825 through 6/30/16
12 Estimated LNG Sales Credit Balance at 9/30/16
13 ESTIMATED ACCOUNT 1910 FIXED BALANCE AT 9/30/16
14 TOTAL DEFERRED ACCOUNT 1910 BALANCE
INTERMOUNTAIN GAS COMPANY
Analysis of Account 1910 Surcharges (Credits)
Estimated September 30, 2016
Detail
(b)
$
$
Detail
(c)
2,649.06
691,168.17
92,539.24
20.28
(1.60)
~
Amount Sub-Total
(d) (e)
$ (689,366.92)
786,356.47
10.13
(271,969.49)
(61,83601)
$ (236,805.82)
Total
(I)
$ (7,520,571.80)
$ (10,850,630.67)
lJ3"()~ Ill...+ ll) 0 CCCDCll-, CD -, CD ;,; 01g z"fil oc:O-o -::, • CD
C11 iii z -,
s· -;-t ~
G> G>. ll) I (11
(/) ..... () 'P 00 3 (,)
"O Ill ::,
'<
Line
No.
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
INTERMOUNTAIN GAS COMPANY
Analysis of LV-1 Tariff Block 1, Block 2, and Block 3 Adjustments
Block 1 Block 2 Block 3
Description Therm Sales Therm Sales Therm Sales
(a)
LV-1 Therm Sales (1/1/15 -12/31/15)
Blocks 1 and 2 Therm Sales
Percent Therm Sales between Blocks 1 and 2
Proposed Adjustment to LV-1 Tariff 1'1
LV-1 Therm Sales (1/1/15 -12/31/15)
Annualized Adjustment (Line 4 multiplied by Line 5)
Annualized Adjustment (Line 6)
Percent Annualized Sales included in Block 1 and Block 2
Adjustment to Block 1 and 2 (Line 7 multiplied by Line 8)
Block 1 and 2 Therms
Price Adjustment/Therm Block 1 and 2 (Line 9 divided by Line 10)
WACOG Commodity Charge Change 12>
Total Price Adjustment/Therm Block 1 and Block 2
Price Adjustment/Therm Block 3 (3>
WACOG Commodity Charge Change 121
Eliminate I NT -G-15-02 Variable Temporary
Total Price Adjustment/Therm Block 3
(b) (c)
5,709,005 0
5,709,005 0
100.000% 0.000%
(1> See Exhibit No. 4; Line 31, Column (I) minus the difference of Line 22, Column (0 minus Line 22, Column (c)
(2> See Exhibit No. 4; Line 22, Column (0 minus Line 22, Column (c)
(3> See Exhibit No. 6; Line 3, Column (e), plus Line 4, Column (e)
(d)
0
Workpaper No. 6
Case No. INT-G-16-03
lntermountain Gas Company
Page 1 of 1
$
$
$
$
$
$
$
$
Total
(e)
5,709,005
5,709,005
100.000%
(0.05670)
5,709,005
(323,701)
(323,701)
100.000%
(323,701)
5,709,005
(0.05670)
(0.03069)
(0.08739)
(0.00712)
(0.03069)
(0.00017)
(0.03798)
INTERMOUNTAIN GAS COMPANY
Analysis of Lost and Unaccounted For Gas ("L&U")
Line
No. Description
(a)
1 Lost and Unaccounted For Gas INT-G-15-02 (Therms)
2
3
4
Actual Oct 14 -Sep 15 L&U (Therms)
Actual Oct 14 -Sep 15 Sales
Oct 14 -Sep 15 L&U Factor (Line 2 divided by Line 3]
5 Lost and Unaccounted For Gas INT-G-16-03 (Therms)
6
7
8
9
10
11
12
13
14
Projected Oct 15 -Sep 16 L&U (Therms)
Estimated Oct 15 -Sep 16 Sales (1l
Oct 15 -Sep 16 L&U Factor (Line 6 divided by Line 7]
Lost and Unaccounted For Gas INT-G-16-03 (Dollars)
Lost & Unaccounted For Gas (1910-2150)(2)
Estimated Oct 15 -Sep 16 Sales (1 l
L&U rate per therm embedded in base rates
Oct 15 -Sep 16 Collection of Lost & Unaccounted for Gas
Projected L&U (Over)/Under Collection (Line 10 minus Line 13]
(1l Estimated Oct 15 -Sep 16 Sales (Therms)
RS-1
RS-2
GS-1
Industrial
Total Sales
(2l See Workpaper No. 5, Page 2, Line 17, Column (c)
$
Detail
(b)
178,227
591 ,930,425
(1,025,465)
663,089,111
663,089,111
0.00182
32,034,393
178,319,479
109,485,403
343,249,836
663,089,111
Workpaper No. 7
Case No. INT-G-16-03
lntermountain Gas Company
Page 1 of2
Amount
(c)
0.030%
-0.155%
$ (487,625)
1,206,822
$ {1 ,694,447}
INTERMOUNTAIN GAS COMPANY
Lost and Unaccounted For Gas Statistics <1>
Check for Dead Orders
Workpaper No. 7
Case No. INT-G-16-03
lntermountain Gas Company
Page 2 of2
Accounted
Year Check for Dead Orders Found Dead
795
513
796
923
893
204
Percent Found Dead For Therms
2011
2012
2013
2014
2015
2016 <2)
Year
2011
2012
2013
2014
2015
2016 (3)
Year
2011
2012
2013
2014
2015
2016 (3)
Year
2011
2012
2013
2014
2015
2016 <3)
10,093
5,089
5,041
6,102
5,974
1,996
Occurrences
14
3
3
15
10
0
Occurrences
8
15
17
6
10
3
Occurrences
154
177
163
187
188
120
Drive Rate Errors
Accounted For
Therms
2,331
26 ,559
7,201
0
Pressure Errors
Accounted For
Therms
(64,400)
9,823
33,429
996
Gas Loss from Line Breaks
Accounted For
Therms
49,856
68,221
66,063
119,291
73,648
64,474
<1l Gas loss resulting from these occurrences becomes accounted for gas
<2l Through February 2016
<3l Through June 2016
8%
10%
16% 213,590
15% 258,839
15% 251,250
10% 80,273
INTERMOUNTAIN GAS COMPANY
Peak Day Analysis for LNG Sales Credit Demand Allocators
Peak Usage
Line
No. Descrietion RS-1 RS-2 GS-1 LV-1
(a) (b) (c) (d) (e)
PROPOSED LNG SALES CREDIT DEMAND ALLOCATORS PER CASE NO. INT-G-16-03:
2 Peak Day Usage Per Customer 5.02 6.91 30.73
3 January 2016 Actual Customers 67,871 238,738 32,189
4 INT-G-16-03 Peak Day Therms (Line 2 mulitplied by Line 3) 340,712 1,649,680 989,168 19,369
5 Percent of Total ~ 4J l~~2°tq '~ ~~~zo,q ~
T-4 T-5
(D (g)
948,442 63,009
'~ ~~~zo,q lilllli.
Total
Peak Sales
(h)
4,010,380
lQQ QQQQ0tq
"'0:5"()<
Dl-D)~ <0CDcn.., (D-,(D;><" ..... 3 z-c 0 D) 0 C O -c,
-:::J • CD
._l. m z _,
s· -;-f ~
G) G).
D) I CX) en .....
() 9>
0 0 3 (.,.)
"C D)
:::J '<