ANNEXE I
Gazifère Inc.
Modifications du Tarif 200 avec commentaires
Ajustement du coût du gaz
Gazifère’s January 1, 2010 Rates
On December 4, 2009, Gazifère filed its Rates reflecting the impact on distribution, load
balancing, transportation and commodity rates resulting from the decision D-2009-151.
These rates are effective January 1, 2010 and reflect October 1, 2009 gas costs. Gazifère has
used these rates as the starting point for its January 1, 2010 Pass-on rates. Gazifère has
generated the change in gas costs from the October 1, 2009 Rate 200 relative to the proposed
January 1, 2010 Rate 200. This change in costs and rates has been applied to the Rates
resulting from the decision D-2009-151. Therefore, the January 1, 2010 Pass-on rates reflect
the impacts of the Régie’s decision D-2009-151 and the January 1, 2010 gas costs. Gazifère
is proposing to implement these rates on January 1, 2010.
Impact on Rate 200 from EB-2009-0398 – January 1, 2010 QRAM
Enbridge Gas Distribution is proposing the following changes to Rate 200 resulting from its
EB-2009-0398 QRAM application for rates effective January 1, 2010.
Enbridge is forecasting an increase in its PGVA reference price of $241.685/103m3 for EB2009-0398 effective January 1, 2010 relative to $236.950/103m3 embedded in its EB-20090309 effective October 1, 2009 rates.
Gas Supply Commodity
The Rate 200 gas supply commodity charge will increase from 19.6846 cents/m3 from EB2009-0309 effective October 1, 2009 to 19.7920 cents/m3 from EB-2009-0398 effective
January 1, 2010 for sales service customers.
The Rate 200 gas supply commodity charge will increase from 19.6668 cents/m3 from EB2009-0309 effective October 1, 2009 to 19.7743 cents/m3 from EB-2009-0398 effective
January 1, 2010 for buy/sell service customers.
Gas Supply Load Balancing Charge
From EB-2009-0309 effective October 1, 2009 to EB-2009-0398 effective January 1, 2010,
the Gas Supply Load Balancing charge will decrease. This is the result of higher carrying
cost of gas in inventory offset by lower load balancing related costs.
Transportation Charge
From EB-2009-0309 effective October 1, 2009 to EB-2009-0398 effective January 1, 2010,
the Transportation Charge has increased due to higher overall transportation related costs
driven primarily from an increase in TransCanada PipeLines tolls effective January 1, 2010.
Original : 2009-12-14
Page 1 de 2
ANNEXE I
Gazifère Inc.
Modifications du Tarif 200 avec commentaires
Ajustement du coût du gaz
Delivery Charge
From EB-2009-0309 effective October 1, 2009 to EB-2009-0398 effective January 1, 2010,
the Delivery charge will increase. This is the result of the higher PGVA reference price
from October 1, 2009 to January 1, 2010 applied to its Lost and Unaccounted for Gas
volumes.
Rider C
The 2010 PGVA balance results in a sales service credit for Rate 200. Effective from
January 1, 2010 to March 31, 2010, a credit of 7.1447 cents/m3 will be applied to Rate 200
sales and buy/sell service volumes.
Adjustment for 2008 Deferral Account Clearing
Enbridge Gas Distribution has notified the Ontario Energy Board (see copy of letters
attached) of its intent to clear its 2008 Deferral and Variance Account balances as part of its
April 1, 2010 QRAM application. At that time, Gazifère will receive a total debit charge of
approximately $258,000 (plus interest).
Original : 2009-12-14
Page 2 de 2
ANNEXE II
GAZIFÈRE INC.
CALCUL DE L'IMPACT UNITAIRE SUR LES TARIFS RÉSULTANT DE L'AUGMENTATION DU TARIF 200 EB-2009-0398
AJUSTEMENT DU COÛT DU GAZ
LINE
NO.
DESCRIPTION
Col. 3
Col. 4
Col. 5
Col. 6
Col. 7
Col. 8
TOTAL
TARIF
1
TARIF
2
TARIF
3
TARIF
5
TARIF
9
1
Gas Supply Cost increase $ '000
126.5
52.03
73.98
0.47
0.00
0.00
2
Transportation Cost increase $ '000
787.0
323.75
460.32
2.93
0.00
0.00
3
Delivery Cost increase $ '000
6.7
2.57
2.92
0.03
0.71
0.48
4
Total increase in cost of service $ '000
4.1
4.2
3
3
VOLUMES 10 m
Sales
Deliveries
117,803.4
153,361.2
48,460.8
58,788.0
68,903.6
69,079.2
439.0
439.0
0.0
14,181.0
0.0
10,874.0
5.1
5.2
5.3
UNIT RATE IMPACT cents/m 3
Gas Supply Cost
Transportation Cost
Delivery Cost
0.11
0.67
0.00
0.11
0.67
0.00
0.11
0.67
0.00
0.11
0.67
0.01
0.11
0.67
0.01
0.11
0.67
0.00
920.2
Notes:
The unit rate impacts by rate class are derived by comparing allocated Rate 200 gas supply and delivery costs from the current versus the previous pass-on.
The allocation methodology reflects the Régie's Decision D-2006-58 from the 2006 rate case (R-3587-2005).
Line 1
Compares allocated gas costs between the previous pass-on and the current pass-on.
Line 2
Compares allocated transportation costs between the previous pass-on and the current pass-on.
Line 3
Compares allocated delivery costs between the previous pass-on and the current pass-on.
Total change in Cost of Service as referenced in Annexe III, Line 32, column 13.
Line 4
Line 4.1 Sales volumes underpinning the Régie's Decision D-2009-151 (see Requête 3692-2009, GI-24, document 1, page 1of 1, lines 3,4,5,8,10,12,15 and 18, column 2).
Line 4.2 Delivery volumes underpinning the Régie's Decision D-2009-151 (see Requête 3692-2009, GI-24, document 1, page 1 of 1, line 23, column 2).
Line 5.1 Line 1 divided by Line 4.1
Line 5.2 Line 2 divided by Line 4.1
Line 5.3 Line 3 divided by Line 4.2. The unit rate equal zero due to rounding from four digits to two digits in exhibit.
Original: 2009-12-14
Page 1 de 1
ANNEXE III
GAZIFÈRE INC.
COÛT DU GAZ SELON LE TARIF 200 EB-2009-0398 (1)
BASÉ SUR LES VOLUMES DE L'ANNÉE TÉMOIN 2010
AJUSTEMENT DU COÛT DU GAZ
1000 m3
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
CONTRACT DEMAND
Col. 1
JAN
1103.1
TOTAL DELIVERIES
TOTAL SALES
T-SERVICE RECEIPTS
Col. 2
FEB
1103.1
Col. 3
MAR
1103.1
Col. 4
APR
1103.1
Col. 5
MAY
1103.1
Col. 6
JUN
1103.1
Col. 7
JUL
1103.1
Col. 8
AUG
1103.1
Col. 9
SEP
1103.1
Col. 10
OCT
1103.1
Col. 11
NOV
1103.1
Col. 12
DEC
Col. 13
TOTAL
1103.1
24,476.1
20,870.7
3,605.4
23,836.8
20,359.4
3,477.4
20,519.3
16,958.7
3,560.6
14,662.3
11,535.1
3,127.2
8,561.4
5,798.3
2,763.1
6,128.3
3,777.0
2,351.3
5,580.9
3,243.9
2,337.0
5,794.9
3,170.7
2,624.3
5,472.3
3,125.0
2,347.3
8,029.5
5,177.4
2,852.1
12,568.1
9,413.9
3,154.3
19,631.8
16,085.3
3,546.6
155,261.8 (2)
119,515.3
35,746.5
GAS COST CALCULATION
RATES
EB-2009-0398
Demand Charge
Delivery Charge
14.7000
1.0646
162,156
260,573
422,728
162,156
253,766
415,922
162,156
218,448
380,604
162,156
156,095
318,250
162,156
91,145
253,300
162,156
65,242
227,398
162,156
59,414
221,570
162,156
61,693
223,849
162,156
58,258
220,414
162,156
85,482
247,638
162,156
133,801
295,956
162,156
209,000
371,156
1,945.9
1,652.9
3,598.8
Load Balancing
Transportation
Gas supply (buy/sell)
Gas supply (system)
CURTAILMENT
0.4821
4.6868
19.7743
19.7920
-1.1000
117,999
978,170
82,541
4,048,121
114,917
954,205
80,519
3,948,946
98,923
794,818
67,069
3,289,328
70,687
540,627
45,620
2,237,365
41,275
271,754
22,931
1,124,644
29,545
177,021
14,938
732,595
26,906
152,035
12,829
629,190
27,937
148,603
12,540
614,989
26,382
146,461
12,359
606,126
38,710
242,655
20,476
1,004,220
60,591
441,210
37,231
1,825,932
94,645
753,884
63,615
3,119,921
748.5
5,601.4
472.7
23,181.4
TOTAL
5,649,559
5,514,509
4,630,742
3,212,549
1,713,904
1,181,497
1,042,530
1,027,918
1,011,741
1,553,699
2,660,920
4,403,221
33,602.8
Niagara Gas Transmission
RATES:
EB-2009-0398
118,483
5,768,042
118,483
5,632,992
118,483
4,749,225
118,483
3,331,032
118,483
1,832,387
118,483
1,299,980
118,483
1,161,013
118,483
1,146,401
118,483
1,130,224
118,483
1,672,182
118,483
2,779,403
118,483
4,521,704
1,421.8
35,024.6
29
30
RATES:
EB-2009-0309
5,607,334
5,476,221
4,618,644
3,242,215
1,787,749
1,270,904
1,136,043
1,121,996
1,106,171
1,632,325
2,706,922
4,397,849
34,104.4
31
32
Écart entre EB-2009-0398 et EB-2009-0309
920.2
Notes: (1) Coût du gaz total selon le tarif 200 en vigueur le 1er janvier 2010.
(2) Correspond aux volumes d'achat à 37,69 MJ/m³ tel qu'approuvés par la Régie dans sa décision D-2009-151 ( Voir R-3692-2009, GI-28, document 2.1, page 1 de 1, ligne 6, révisé le 25 septembre 2009).
Original: 2009-12-14
Page 1 de 1
ANNEXE IV
GAZIFÈRE INC.
COÛT DU GAZ SELON LE TARIF 200 EB-2009-0309 (1)
BASÉ SUR LES VOLUMES DE L'ANNÉE TÉMOIN 2010
AJUSTEMENT DU COÛT DU GAZ
1000 m3
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
CONTRACT DEMAND
Col. 1
JAN
1103.1
TOTAL DELIVERIES
TOTAL SALES
T-SERVICE RECEIPTS
Col. 2
FEB
1103.1
Col. 3
MAR
1103.1
Col. 4
APR
1103.1
Col. 5
MAY
1103.1
Col. 6
JUN
1103.1
Col. 7
JUL
1103.1
Col. 8
AUG
1103.1
Col. 9
SEP
1103.1
Col. 10
OCT
1103.1
Col. 11
NOV
1103.1
Col. 12
DEC
Col. 13
TOTAL
1103.1
24,476.1
20,870.7
3,605.4
23,836.8
20,359.4
3,477.4
20,519.3
16,958.7
3,560.6
14,662.3
11,535.1
3,127.2
8,561.4
5,798.3
2,763.1
6,128.3
3,777.0
2,351.3
5,580.9
3,243.9
2,337.0
5,794.9
3,170.7
2,624.3
5,472.3
3,125.0
2,347.3
8,029.5
5,177.4
2,852.1
12,568.1
9,413.9
3,154.3
19,631.8
16,085.3
3,546.6
155,261.8 (2)
119,515.3
35,746.5
GAS COST CALCULATION
RATES
EB-2009-0309
Demand Charge
Delivery Charge
14.7000
1.0606
162,156
259,594
421,749
162,156
252,813
414,969
162,156
217,627
379,783
162,156
155,508
317,664
162,156
90,802
252,958
162,156
64,997
227,153
162,156
59,191
221,347
162,156
61,461
223,617
162,156
58,039
220,195
162,156
85,161
247,316
162,156
133,298
295,453
162,156
208,215
370,371
1,945.9
1,646.7
3,592.6
Load Balancing
Transportation
Gas supply (buy/sell)
Gas supply (system)
CURTAILMENT
0.4866
4.0236
19.6668
19.6846
-1.1000
119,101
839,755
82,092
4,026,154
115,990
819,182
80,081
3,927,517
99,847
682,348
66,704
3,271,478
71,347
464,126
45,372
2,225,224
41,660
233,300
22,807
1,118,541
29,820
151,972
14,856
728,620
27,157
130,521
12,759
625,776
28,198
127,575
12,471
611,652
26,628
125,737
12,292
602,836
39,071
208,319
20,365
998,771
61,157
378,777
37,028
1,816,024
95,528
647,206
63,269
3,102,991
755.5
4,808.8
470.1
23,055.6
TOTAL
5,488,851
5,357,738
4,500,161
3,123,732
1,669,266
1,152,421
1,017,560
1,003,513
987,688
1,513,842
2,588,439
4,279,366
32,682.6
EB-2009-0309
118,483
5,607,334
118,483
5,476,221
118,483
4,618,644
118,483
3,242,215
118,483
1,787,749
118,483
1,270,904
118,483
1,136,043
118,483
1,121,996
118,483
1,106,171
118,483
1,632,325
118,483
2,706,922
118,483
4,397,849
1,421.8
34,104.4
Niagara Gas Transmission
RATES:
Notes: (1) Coût du gaz total selon le tarif 200 en vigueur le 1er octobre 2009.
(2) Correspond aux volumes d'achat à 37,69 MJ/m³ tel qu'approuvés par la Régie dans sa décision D-2009-151 ( Voir R-3692-2009, GI-28, document 2.1, page 1 de 1, ligne 6, révisé le 25 septembre 2009).
Original: 2009-12-14
Page 1 de 1
ANNEXE VI
GAZIFÈRE INC.
Autres composantes des tarifs
Ajustement du coût du gaz
Line
no
Description
Average
unit rate
of last block of
the proposed rate (1)
3
¢/m
1
1
Billing of the deficiency in minimum annual volume
2
Rate 3
3
Rate 4
4
5
Unit
load balancing
rate (2)
¢/m 3
Proposed
rate
of other
components
¢/m 3
2
3=1+2
13.46
(6.30)
7.16
load factor less
or equal to 70%
11.57
(6.59)
4.98
load factor higher than 70%
10.52
(6.59)
3.93
6
Rate 5
8.06
(6.21)
1.85
7
Rate 9
6.82
(5.65)
1.17
8
Maximum charge on a prorated basis of any annual
minimum bill incurred by Gazifère
9
Rate 3
13.46
s/o
13.46
10
Rate 4
11
load factor less
or equal to 70%
11.57
s/o
11.57
12
load factor higher than 70%
10.52
s/o
10.52
13
Rate 5
8.06
s/o
8.06
14
Rate 9
6.82
s/o
6.82
Notes: (1) Average Unit Rate = Last Block of Delivery Charge+ Transportation Charge per the proposed rates included in Annexe V.
(2) Unit Load Balancing Rate = (Allocated Load Balancing and Transportation Costs including Return & Taxes by Rate Class)/Volume
Original: 2009-12-14
Page 1 de 1
ANNEXE VII
Gazifère Inc.
Taux unitaire et revenus par composante et par tarif
Ajustement du coût du gaz
January 1st, 2010 with October 09 rate 200
D-2009-151
Line No.
Unit rate
cents/m3
Col. 1
Total
$ '000
Col. 2
January 1st, 2010 Pass-on
Unit rate
cents/m3
Col. 3
Total
$ '000
Col. 4
Variance
%(1)
$'000
Col. 5
Col. 6
Rate 1
1.1
1.2
1.3
1.4
1.0
Gas Supply Commodity
Gas Supply Load Balancing
Transportation
Distribution
Total
19.91
4.05
4.05
12.18
40.19
9,650
2,379
1,964
7,158
21,151
20.02
4.05
4.72
12.18
40.97
9,702
2,382
2,288
7,158
21,530
52
3
324
378
1%
0%
16%
0%
2%
19.91
4.70
4.05
21.48
50.14
13,720
3,245
2,793
14,835
34,594
20.02
4.70
4.72
21.48
50.92
13,794
3,248
3,253
14,835
35,131
74
3
460
537
1%
0%
16%
0%
2%
19.91
1.69
4.05
8.06
33.72
87
7
18
35
148
20.02
1.70
4.72
8.06
34.50
88
7
21
35
151
0
0
3
1%
0%
16%
0%
2%
19.91
1.17
4.05
3.41
28.55
166
484
650
20.02
1.18
4.72
3.41
29.33
166
484
651
-
19.91
0.69
4.05
3.34
27.99
75
363
438
20.02
0.69
4.72
3.34
28.77
-
-
363
438
19.91
3.83
4.05
14.92
42.71
23,458
5,872
4,775
22,876
56,980
20.02
3.83
4.72
14.92
43.49
23,584
5,879
5,562
22,876
57,900
Rate 2
2.1
2.2
2.3
2.4
2.0
Gas Supply Commodity
Gas Supply Load Balancing
Transportation
Distribution
Total
Rate 3
3.1
3.2
3.3
3.4
3.0
Gas Supply Commodity
Gas Supply Load Balancing
Transportation
Distribution
Total
3
Rate 5
4.1
4.2
4.3
4.4
4.0
Gas Supply Commodity
Gas Supply Load Balancing
Tranportation
Distribution
Total
1
1
1%
0%
16%
0%
3%
Rate 9
5.1
5.2
5.3
5.4
5.0
Gas Supply Commodity
Gas Supply Load Balancing
Transportation
Distribution
Total
0
1%
1%
16%
0%
3%
127
7
787
920
1%
0%
16%
0%
2%
75
0
-
Gazifère Total
6.1
6.2
6.3
6.4
6.0
Gas Supply Commodity
Gas Supply Load Balancing
Transportation
Distribution
Total
Notes:
(1) The % variance depicts the change in the unit rates.
Original: 2009-12-14
Page 1 de 3
ANNEXE VIII
Gazifère Inc.
Revenus totaux par composantes
Tarif du 1er janvier 2010 versus tarif du 1er octobre 2009
Ajustement du coût du gaz
('000 Dollars)
40000
30000
20000
10000
0
October 09
January 10
Gas Supply Commodity, Load Balancing &
Transportation
Distribution
Original: 2009-12-14
Page 2 de 3
ANNEXE IX
Gazifère Inc.
Taux unitaire par composante
Tarif du 1er janver 2010 versus tarif du 1er octobre 2009
Ajustement du coût du gaz
55
50
45
Gas Supply Commodity
Gas Supply Load Balancing
Transportation
Distribution
40
Unit Rate cents/m3
35
30
25
20
15
10
5
0
1
Oct 09
Jan Passon
2
Rate 1
Original: 2009-12-14
Oct309
4
Jan Passon
Rate 2
Oct
5 09
6
Jan Passon
Rate 3
7 09
Oct
8
Jan Passon
Rate 5
Oct
9 09
10
Jan Passon
11
12
Rate 9
Page 3 de 3
ANNEXE X
GAZIFÈRE INC.
ANNEXE AJUSTEMENT DU COÛT DU GAZ
AJUSTEMENT DU COÛT DU GAZ
ANNEXE AJUSTEMENT DU COÛT DU GAZ
Le présent ajustement du coût du gaz s’applique à tous les volumes de gaz vendus ou livrés
durant la période du 1er janvier 2010 au 31 mars 2010.
Tarifs
Service de vente et
service achat / revente
(¢/m3)
Service de
transport
(¢/m3)
1à9
(7,18)
0,00
Note: (1) Voir "Rider C - Gas Cost Adjustment Rider " à la page 54 du "Rate Handbook"
de Enbridge Gas Distribution, requête EB-2009-0398.
Le montant de (7,1447) ¢/m³ a été ajusté pour la valeur calorifique.
Original: 2009-12-14
Page 1 de 1
ANNEXE XI
Enbridge Gas distribution's documents
-
Lettre de transmission de la demande d'ajustement des tarifs à la Commission de l'énergie de l'Ontario (OEB)
-
Application to the OEB for Rate Adjustment
-
Quaterly Rate Adjustment Mechanism
-
Rate 200
-
Rider A, B, C & E
-
EB-2009-0055 (2008 Deferral and variance Accounts)
Original: 2009-12-14
28 Pages
500 Consumers Road
North York, ON M2J 1P8
PO Box 650
Scarborough ON M1 K 5E3
Norm Ryckman
Director, Regulatory Affairs
Tel
416-753-6280
Fax 416-495-6072
Email norm.ryckman@enbridge.com
VIA COURIER AND EMAIL
December 11 , 2009
Ms. Kirsten Walli
Board Secretary
Ontario Energy Board
2300 Yonge Street
Toronto, Ontario
M4P 1E4
Dear Ms. Walli:
Re:
EB-2009-0398 (QRAM Application)
I am hereby filing with you one electronic copy of the Application of Enbridge Gas
Distribution Inc. ("Enbridge") in Word and PDF formats, and 2 copies of the
Application with the supporting evidence (binder format) by courier, for an order
approving or fixing interim rates for the sale, distribution, storage, and
transmission of gas effective January 1,2010.
The Board approved the original Quarterly Rate Adjustment Mechanism
("QRAM") process, and subsequent modifications in the following proceedings,
RP-2000-0040, RP-2002-0133 and RP-2003-0203. On September 21, 2009, the
Board issued its decision in the QRAM Generic Proceeding under docket number
EB-2008-0106. This Application and the supporting evidence were both prepared
in accordance with the process for Enbridge's QRAM and the EB-2008-0106
decision. A description of the QRAM process is attached to the Application as
Appendix A.
Enbridge is concurrently serving an electronic copy of the Application with
supporting evidence in PDF format, or a hard copy (binder format) by courier, if
requested, on the interested parties listed in Appendix B to this Application.
The following is the proposed procedural schedule for processing the Application,
according to the prescribed regulatory framework for the QRAM process:
•
Any responsive comments from interested parties must be filed with the
Board, and served on Enbridge and the other interested parties, on or
before December 16, 2009.
2009-12-11
Ms. Walli
Page 2
•
Any reply comments from Enbridge must be filed with the Board, and
served on all interested parties, on or before December 18, 2009.
•
The Board would thereafter issue an order approving the applied-for rate
adjustments, or modifying them as required, effective January 1, 2010.
Enbridge requests the Board to issue such an order on or before December 22,
2009. Enbridge would then be able to implement the resultant rates during
Enbridge's first billing cycle in January 2010.
The prescribed procedures for processing cost claims are as follows:
•
Due to the mechanistic nature of the QRAM application, the Board does
not anticipate awarding costs. Parties that meet the eligibility criteria
contained in the Board's Practice Direction on Cost Awards may submit
costs with supporting rationale as to how their participation contributed to
the Board's ability to decide on this matter.
•
Any party eligible for an award of costs must file a claim with the Board
and Enbridge no later than ten days from the date of the Board's decision
and order. Should Enbridge have any comments concerning any of the
claims, these concerns shall be forwarded to the Board and to the
claimant within seven days of receiving the claims. Any response to
Enbridge's comments must be filed with the Board and Enbridge within
seven days of receiving the comments.
Yours truly,
rraf~
Norm Ryckman
Director, Regulatory Affairs
Encl.
cc:
Mr. Fred Cass, Aird & Berlis LLP
All Interested Parties EB-2008-0219 and EB-2009-0172
Filed: 2009-12-11
EB-2009-0398
Exhibit Q1-1
Tab 2
Schedule 1
Page 1 of 5
ONTARIO ENERGY BOARD
IN THE MATTER OF the Ontario Energy Board Act,
1998, S.O. 1998, c. 15, Sched. B, as amended.
AND IN THE MATTER OF an Application by
Enbridge Gas Distribution Inc. for an Order approving
or fixing rates for the sale, distribution, storage, and
transmission of gas effective January 1, 2010.
APPLICATION FOR
RATE ADJUSTMENT
Gas Costs
First Quarter - Test Year 2010
Introduction
1. Enbridge Gas Distribution Inc. ("Enbridge") hereby applies to the Board for
an order approving or fixing interim rates for the sale, distribution, storage,
and transmission of gas effective January 1, 2010. This Application is made
pursuant to, and the order would be issued under, section 36 of the Ontario
Energy Board Act, 1998, as amended.
2. This Application and the supporting evidence were prepared in accordance
with the process for Enbridge's Quarterly Rate Adjustment Mechanism
("QRAM").
The Board approved the original QRAM process, and
subsequent modifications, in the following proceedings:
•
RP-2000-0040: The QRAM process was prescribed, under Issue
2.2, in the "Settlement Proposal (Main Case)" dated May 11, 2001;
see Exhibit N2, Tab 1, Schedule 1, pp. 13-18 of 54. The Board
approved the entire Settlement Proposal on May 30, 2001; see
transcript volume no. 1, pp. 107-9.
•
RP-2002-0133: The QRAM process was modified, under Issue 4.2,
in the Settlement Proposal dated March 14, 2003; see Exhibit N1,
Tab 1, Schedule 1, pp. 21-25 of 93. The Board approved the entire
Settlement Proposal on March 20, 2003; see transcript volume 1,
para. 687.
Filed: 2009-12-11
EB-2009-0398
Exhibit Q1-1
Tab 2
Schedule 1
Page 2 of 5
•
RP-2003-0203: The QRAM process was modified, under Issue
15.11 in the Settlement Proposal dated June 17, 2004, Exhibit N1,
Tab 1, Schedule 1, pp. 56-58 of 59. The Board approved the entire
Settlement Proposal on June 16, 2003; see transcript volume 1,
paragraphs. 32 to 39.
•
EB-2008-0106: The QRAM process was modified in the Board’s
Decision dated September 21, 2009 at pages 5, 16 and 22.
3. The particulars of the QRAM process are described, for ease of reference, in
Appendix A to this Application. Pursuant to the Board’s direction, the
“Regulatory Framework” has further been modified to include procedures for
processing cost claims and awards, if any.
Utility Price and Customer Impacts
4. Enbridge’s utility price during the fourth quarter of Test Year 2009 was
$236.950/103m3 ($6.287/GJ @ 37.69 MJ/m3). Enbridge has recalculated the
utility price for the first quarter of Test Year 2010 using the prescribed
methodology, reflecting a higher commodity cost and higher tolls for
TransCanada PipeLines. The recalculated utility price is $241.685/103m3
($6.412/GJ @ 37.69 MJ/m3).
5. The resultant rates would increase the total bill for a typical residential
customer on system gas by $23 or 2.0% (approx.) annually and, for a typical
residential customer on direct purchase, would increase the total bill by $20
or 3.5% (approx.) annually.
PGVA
6. Enbridge’s existing Rider C unit rates for customers on sales service will
continue to be in effect until March 31, 2010. The unit rates and extended
clearing period to March 31, 2010 for Rider C was approved in the EB-20090309 (October 1, 2009 QRAM) Decision. For residential customers on sales
service the unit rate is a credit of (6.9075) cents / m3
7. For the first quarter of 2010, Enbridge has re-valued its gas in inventory to
reflect the recalculated utility price of $241.685/103m3. For example, the
adjusted gas in inventory balance in the PGVA, when translated into ¢/m3
based on forecast volumes for the 12 months of Test Year 2010, is a credit of
(0.1474) cents / m3 for residential customers on sales service.
8. For billing purposes, the re-valued gas in inventory unit rate of (0.1474) cents
/ m3 will be combined with the existing unit rate of (6.9075) cents/ m3
Filed: 2009-12-11
EB-2009-0398
Exhibit Q1-1
Tab 2
Schedule 1
Page 3 of 5
resulting in a Rider C unit rate of ($7.0549) cents/ m3 applicable to residential
customers on sales service. The combined Rider C unit rates will be
effective from January 1, 2010 to March 31, 2010. On March 31, 2010 the
existing rider unit rate of (6.9075) cents/ m3 will terminate.
Regulatory Framework
9. The QRAM process includes the regulatory framework for interested parties
as well as the Board and its staff to examine the Application with the
supporting evidence and, thereafter, for the Board to issue an order
disposing of the Application. Enbridge's list of interested parties is presented
in Appendix B; the list includes the name(s) of the parties and their
respective representative(s).
10. The following is the prescribed regulatory framework for processing the
Application:
•
Any responsive comments from interested parties are filed with the
Board, and served on Enbridge and the other interested parties, on
or before December 16, 2009.
•
Any reply comments from Enbridge are filed with the Board, and
served on all interested parties, on or before December 18, 2009.
•
The Board thereafter issues an order approving the applicable rate
adjustments or modifying them as required, effective January 1,
2010.
11. Enbridge requests that the Board issue such an order on or before
December 22, 2009. Enbridge would then be able to implement the resultant
rates during the first billing cycle in January 2010.
12. The following procedures are prescribed for cost claims for QRAM
applications, as directed by the Board on February 14, 2007:
•
Due to the mechanistic nature of the QRAM application, the Board
does not anticipate awarding costs. Parties that meet the eligibility
criteria contained in the Board’s Practice Direction on Cost Awards
may submit costs with supporting rationale as to how their
participation contributed to the Board’s ability to decide on this
matter.
•
Any party eligible for an award of costs must file a claim with the
Board and Enbridge no later than ten days from the date of the
Filed: 2009-12-11
EB-2009-0398
Exhibit Q1-1
Tab 2
Schedule 1
Page 4 of 5
Board’s decision and order. Should Enbridge have any comments
concerning any of the claims, these concerns shall be forwarded to
the Board and to the claimant within seven days of receiving the
claims. Any response to Enbridge’s comments must be filed with
the Board and Enbridge within seven days of receiving the
comments.
13. Enbridge also requests that all documents in relation to the Application and
its supporting evidence, including the responsive comments of any interested
party, be served on Enbridge and its counsel as follows:
(1) Mr. Norm Ryckman
Director, Regulatory Affairs
Telephone:
Fax:
Electronic access:
(416) 495-5499
(416) 495-6072
egdregulatoryproceedigns@enbridge.com
(2) Ms. Tania Persad
Senior Legal Counsel,
Regulatory
Telephone:
Fax:
Electronic access:
(416) 495-5891
(416) 495-5994
tania.persad@enbridge.com
Address for personal service:
Enbridge Gas Distribution Inc.
500 Consumers Road
Willowdale, Ontario
M2J 1P8
Mailing address:
P.O. Box 650
Scarborough, Ontario
M1K 5E3
Filed: 2009-12-11
EB-2009-0398
Exhibit Q1-1
Tab 2
Schedule 1
Page 5 of 5
DATE: December 11, 2009
ENBRIDGE GAS DISTRIBUTION INC.
Per: -----=-------=~::....--_-+---+-----Norm Ryckman
Director, Regulatory Affairs
Filed: 2009-12-11
EB-2009-0398
Exhibit Q1-1
Tab 2
Schedule 1
Appendix A
Page 1 of 6
QUARTERLY RATE ADJUSTMENT MECHANISM
Introduction
1.
The QRAM process approved by the Board for Enbridge now comprises
the following components: the calculation of a forecast price for ratemaking purposes during a test year ("utility price"); the means of adjusting
the utility price for rate-making purposes during a test year; the means of
calculating and clearing variances recorded in Enbridge's Purchased Gas
Variance Account ("PGVA"); the regulatory framework for approving
adjustments and clearances; and the means of providing pricing
information to end-use customers, or their marketers, and to other
stakeholders as well.
2.
The QRAM process is intended to achieve or accommodate the following
eight principles:
•
•
•
•
•
•
•
•
more reflective of market prices on an ongoing basis;
enhanced price transparency;
regular quarterly review process;
customer awareness, customer acceptance, and less confusion in the
marketplace;
mitigation of large adjustments of customer bills;
fairness and equity among all customer groups;
implementation in a cost effective manner: and
reduced regulatory burden relative to the former "trigger methodology",
and the related rate adjustment mechanism, for Enbridge's PGVA.
Utility Price
3.
Enbridge calculates the utility price for a test year by using its Boardapproved methodology to develop a forecast of its supply (i.e., commodity)
costs, including buy/sell as well as system gas, and its transportation
costs for the test year. The forecast of supply costs includes the forecast
price of natural gas based on a so-called "21-day strip”.
4.
This 21-day strip represents the simple average of future market prices, as
reported by various media and other services, over a 21-day period for a
basket of pricing periods, pricing points, and pricing indices that reflects
Filed: 2009-12-11
EB-2009-0398
Exhibit Q1-1
Tab 2
Schedule 1
Appendix A
Page 2 of 6
Enbridge's gas purchase arrangements, both actual and anticipated,
during the 12 months subsequent to the 21-day period.
5.
Enbridge uses the initial utility price as the basis for calculating the gas
supply charges for Sales service, subject to subsequent adjustment(s),
during a test year. Sales service is provided to buy/sell gas customers,
who are direct purchasers, as well as to system gas customers. Enbridge
also uses the initial utility price for PGVA purposes.
Price Adjustment
6.
Enbridge recalculates the utility price, using the same methodology, for
each of the subsequent three quarters of the test year. The forecast of the
price of natural gas, in each case, is based on a 21-day strip. The last day
of each 21-day strip precedes the quarter in question by no more than 31
days.
7.
Whenever a recalculated utility price comes into effect at the beginning of
a quarter, Enbridge calculates the consequential effect of this price on the
following commodity-related costs: carrying costs of gas in storage,
working cash allowance (gas costs), unbilled and unaccounted for gas,
company-use gas, and lost and unaccounted for gas (storage). Enbridge
then uses the recalculated utility price, together with the consequential
effect on these commodity-related costs, as the basis for adjusting the
revenue requirement for a test year and, in turn, the gas supply charges
for sales service, transportation charges for Sales and Western T-service,
and the delivery charges and gas supply load balancing charges (when
discrete) for distribution service, effective as of the beginning of the
quarter. Enbridge also begins to use the recalculated utility price for
PGVA purposes on the same effective date.
8.
The following provisions apply when adjusting the revenue requirement for
a test year:
(a)
The volumetric forecast of Sales service, Western T-service and
Ontario T-service is Enbridge's as-filed forecast for the test year,
as updated (if any), until there is a Board-approved forecast. The
latter is the volumetric forecast thereafter.
(b)
The capital structure for rate base and rate of return purposes is
Enbridge's as-filed capital structure for the test year, as updated (if
Filed: 2009-12-11
EB-2009-0398
Exhibit Q1-1
Tab 2
Schedule 1
Appendix A
Page 3 of 6
any), until there is a Board-approved capital structure. The latter is
the capital structure thereafter.
(c)
The cost of equity for rate of return purposes is the Board-approved
rate of return on equity ("ROE") for the prior test year,
notwithstanding Enbridge's as-filed ROE, until there is a Boardapproved ROE for the test year. The latter is the cost of equity
thereafter.
PGVA
9.
Enbridge records in the PGVA the product derived by multiplying the
volumes delivered during each month of a test year by the variances
between the utility price in effect and Enbridge's actual purchased gas
costs per unit during each month of a test year.
10.
Enbridge shall use the AECO index plus Nova transportation plus fuel
costs as the benchmark in calculating the components of the PGVA.
11.
Whenever a recalculated utility price comes into effect at the beginning of
a quarter, the opening balance of gas in storage is adjusted at the same
time in order to reflect the recalculated utility price. The resultant debits or
credits, as the case may be, are recorded in the PGVA as commodityrelated entries.
12.
For the purpose of developing rate riders (i.e. Rider C unit rates) for
clearance of the PGVA balance, Enbridge identifies the balances /
amounts attributable to commodity, transportation and load balancing
components of the PGVA.
13.
Each quarter, Enbridge forecasts the balances / amounts attributable to
commodity, transportation and load balancing components of the PGVA
for the following 12 month period. Enbridge also records variances
reflecting the difference between what was forecast to be recovered in the
previous quarter from rate riders and what was actually recovered. These
variances are included in the establishment of the rate rider unit rates for
the next 12 month period. As a result, Enbridge updates quarterly its rate
rider unit rates to reflect the updated forecast of PGVA balances and the
historical recovery variance.
Filed: 2009-12-11
EB-2009-0398
Exhibit Q1-1
Tab 2
Schedule 1
Appendix A
Page 4 of 6
14.
Based on the amounts attributable to commodity, transportation and load
balancing components of the PGVA, individual riders are determined and
applied to Sales service, Western T-service and Ontario T-service. The
unit rates are derived based on the 12 month test year forecast of volumes
(i.e. 12-month rolling rider methodology). The rate riders (i.e. Rider C unit
rates) become effective at the beginning of the quarter and specify, by rate
class, the unit rates for Sales, Western T-service and Ontario T-service
customers.
15.
Whenever there is a change in upstream transportation tolls during a
quarter, Enbridge records the consequential effect of the change in the
PGVA. Enbridge also adjusts the transportation charge for all Sales and
Western T-service customers at the beginning of the next quarter, in order
to account for the consequential effect of the changes in upstream
transportation tolls.
Regulatory Framework (Including Cost Awards)
16.
Enbridge maintains and updates, from time to time, a list of interested
parties for the purposes of the QRAM process; for example, serving
documents filed with the Board. An "interested party" is Board staff, an
intervenor in Enbridge's most recent rates proceeding, and any other
stakeholder in Enbridge's franchise area who advises Enbridge of its
interest in the QRAM process. The list of interested parties includes the
name of each interested party and, as each of them indicates, the name(s)
of their respective representative(s) and any limitation(s) on service (e.g.,
application only). Enbridge also maintains and updates the address(es)
for service of each such representative.
17.
Each quarter, Enbridge files a corresponding application and supporting
evidence with the Board, and serves one or both on each interested
party's representative(s), no fewer than 19 calendar days prior to the
quarter in question. The application seeks approval of the applicable
utility price for PGVA purposes, the corresponding gas supply charges for
sales service, the corresponding transportation charge for Sales and
Western T-service and delivery charges and gas supply load balancing
charges (when discrete) for distribution service, and the rate rider to be
used to clear the PGVA balance. The application will include an executive
summary of the application in a tabular format or otherwise.
18.
Interested parties may file with the Board, and serve on Enbridge and the
other interested parties, comments in response to each application. The
Filed: 2009-12-11
EB-2009-0398
Exhibit Q1-1
Tab 2
Schedule 1
Appendix A
Page 5 of 6
deadline for filing and serving responsive comments is five calendar days
after Enbridge files and serves its application. Enbridge may file with the
Board, and serve on the interested parties, comments in reply to any
responsive comments. The deadline for reply comments is two calendar
days after the interested parties file and serve their respective responsive
comments.
19.
The Board thereafter issues an order, prior to the quarter in question if
possible, approving the applicable utility price for PGVA purposes, the
corresponding gas supply charges for sales service, the corresponding
gas distribution, transportation and load balancing charges (when
discrete) for distribution service, and the rate rider to be used to clear
PGVA, or modifying them as required, effective as of the beginning of the
quarter.
20.
Due to the mechanistic nature of the QRAM application, the Board does
not anticipate awarding costs. Parties that meet the Board eligibility
criteria contained in the Board’s Practice Direction on Cost Awards may
submit costs with supporting rationale as to how their participation
contributed to the Board’s ability to decide on this matter.
21.
Any party eligible for an award of costs must file a claim with the Board
and Enbridge no later than ten days from the date of the Board’s decision
and order. Should Enbridge have any comments concerning any of the
claims, these concerns shall be forwarded to the Board and to the
claimant within seven days of receiving the claims. Any response to
Enbridge’s comments must be filed with the Board and Enbridge within
seven days of receiving the comments.
Pricing Information
22.
Enbridge's monthly bill displays the gas supply charges for Sales service
and the rate rider (if any) in effect for the month, and the total of the two
when there is a rate rider, expressed in ¢/m3 in each case. Enbridge
ensures that customers are given a clear explanation, by means of a
message on the bill or a bill insert, of the pricing information displayed on
the bill and, whenever the pricing information changes, of the significance
of the changes.
23.
Enbridge posts on its website, promptly after receiving the Board’s order in
this regard, information on the gas supply charges for Sales service and
the rate rider (if any), and the total of the two when there is a rate rider,
Filed: 2009-12-11
EB-2009-0398
Exhibit Q1-1
Tab 2
Schedule 1
Appendix A
Page 6 of 6
expressed in ¢/m3 in each case. Enbridge provides on its website a
meaningful description of the posted information so as to inform
customers of its significance, in plain language, and of the significance of
changes in the posted information whenever change occurs.
24.
Enbridge’s website provides links to other websites, such as
energyshop.com, that provide prices and other information on competitive
gas services in Enbridge's franchise area.
25.
Enbridge also makes similar information available, through an additional
branch, on Enbridge’s Curtailment and Buy/Sell Information Line on a
timely basis.
RATE NUMBER:
200
WHOLESALE SERVICE
APPLICABILITY:
To any Distributor who enters into a Service Contract with the Company to use the Company's natural gas
distribution network for the transportation of an annual supply of natural gas to customers outside of the
Company's franchise area.
CHARACTER OF SERVICE:
Service shall be continuous (firm), except for events as specified in the Service Contract including force majeure,
up to the contracted firm daily demand and subject to curtailment or discontinuance, of demand in excess of the
firm contract demand, upon the Company issuing a notice not less than 4 hours prior to the time at which such
curtailment or discontinuance is to commence.
RATE:
Rates per cubic metre assume an energy content of 37.69 MJ/m³.
Billing Month
January
to
December
Monthly Customer Charge
The monthly customer charge shall be
negotiated with the applicant and shall not exceed:
$2,000.00
Delivery Charge
Per cubic metre of Firm Contract Demand
Per cubic metre of gas delivered
14.7000 ¢/m³
1.0646 ¢/m³
Gas Supply Load Balancing Charge
0.4821 ¢/m³
Transportation Charge per cubic metre
4.6868 ¢/m³
System Sales Gas Supply Charge per cubic metre
(If applicable)
Buy/Sell Sales Gas Supply Charge per cubic metre
(If applicable)
19.7920 ¢/m³
19.7743 ¢/m³
The rates quoted above shall be subject to the Gas Inventory Adjustment contained in Rider "C" and the
Revenue Adjustment Rider contained in Rider "E". Also, meter readings will be adjusted by the Atmospheric
Pressure Factor relevant to the customer's location as shown in Rider "F". The Gas Supply Charge
is applicable to volumes of natural gas purchased from the Company. The volumes purchased shall be
the volumes delivered at the Point of Delivery less any volumes, which the Company does not own and are
received at the Point of Acceptance for delivery to the Applicant at the Point of Delivery.
DIRECT PURCHASE ARRANGEMENTS:
Rider "A" or Rider "B" shall be applicable to Applicants who enter into Direct Purchase Arrangements under this
Rate Schedule.
CURTAILMENT CREDIT:
Rate for 4 hours of notice per cubic metre of Mean Daily Volume from December to March
EFFECTIVE DATE:
IMPLEMENTATION DATE:
BOARD ORDER:
REPLACING RATE EFFECTIVE:
January 1, 2010
January 1, 2010
EB-2009-0398
October 1, 2009
$
1.10 /m³
Page 1 of 2
Handbook 31
RATE NUMBER:
200
In addition, if the Applicant is supplying its own gas requirements, the gas delivered by the Applicant during the
period of curtailment shall be purchased by the Company for the Company's use. The purchase price
for such gas will be equal to the price that is reported for the month, in the first issue of the Natural Gas
Market Report published by Canadian Enerdata Ltd. during the month, as the "current" "Avg." (i.e., average)
"Alberta One-Month Firm Spot Price" for "AECO 'C' and Nova Inventory Transfer" in the table entitled
"Domestic spot gas prices", adjusted for AECO to Empress transportation tolls and compressor fuel costs.
For the areas specified in Appendix A to this Rate Schedule, the Company's gas distribution network does not
have sufficient physical capacity under current operating conditions to accommodate the provision of firm service
to existing interruptible locations.
UNAUTHORIZED OVERRUN GAS RATE:
When the Applicant takes Unauthorized Supply Overrun Gas, the Applicant shall purchase such gas at a rate of
150% of the average price on each day on which an overrun occurred for the calendar month as published in the
Gas Daily for the Niagara and Iroquois export points for the CDA and EDA respectively.
On the second and subsequent occasion in a contract year when the Applicant takes Unauthorized Demand Overrun Gas,
a new Contract Demand will be established and shall be charged equal to 120% of the applicable monthly charge
for twelve months of the current contract term, including retroactively based on the terms of the Service Contract.
The third instance of such failure in any contract year may result in the Applicant forfeiting the right to be served
under this Rate Schedule. In such case service hereunder would cease, notwithstanding any Service Contract
between the Company and the Applicant. Gas supply and/or transportation service would continue to be
available to the Applicant pursuant to the provisions of the Company's Rate 6 until a Service Contract pursuant to
another applicable Rate Schedule was executed.
MINIMUM BILL:
Per cubic metre of Annual Volume Deficiency
(See Terms and Conditions of Service):
6.1817 ¢/m³
TERMS AND CONDITIONS OF SERVICE:
The provisions of PARTS III and IV of the Company's HANDBOOK OF RATES AND DISTRIBUTION SERVICES
apply, as contemplated therein, to service under this Rate Schedule.
EFFECTIVE DATE:
To apply to bills rendered for gas consumed by customers on and after January 1, 2010 under Sales Service including
Buy/Sell Arrangements and Transportation Service. This rate schedule is effective January 1, 2010 and replaces the
numbered rate schedule that specifies as the effective date, October 1, 2009 and that indicates
as the Board Order, EB-2009-0309.
EFFECTIVE DATE:
IMPLEMENTATION DATE:
BOARD ORDER:
REPLACING RATE EFFECTIVE:
January 1, 2010
January 1, 2010
EB-2009-0398
October 1, 2009
Page 2 of 2
Handbook 32
RIDER:
A
TRANSPORTATION SERVICE RIDER
APPLICABILITY:
This rider is applicable to any Applicant who enters into Gas Transportation Agreement with the Company under any
rate other than Rates 125 and 300.
MONTHLY DIRECT PURCHASE ADMINISTRATION CHARGE:
Base Charge
Maximum Charge
$50.00 per month
$815.00 per month
Account Charge
New Accounts
Renewal Accounts
$0.50 per month per account
$0.15 per month per account
The above Basic Charge shall be increased up to the maximum charge, by the new account charge for each new
account and by the Renewal Account charge for each renewal account in a Direct Purchase Contract.
AVERAGE COST OF TRANSPORTATION:
The average cost of transportation effective January 1, 2010:
Firm Transportation
(FT)
Point of Acceptance
CDA, EDA
4.6868 ¢/m³
TCPL FT CAPACITY TURNBACK:
APPLICABILITY:
To Ontario T-Service customers who have been or will be assigned TCPL capacity by the Company.
TERMS AND CONDITIONS OF SERVICE:
1.
The Company will accommodate TCPL FT capacity turnback from customers to the extent that the Company is
allowed to turnback FT capacity to TCPL.
2.
The Company will accommodate all TCPL FT capacity turnback requests in a manner that minimizes stranded
and other transitional costs. The Company is committed to maintaining the integrity of its distribution system
and the sanctity of all contracts.
3.
The Company may amend any contracts to accommodate a customer's request to turnback capacity.
4.
Notice of TCPL FT turnback capacity will be accepted on Enbridge's Election for Enbridge Firm Transportation
Assignment form or other authorized written notice.
5.
The daily contractual right to receive natural gas would still be subject to the delivery, on a firm basis, of the full
Mean Daily Volume into the Company's Central Delivery Area (CDA) and/or Eastern Delivery Area (EDA). The
delivery area must match the area in which consumption will occur.
EFFECTIVE DATE:
IMPLEMENTATION DATE:
BOARD ORDER:
REPLACING RATE EFFECTIVE:
January 1, 2010
January 1, 2010
EB-2009-0398
October 1, 2009
Page 1 of 2
Handbook 51
RIDER:
A
6.
The proportion of TCPL FT capacity that an eligible customer may request to be turned back each year
("percentage turnback") shall not exceed the proportion of the TCPL capacity that Enbridge is entitled to turn
back that year. This percentage turnback will be applied to calculate the customer's turnback capacity limit
based on the renewal volume of the direct purchase agreement.
7.
If the Company is unable to accommodate all or a portion of an eligible customer's request to turnback TCPL FT
capacity in the month requested by the customer, the Company will indicate the month(s) when such customer
request can be fully satisfied and the costs, if any, associated with accommodating this request. The customer
may then advise the Company as to whether or not they wish to proceed with the TCPL FT capacity turnback
request.
8.
All TCPL FT capacity turnback requests will be treated on an equitable basis.
9.
Customers may withdraw their original election given they provide notice to the Company a minimum of one week
prior to the deadline specified in the TransCanada tariff for FT contract extension.
10. The percentage turnback of TCPL FT capacity will be applied at the Direct Purchase Agreement level.
11. Written notice to turnback capacity must be received by the Company the earlier of:
(a) Sixty days prior to the expiry date of the current contract.
or
(b) A minimum of one week prior to the deadline specified in TransCanada tariff for FT contract extension.
EFFECTIVE DATE:
To apply to bills rendered for gas delivered on and after January 1, 2010. This rate schedule is effective January 1, 2010
and replaces the identically numbered rate schedule that specifies implementation date, October 1, 2009 and that
indicates, as the Board Order, EB-2009-0309.
EFFECTIVE DATE:
IMPLEMENTATION DATE:
BOARD ORDER:
REPLACING RATE EFFECTIVE:
January 1, 2010
January 1, 2010
EB-2009-0398
October 1, 2009
Page 2 of 2
Handbook 52
RIDER:
B
BUY / SELL SERVICE RIDER
APPLICABILITY:
This rider is applicable to any Applicant who entered into a Gas Purchase Agreement with the Company, prior to
April 1, 1999, to sell to the Company a supply of natural gas.
MONTHLY DIRECT PURCHASE ADMINISTRATION CHARGE:
Base Charge
Maximum Charge
$50.00 per month
$815.00 per month
Account Charge
New Accounts
Renewal Accounts
$0.50 per month per account
$0.15 per month per account
The above Basic Charge shall be increased up to the maximum charge, by the new account charge for each new
account and by the Renewal Account charge for each renewal account in a Direct Purchase Contract.
BUY / SELL PRICE:
In Buy/Sell Arrangements between the Company and an Applicant, the Company shall buy the Applicants gas at the
Company's actual FT-WACOG price determined on a monthly basis in the manner approved by the Ontario Energy
Board. For Western Buy/Sell arrangements the FT-WACOG price shall be reduced by pipeline transmission costs.
FT FUEL PRICE:
The FT fuel price used to establish the Buy price in Western Buy/Sell arrangements without fuel will be determined
monthly based upon the actual FT-WACOG.
EFFECTIVE DATE:
To apply to bills rendered for gas delivered on and after January 1, 2010. This rate schedule is effective January 1, 2010
and replaces the identically numbered rate schedule that specifies implementation date, October 1, 2009 and that
indicates, as the Board Order, EB-2009-0309.
EFFECTIVE DATE:
IMPLEMENTATION DATE:
BOARD ORDER:
REPLACING RATE EFFECTIVE:
January 1, 2010
January 1, 2010
EB-2009-0398
October 1, 2009
Page 1 of 1
Handbook 53
RIDER:
C
GAS COST ADJUSTMENT RIDER
The following adjustment is applicable to all gas sold or delivered during the period of January 1, 2010 to March 31, 2010.
Rate Class
Sales Service
( ¢/m³ )
Western
Ontario
Transportation Service Transportation Service
( ¢/m³ )
( ¢/m³ )
Rate 1
(7.0549)
0.0000
0.0000
Rate 6
(7.0477)
0.0000
0.0000
Rate 9
(9.8943)
0.0000
0.0000
Rate 100
0.0000
0.0000
0.0000
Rate 110
(9.3690)
0.0000
0.0000
Rate 115
(9.1768)
0.0000
0.0000
Rate 135
(9.9386)
0.0000
0.0000
Rate 145
(7.9678)
0.0000
0.0000
Rate 170
(8.6531)
0.0000
0.0000
Rate 200
(7.1447)
0.0000
0.0000
EFFECTIVE DATE:
IMPLEMENTATION DATE:
BOARD ORDER:
REPLACING RATE EFFECTIVE:
January 1, 2010
January 1, 2010
EB-2009-0398
October 1, 2009
Page 1 of 1
Handbook 54
RIDER:
E
REVENUE ADJUSTMENT RIDER
The following adjustment shall be applicable to volumes during the period January 1, 2009 to December 31, 2009.
Rate Class
Sales Service
( ¢/m³ )
Transportation Service
( ¢/m³ )
Rate 1
0.0000
0.0000
Rate 6
0.0000
0.0000
Rate 9
0.0000
0.0000
Rate 100
0.0000
0.0000
Rate 110
0.0000
0.0000
Rate 115
0.0000
0.0000
Rate 135
0.0000
0.0000
Rate 145
0.0000
0.0000
Rate 170
0.0000
0.0000
Rate 200
0.0000
0.0000
Rate 300
n/a
EFFECTIVE DATE:
IMPLEMENTATION DATE:
BOARD ORDER:
REPLACING RATE EFFECTIVE:
January 1, 2010
January 1, 2010
EB-2009-0398
October 1, 2009
-
Page 1 of 1
Handbook 56
500 Consumers Road
North York, ON M2J 1P8
PO Box 650
Scarborough ON M1K 5E3
Norm Ryckman
Director, Regulatory Affairs
Tel
416-753-6280
Fax 416-495-6072
Email norm.ryckman@enbridge.com
VIA COURIER AND EMAIL
December 11, 2009
Ms. Kirsten Walli
Board Secretary
Ontario Energy Board
2300 Yonge Street
Toronto, Ontario
M4P 1E4
Dear Ms. Walli:
Re:
EB-2009-0055 (2008 Deferral and Variance Accounts)
In its Decision and Order in EB-2009-0055, the Ontario Energy Board approved
the balances in Enbridge Gas Distribution Inc.'s 2008 Deferral and Variance
Accounts, and ordered Enbridge to clear those balances in two equal instalments
during the October 2009 and November 2009 billing cycles.
By way of a letter dated September 2, 2009, Enbridge requested that the Board's
Order be varied to allow Enbridge to clear the Deferral and Variance Account
balances in 2010. As explained in this letter (a copy of which is attached),
Enbridge proposed that the clearance of the Accounts occur at the earliest
opportunity upon stabilization of the Company's new Customer Information
System (CIS). The Board received submissions regarding the request to vary
the EB-2009-0055 Order and, on September 17, 2009, it issued a further Order
(copy attached) which requires Enbridge to report, no later than the time of filing
of its January 1, 2010 QRAM application, on the advisability and proposed timing
of the clearance of the Deferral and Variance Accounts.
At this time, circumstances remain as described in the attached letter of
September 2r.d. In order to facilitate the early operations of the new CIS,
Enbridge has concluded that is it not advisable to proceed with the clearance of
the Deferral and Variance Accounts in conjunction with the January, 1, 2010
2009-12-11
Ms. Walli
Page 2
QRAM. Enbridge now anticipates that clearance will coincide with the April 1,
2010 QRAM. The balances will be cleared to customers in two equal monthly
instalments.
Yours truly,
ferf!L~L
Norm Ryckman
Director, Regulatory Affairs
cc:
Mr. Fred Cass, Aird & Berlis LLP
All Interested Parties EB-2008-0219/EB-2009-0172
500 Consumers Road
North York, ON M2J 1P8
PO Box 650
Scarborough ON M1 K 5E3
Norm Ryckman
Director, Regulatory Affairs
Tel
416-753-6280
Fax 416-495-6072
Email norm.ryckman@enbridge.com
VIA COURIER AND EMAIL
September 2, 2009
Ms. Kirsten Walli
Board Secretary
Ontario Energy Board
2300 Yonge Street
Toronto, Ontario
M4P 1E4
Dear Ms. Walli:
Re:
EB-2009-0055 (2008 Deferral and Variance Accounts) and
EB-2009-0309 (QRAM Application)
In its Decision and Order in EB-2009-0055, the Ontario Energy Board (the
"OEB", or the "Board") approved the balances in Enbridge Gas Distribution Inc.'s
2008 Deferral and Variance Accounts, and ordered Enbridge to clear those
balances in two equal installments during the October 2009 and November 2009
billing cycles. The Board ordered that this clearance will coincide with Enbridge's
October 1, 2009 QRAM. For the reasons set out below, Enbridge respectfully
requests that the Board's Order be varied to allow and direct Enbridge to clear
the balances in its 2008 Deferral and Variance Accounts in 2010.
The Company is in the process of implementing its new Customer Information
System ("CIS") in September of 2009. This is a significant undertaking that is the
culmination of approximately two years of extensive effort.
Enbridge is pleased to confirm that billing using the new CIS will commence as of
mid-September. Naturally, the Company wants to ensure that the switch-over of
its customers to the new billing system is as smooth as possible and that
adequate time and resources are dedicated to address problems should they
arise. To this end, the parties most closely involved with the implementation of
the new CIS (which include TMG Consulting, Sapient Canada and Enbridge's
own steering committee) have recommended that steps be taken to avoid the
potential complications that could arise from additional billing activities during the
first several months of operation. Those parties have specifically identified the
collection of 2008 deferral and variance account balances as an activity that
should be avoided in the early operations of the new CIS and have
2009-09-02
MS.Walii
Page 2
recommended that this be delayed. Unlike the gas cost adjustment (Le., QRAM
adjustment) which is applied to customer bills on a forward looking basis,
clearance of the 2008 deferral and variance accounts relies on historic
consumption data and therefore requires additional processes and steps in order
to facilitate collection of the amounts from customers.
The recommendation to delay clearance of the 2008 deferral and variance
accounts did not arise until an August 31 sl meeting of the parties involved in the
CIS implementation.
Since that time, Enbridge has taken prompt action to
amend its October 1 QRAM Application and formulate this request.
In these circumstances, Enbridge requests, pursuant to Part VII of the Board's
Rules of Practice and Procedure, that the Board review and vary its Decision and
Order in EB-2009-0055.
Specifically, Enbridge requests that the Board vary paragraphs 2 and 3 of its
Order in EB-2009-0055, so that they read as follows:
2) The clearance of the deferral and variance accounts will occur at the
earliest opportunity upon stabilization of the new CIS. Currently it is
anticipated that collection will coincide with the January 1, 2010
QRAM. The balances will be cleared to customers in two equal
monthly installments.
3) For purposes of clearance, Enbridge shall include in the appropriate
QRAM application, similar schedules, as indicated in Appendix "A",
reflective of the balances approved in this Decision and Order.
As there is some urgency to this request, we would be grateful if it could be
addressed at the Board's early convenience.
Should you have any questions, please contact me.
cc:
Mr. David Stevens, Aird & Berlis LLP
All Interested Parties EB-2008-0219 and EB-2009-0055
5723742.2
Ontario Energy
Board
Commission de l’énergie
de l’Ontario
EB-2009-0055
IN THE MATTER OF the Ontario Energy Board Act 1998,
S.O.1998, c.15, (Schedule B);
AND IN THE MATTER OF an Application by Enbridge Gas
Distribution Inc. for an order or orders amending or varying
the rate or rates charged to customers as of October 1,
2009.
BEFORE:
Pamela Nowina
Presiding Member and Vice Chair
Paul Sommerville
Member
SUPPLEMENTARY DECISION AND ORDER
Deferral and Variance Accounts
Enbridge Gas Distribution Inc. (“Enbridge” or the “Applicant”) filed an application, dated
March 18, 2009 (the “Application”), with the Ontario Energy Board (the “Board”) under
section 36 of the Ontario Energy Board Act, S.O. 1998, c.15, Schedule B (the “Act”) for
an order approving the disposition of balances in certain deferral or variance accounts.
The Board assigned file number EB-2009-0055 to the Application and issued a Notice
of Application dated April 1, 2009. The Board issued its Decision and Order on the
matter on August 7, 2009 (the “Order”).
On September 2, 2009, the Board received a letter from Enbridge seeking to vary the
Order to alter the timing of the clearances of the balances in the deferral and variance
accounts. In its Order, the Board had ordered the clearances to occur in October and
November of 2009 to coincide with the October 1, 2009 quarterly commodity rate
adjustment process for Enbridge (“QRAM”). In its letter, Enbridge requested that the
-2-
Ontario Energy Board
clearance dates be postponed until 2010 when it expects that its new Customer
Information System (“CIS”) will be able to facilitate the billing of the clearances.
The Board issued Procedural Order No. 3 on September 4, 2009 which outlined a
process for parties to make submissions on Enbridge’s request to vary the Order.
The Board received submissions from the Industrial Gas Users Association (“IGUA”),
Canadian Manufacturers & Exporters (“CME”) and Energy Probe Research Foundation
(“Energy Probe”). No party objected to Enbridge’s request. CME, however, suggested
that the Board order the clearances for January and February of 2010 and if the CIS
billing system is still unable to handle it, then Enbridge should apply for another vary
order.
Enbridge replied that while it continues to expect that it will be in a position to clear its
2008 Deferral and Variance Accounts in January and February 2010, it will not know
for certain whether that is advisable for some time. In keeping with this, Enbridge
proposed that as part of its January 1, 2010 QRAM Application, it will either request the
clearances of its 2008 Deferral and Variance Accounts in January and February 2010
or, if that is still not advisable, it will inform the Board of when the clearances will be
effected.
The Board finds that Enbridge’s proposal is acceptable. The Board will therefore await
notice from Enbridge in its January 2010 QRAM Application on the appropriate timing
of the clearances, including the advisability of clearing the accounts in January and
February of 2010. The Board notes that the January 1, 2010 QRAM Application filing is
expected on or around the first of December 2009.
THE BOARD THEREFORE ORDERS THAT:
1. The Board’s August 7, 2009 Order is hereby varied to remove the requirement for
the clearances of the deferral and variance accounts to coincide with the October
1, 2009 QRAM.
-3-
Ontario Energy Board
2. Enbridge shall report to the Board no later than the time of its filing for the
January 1, 2010 QRAM on the advisability and proposed timing of the clearances
of the deferral and variance accounts.
3. IGUA, CME and Energy Probe shall be eligible to submit to the Board, and
provide a copy to Enbridge, any supplemental cost claim relating to this portion of
the proceeding within 10 days of the day of this Decision and Order.
4. Enbridge shall file with the Board and forward these parties any objections to the
claimed costs within 15 calendar days from the date of this Decision and Order.
5. Intervenors whose cost claims have been objected to may file with the Board and
forward to Enbridge any responses to any objections for cost claims within 20
calendar days of the date of this Decision and Order.
6. All filings to the Board must quote file number EB-2009-0055, and consist of two
paper copies and one electronic copy in searchable / unrestricted PDF format
filed through the Board’s web portal at www.errr.oeb.gov.on.ca. Filings must
clearly state the sender’s name, postal address and telephone number and, if
available, a fax number and e-mail address. Please use the document naming
conventions and document submission standards outlined in the RESS
Document Guideline found on the “e-Filing Services” webpage of the Board’s
website at www.oeb.gov.on.ca. If the web portal is not available you may email
your document to BoardSec@oeb.gov.on.ca.
DATED at Toronto, September 17, 2009
ONTARIO ENERGY BOARD
Original signed by
Kirsten Walli
Board Secretary