ANNEXE I
Gazifère Inc.
Modifications du Tarif 200 avec commentaires
Ajustement du coût du gaz
Impact on Rate 200 from EB-2010-0347 – January 1, 2011 QRAM
Enbridge Gas Distribution (“EGD”) is proposing the following changes to Rate 200 resulting
from its EB-2010-0347 QRAM application for rates effective January 1, 2011.
EGD’s January 1, 2011 EB-2010-0347 QRAM rates reflect the effects of the forecast gas
costs for January 1, 2011 and the impacts of EGD’s Board Decision from its main rate case
(EB-2010-0146) for calendar year rates effective January 1, 2011.
EGD is forecasting a decrease in its PGVA reference price to $192.600/103m3 for January 1,
2011 EB-2010-0347 relative to $204.864/103m3 embedded in its EB-2010-0258 October 1,
2010 rates.
Gas Supply Commodity
The Rate 200 gas supply commodity charge will decrease from 15.2837 cents/ m3 from EB2010-0258 to 14.3123 cents/ m3 in EB-2010-0347 for sales service customers.
The Rate 200 gas supply commodity charge will decrease from 15.2613 cents/ m3 from EB2010-0258 to 14.2900 cents/ m3 in EB-2010-0347 for buy/sell service customers.
Gas Supply Load Balancing Charge
The Gas Supply Load Balancing charge will increase from EB-2010-0258 to EB-2010-0347
as a result of higher seasonal load balancing costs offset by lower carrying cost of gas in
inventory.
Transportation Charge
The transportation charge will decrease from EB-2010-0258 to EB-2010-0347 as a result of
lower transportation related costs.
Delivery Charge
The Rate 200 delivery charge will decrease from EB-2010-0258 to EB-2010-0347. This is
the result of the lower PGVA reference price applied to its Lost and Unaccounted for Gas
volumes offset by a slight increase in EGD’s distribution costs for 2011 for its final decision
under EB-2010-0146. The impact of EGD’s final rate case decision resulted in a rate
increase to Rate 200 delivery rate of 0.3%. The combined impact of EB-2010-0347 and EB2010-0146 on the delivery rate is a decrease of approximately 0.2%.
Original : 2010-12-13
Page 1 de 2
ANNEXE I
Gazifère Inc.
Modifications du Tarif 200 avec commentaires
Ajustement du coût du gaz
Rider C
Effective from January 1, 2011 to December 31, 2011 the Rate 200 Rider C unit rate for sales
and buy/sell customers is (2.0042) ¢/m³, for Western T-service it is 0.1398 ¢/m³ and for
Ontario T-service it is 0.0527 ¢/m³.
Adjustment for 2009 Deferral Account Clearing (EB-2010-0042)
As a result of the Board Decision in EB-2010-0042 Final Rate Order, EGD will clear its
2009 Actual PGVA and Non Gas-Supply Related Deferral Account balances as a one-time
billing adjustment on customers’ January 2011 bill. Gazifere will receive a refund of
approximately $2,215,300 on its January 2011 bill.
Original : 2010-12-13
Page 2 de 2
ANNEXE II
GAZIFÈRE INC.
CALCUL DE L'IMPACT UNITAIRE SUR LES TARIFS RÉSULTANT DE LA DIMINUTION DU TARIF 200 EB-2010-0347
AJUSTEMENT DU COÛT DU GAZ
LINE
NO.
DESCRIPTION
1
Gas Supply Cost decrease $ '000
2
Transportation Cost increase $ '000
3
Delivery Cost increase $ '000
4
Total decrease in cost of service $ '000
4.1
4.2
3
3
VOLUMES 10 m
Sales
Deliveries
5.1
5.2
5.3
UNIT RATE IMPACT cents/m 3
Gas Supply Cost
Transportation Cost
Delivery Cost
Col. 3
Col. 4
Col. 5
Col. 6
Col. 7
Col. 8
TOTAL
TARIF
1
TARIF
2
TARIF
3
TARIF
5
TARIF
9
(1,192.0)
-488.7
-699.0
-4.3
0.0
0.0
(651.0)
-266.9
-381.7
-2.4
0.0
0.0
36.7
56.5
0.0
0.8
0.5
94.6
(1,748.4)
121,692.9
160,178.9
-0.98
-0.53
0.06
49,894.1
60,466.8
-0.98
-0.53
0.06
71,358.8
71,438.7
-0.98
-0.53
0.08
440.0
440.0
-0.98
-0.53
0.01
0.0
14,159.1
0.0
13,674.3
-0.98
-0.53
0.01
-0.98
-0.53
0.00
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 Regie's Decision D-2010-147 and the current pass-on.
Line 2
Compares allocated transportation costs between the Regie's Decision D-2010-147 and the current pass-on.
Line 3
Compares allocated delivery costs between the Regie's Decision D-2010-147 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-2010-147 (see Requête 3724-2010, GI-36, document 1, page 1of 1, lines 3,4,6,8,10,12,15 and 18, column 2).
Line 4.2 Delivery volumes underpinning the Régie's Decision D-2010-147 (see Requête 3724-2010, GI-36, 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.
Original: 2010-12-13
Page 1 de 1
ANNEXE III
GAZIFÈRE INC.
COÛT DU GAZ SELON LE TARIF 200 EB-2010-0347
BASÉ SUR LES VOLUMES DE L'ANNÉE TÉMOIN 2011
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
1111.2
TOTAL DELIVERIES
TOTAL SALES
T-SERVICE RECEIPTS
24,734.5
20,570.6
4,163.8
Col. 2
FEB
1111.2
25,742.6
21,683.0
4,059.6
Col. 3
MAR
1111.2
21,964.4
17,919.1
4,045.3
Col. 4
APR
1111.2
15,972.5
12,514.1
3,458.4
Col. 5
MAY
1111.2
Col. 6
JUN
1111.2
Col. 7
JUL
1111.2
Col. 8
AUG
1111.2
Col. 9
SEP
Col. 10
OCT
1111.2
1111.2
8,985.8
5,977.9
3,008.0
6,314.2
3,699.3
2,614.9
5,840.5
3,345.7
2,494.9
5,561.9
3,267.8
2,294.0
5,597.7
3,277.2
2,320.5
8,461.4
5,427.5
3,033.9
Col. 11
NOV
1111.2
13,994.2
10,612.3
3,381.9
Col. 12
DEC
Col. 13
TOTAL
1111.2
19,338.0
15,523.1
3,815.0
162,507.8 (2)
123,817.6
38,690.2
GAS COST CALCULATION
RATES
EB-2010-0347
Demand Charge
Delivery Charge
14.7000
1.1202
163,346
277,075
440,422
163,346
288,369
451,715
163,346
246,045
409,391
163,346
178,924
342,270
163,346
100,659
264,006
163,346
70,732
234,078
163,346
65,426
228,772
163,346
62,304
225,650
163,346
62,706
226,052
163,346
94,785
258,131
163,346
156,763
320,109
163,346
216,625
379,971
1,960.2
1,820.4
3,780.6
Load Balancing
Transportation
Gas supply (buy/sell)
Gas supply (system)
CURTAILMENT
0.5881
4.5736
14 2900
14.2900
14.3123
-1.1000
145,463
940,819
58 791
58,791
2,885,250
151,392
991,693
61 970
61,970
3,041,268
129,173
819,548
51 213
51,213
2,513,342
93,934
572,346
35 765
35,765
1,755,237
52,846
273,405
17 085
17,085
838,462
37,134
169,190
10 573
10,573
518,864
34,348
153,017
9 562
9,562
469,264
32,709
149,457
9 339
9,339
458,347
32,920
149,886
9 366
9,366
459,663
49,762
248,232
15 512
15,512
761,263
82,300
485,365
30 330
30,330
1,488,488
113,727
709,963
44 365
44,365
2,177,273
955.7
5,662.9
353 9
353.9
17,366.7
TOTAL
4,470,746
4,698,039
3,922,666
2,799,552
1,445,803
969,839
894,963
875,503
877,887
1,332,900
2,406,592
3,425,299
28,119.8
Niagara Gas Transmission
RATES:
EB-2010-0347
118,483
4,589,229
118,483
4,816,522
118,483
4,041,149
118,483
2,918,035
118,483
1,564,286
118,483
1,088,322
118,483
1,013,446
118,483
993,986
118,483
996,370
118,483
1,451,383
118,483
2,525,075
118,483
3,543,782
1,421.8
29,541.6
29
30
RATES:
EB-2010-0258
4,881,256
5,124,566
4,295,248
3,095,056
1,647,918
1,139,560
1,059,697
1,039,260
1,041,760
1,527,108
2,674,886
3,763,691
31,290.0
31
32
Écart entre EB-2010-0347 et EB-2010-0258
(1,748.4)
Notes: (1) Coût du gaz total selon le tarif 200 en vigueur le 1er janvier 2011.
(2) Correspond aux volumes d'achat à 37,69 MJ/m³ tel qu'approuvés par la Régie dans sa décision D-2010-147 ( Voir R-3724-2010, GI-40, document 2.1, page 1 de 1, ligne 6, révisé le 8 décembre 2010).
Original: 2010-12-13
Page 1 de 1
ANNEXE IV
GAZIFÈRE INC.
COÛT DU GAZ SELON LE TARIF 200 EB-2010-0258 (1)
BASÉ SUR LES VOLUMES DE L'ANNÉE TÉMOIN 2011
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
1111.2
TOTAL DELIVERIES
TOTAL SALES
T-SERVICE RECEIPTS
24,734.5
20,570.6
4,163.8
Col. 2
FEB
1111.2
25,742.6
21,683.0
4,059.6
Col. 3
MAR
1111.2
21,964.4
17,919.1
4,045.3
Col. 4
APR
1111.2
15,972.5
12,514.1
3,458.4
Col. 5
MAY
1111.2
Col. 6
JUN
1111.2
Col. 7
JUL
1111.2
Col. 8
AUG
1111.2
Col. 9
SEP
Col. 10
OCT
1111.2
1111.2
8,985.8
5,977.9
3,008.0
6,314.2
3,699.3
2,614.9
5,840.5
3,345.7
2,494.9
5,561.9
3,267.8
2,294.0
5,597.7
3,277.2
2,320.5
8,461.4
5,427.5
3,033.9
Col. 11
NOV
1111.2
13,994.2
10,612.3
3,381.9
Col. 12
DEC
Col. 13
TOTAL
1111.2
19,338.0
15,523.1
3,815.0
162,507.8 (2)
123,817.6
38,690.2
GAS COST CALCULATION
RATES
EB-2010-0258
Demand Charge
Delivery Charge
14.7000
1.1218
163,346
277,471
440,818
163,346
288,781
452,127
163,346
246,396
409,743
163,346
179,179
342,526
163,346
100,803
264,150
163,346
70,833
234,179
163,346
65,519
228,866
163,346
62,393
225,739
163,346
62,795
226,142
163,346
94,920
258,267
163,346
156,987
320,333
163,346
216,934
380,280
1,960.2
1,823.0
3,783.2
Load Balancing
Transportation
Gas supply (buy/sell)
Gas supply (system)
CURTAILMENT
0.5180
5.1042
15 2613
15.2613
15.2837
-1.1000
128,125
1,049,967
62 787
62,787
3,081,077
133,347
1,106,743
66 182
66,182
3,247,684
113,775
914,626
54 694
54,694
2,683,927
82,737
638,746
38 196
38,196
1,874,368
46,547
305,123
18 246
18,246
895,370
32,708
188,819
11 291
11,291
554,080
30,254
170,769
10 212
10,212
501,113
28,810
166,797
9 974
9,974
489,456
28,996
167,275
10 003
10,003
490,861
43,830
277,030
16 566
16,566
812,932
72,490
541,673
32 392
32,392
1,589,514
100,171
792,328
47 380
47,380
2,325,048
841.8
6,319.9
377 9
377.9
18,545.4
TOTAL
4,762,773
5,006,083
4,176,765
2,976,573
1,529,435
1,021,077
941,214
920,777
923,277
1,408,625
2,556,403
3,645,208
29,868.2
EB-2010-0258
118,483
4,881,256
118,483
5,124,566
118,483
4,295,248
118,483
3,095,056
118,483
1,647,918
118,483
1,139,560
118,483
1,059,697
118,483
1,039,260
118,483
1,041,760
118,483
1,527,108
118,483
2,674,886
118,483
3,763,691
1,421.8
31,290.0
Niagara Gas Transmission
RATES:
Notes: (1) Coût du gaz total selon le tarif 200 en vigueur le 1er octobre 2010.
(2) Correspond aux volumes d'achat à 37,69 MJ/m³ tel qu'approuvés par la Régie dans sa décision D-2010-147 ( Voir R-3724-2010, GI-40, document 2.1, page 1 de 1, ligne 6, révisé le 8 décembre 2010).
Original: 2010-12-13
Page 1 de 1
ANNEXE V
GAZIFÈRE INC.
AJUSTEMENT SUBSÉQUENT AUX TARIFS EN VIGUEUR RÉSULTANT DE LA DÉCISION D-2010-147
AJUSTEMENT DU COÛT DU GAZ
ITEM
NO.
DESCRIPTION
January 1st 2011
Rates with
October 1st, 2010, rate 200
Proposed
Proposed Rates
January 1st, 2011
D-2010-147
Adjustment
Pass On
col.1
col.2
col.3
Rate 1:
1
Monthly Fixed Charge ($)
17.13
0.00
17.13
2
3
4
5
6
7
Delivery Charge (¢/m³):
from 0 to 100 m³
from 100 to 320 m³
from 320 to 1,000 m³
from 1,000 to 3,200 m³
from 3,200 to 10,000 m³
in excess of 10,000 m³
19.32
18.27
17.24
16.17
14.12
12.55
0.06
0.06
0.06
0.06
0.06
0.06
19.38
18.33
17.30
16.23
14.18
12.61
8
Transportation Charge
5.15
-0.53
4.62
9
Gas Supply Charge
15.48
-0.98
14.50
10.05
0.00
10.05
Rate 2:
10
Monthly Fixed Charge ($)
11
12
13
14
15
Delivery Charge (¢/m³):
from 0 to 50 m³
from 50 to 100 m³
from 100 to 320 m³
from 320 to 1,000 m³
in excess of 1,000 m³
20.42
19.86
19.29
18.74
18.17
0.08
0.08
0.08
0.08
0.08
20.50
19.94
19.37
18.82
18.25
16
Transportation Charge
5.15
-0.53
4.62
17
Gas Supply Charge
15.48
-0.98
14.50
20.68
0.00
20.68
Rate 3:
18
Monthly Fixed Charge:
(¢/m³ of the subscribed volume)
Delivery Charge (¢/m³):
For all volumes delivered
8.38
0.01
8.39
19
20
Transportation Charge
5.15
-0.53
4.62
21
Gas Supply Charge
15.48
-0.98
14.50
20.94
0.00
20.94
6.61
5.61
0.01
0.01
6.62
5.62
Rate 4:
22
23
24
Monthly Fixed Charge:
(¢/m³ of the subscribed volume)
Delivery Charge (¢/m³):
Load factor less or equal to 70%
Load factor higher than 70%
25
Transportation Charge
5.15
-0.53
4.62
26
Gas Supply Charge
15.48
-0.98
14.50
Original: 2010-12-13
Page 1 de 2
ANNEXE V
GAZIFÈRE INC.
AJUSTEMENT SUBSÉQUENT AUX TARIFS EN VIGUEUR RÉSULTANT DE LA DÉCISION D-2010-147
AJUSTEMENT DU COÛT DU GAZ
ITEM
NO.
DESCRIPTION
January 1st 2011
Rates with
October 1st, 2010, rate 200
Proposed
Proposed Rates
January 1st, 2011
D-2010-147
Adjustment
Pass On
col.1
col.2
col.3
31.76
0.00
31.76
Rate 5:
27
Monthly Fixed Charge:
(¢/m³ of the subscribed volume)
28
Delivery Charge (¢/m³):
For all volumes delivered
3.15
0.01
3.16
29
Transportation Charge
5.15
-0.53
4.62
30
Gas Supply Charge
15.48
-0.98
14.50
20.94
0.00
20.94
3.34
0.42
0.00
0.00
3.34
0.42
Rate 6:
31
32
33
Monthly Fixed Charge:
(¢/m³ of the subscribed volume)
Delivery Charge (¢/m³):
Maximum
Minimum
34
Transportation Charge
5.15
-0.53
4.62
35
Gas Supply Charge
15.48
-0.98
14.50
Rate 7:
21 42
21.42
0 00
0.00
21 42
21.42
36
37
38
39
40
41
Monthly Fixed Charge
Delivery Charge (¢/m³):
from 0 to 100 m³
from 100 to 320 m³
from 320 to 1,000 m³
from 1,000 to 3,200 m³
from 3,200 to 10,000 m³
in excess of 10,000 m³
20.38
19.32
18.28
17.25
15.17
13.60
0.06
0.06
0.06
0.06
0.06
0.06
20.44
19.38
18.34
17.31
15.23
13.66
42
Transportation Charge
5.15
-0.53
4.62
43
Gas Supply Charge
15.48
-0.98
14.50
8.90
1.61
0.00
0.00
8.90
1.61
Tarif 8:
44
45
Delivery Charge (¢/m³):
Maximum
Minimum
46
Transportation Charge
5.15
-0.53
4.62
47
Gas Supply Charge
15.48
-0.98
14.50
3.15
0.00
3.15
2.19
2.02
0.00
0.00
2.19
2.02
Tarif 9:
48
49
50
Monthly Fixed Charge:
(¢/m³ times the maximum daily volume)
Delivery Charge (¢/m³):
from 0 to 1,000,000 m³
in excess of 1,000,000 m³
51
Transportation Charge
5.15
-0.53
4.62
52
Gas Supply Charge
15.48
-0.98
14.50
Original: 2010-12-13
Page 2 de 2
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)
3
¢/m
Proposed
rate
of other
components
3
¢/m
2
3=1+2
13.01
(6.19)
6.82
load factor less
or equal to 70%
11.24
(6.49)
4.75
load factor higher than 70%
10.24
(6.49)
3.75
6
Rate 5
7.78
(6.11)
1.67
7
Rate 9
6.64
(5.66)
0.98
8
Maximum charge on a prorated basis of any annual
minimum bill incurred by Gazifère
9
Rate 3
13.01
s/o
13.01
10
Rate 4
11
load factor less
or equal to 70%
11.24
s/o
11.24
12
load factor higher than 70%
10.24
s/o
10.24
13
Rate 5
7.78
s/o
7.78
14
Rate 9
6.64
s/o
6.64
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: 2010-12-13
Page 1 de 1
ANNEXE VII
Gazifère Inc.
Taux unitaire et revenus par composante et par tarif
Ajustement du coût du gaz
January 1st, 2011 with October 2010 rate 200
D-2010-147
Line No.
Unit rate
cents/m3
Col. 1
Total
$ '000
Col. 2
January 1st, 2011 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 (2)
Transportation
Distribution
Total
15.48
4.11
5.15
11.28
36.02
7,724
2,488
2,567
6,823
19,602
14.50
4.17
4.62
11.28
34.57
15.48
4.81
5.15
20.34
45.78
11,047
3,436
3,672
14,532
32,687
14.50
4.89
4.62
20.34
44.35
15.48
68
1.68
5.15
7.72
30.03
7
23
34
132
7,235
2,525
2,300
6,823
18,883
(489)
37
(267)
(719)
-6%
1%
-10%
0%
-4%
10,347
3,493
3,290
14,532
31,662
(699)
57
(382)
(1,024)
-6%
2%
-10%
0%
-3%
14.50
64
(4)
-6%
1.69
4.62
7.72
28.53
7
20
34
126
0
(2)
1%
-10%
0%
-5%
Rate 2
2.1
2.2
2.3
2.4
2.0
Gas Supply Commodity
(2)
Gas Supply Load Balancing
Transportation
Distribution
Total
Rate 3
3.1 Gas Supply Commodity
3.2
3.3
3.4
3.0
Gas Supply Load Balancing (2)
Transportation
Distribution
Total
(7)
Rate 5
4.1
4.2
4.3
4.4
4.0
Gas Supply Commodity
Gas Supply Load Balancing (2)
Tranportation
Distribution
Total
15.48
1.18
5.15
3.32
25.12
167
469
636
14.50
1.18
4.62
3.32
23.62
168
469
637
15.48
0.67
5.15
2.31
23.61
-
14.50
0.67
4.62
2.31
22.10
317
408
14.50
3.92
4.62
13.84
36.89
17,647
6,284
5,611
22,175
51,717
1
1
-6%
1%
-10%
0%
-6%
Rate 9
5.1
5.2
5.3
5.4
5.0
Gas Supply Commodity
Gas Supply Load Balancing (2)
Transportation
Distribution
Total
92
317
408
92
-
-6%
0%
-10%
0%
-6%
(1,193)
95
(651)
(1,748)
-6%
2%
-10%
0%
-4%
Gazifère Total
6.1
6.2
6.3
6.4
6.0
Gas Supply Commodity
Gas Supply Load Balancing (2)
Transportation
Distribution
Total
15.48
3.86
5.15
13.84
38.33
18,839
6,190
6,262
22,175
53,465
Notes:
(1) The % variance depicts the change in the unit rates.
(2) Load Balancing Unit Rate = Load Balancing Rate from Column 1 + Unitized Change in Delivery Costs from Annexe II, line 5.3.
Original: 2010-12-13
Page 1 de 3
ANNEXE VIII
('000 Dollars)
Gazifère Inc.
Revenus totaux par composantes
Tarif du 1er janvier 2011 versus tarif du 1er octobre 2010
Ajustement du coût du gaz
35000
30000
25000
20000
15000
10000
5000
0
October 10
January 11
Gas Supply Commodity, Load Balancing &
Transportation
Distribution
Original: 2010-12-13
Page 2 de 3
ANNEXE IX
Gas Supply Commodity
Gazifère Inc.
Taux unitaire par composante
Tarif du 1er janvier 2011 versus tarif du 1er octobre 2010
Ajustement du coût du gaz
55
50
Gas Supply Load Balancing
Transportation
Distribution
45
Unit Rate cents/m3
40
35
30
25
20
15
10
5
0
Oct110
2
Jan Passon
Rate 1
Original: 2010-12-13
Oct 3
10
Jan Passon
4
Rate 2
Oct
5 10
Jan Passon
6
Rate 3
Oct710
Jan Passon
8
Rate 4
Oct 10
9
Jan Passon
10
Rate 5
Oct 10
11
Jan Passon
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 2011 au 31 décembre 2011.
Tarifs
Service de vente et
service achat / revente
(¢/m3)
Service de
transport
(¢/m3)
1à9
(2,16)
0,00
Note: (1) Voir "Rider C - Gas Cost Adjustment Rider " à la page 56 du "Rate Handbook", composante "Commodity"
de Enbridge Gas Distribution, requête EB-2010-0347.
Le montant de (2,1440) ¢/m³ a été ajusté pour la valeur calorifique.
Original: 2010-12-13
Page 1 de 1
ANNEXE XI
GAZIFÈRE INC.
AJUSTEMENT DU COÛT DU GAZ - JANVIER 2011
LIQUIDATION DU COMPTE AJUSTEMENT DU COÛT DU GAZ ET COMPTES DIFFÉRÉS D'EGD
CALCUL DE LA RÉCUPÉRATION NETTE (DU REMBOURSEMENT NET) PAR TYPE DE CLIENT
PÉRIODE DE RÉFÉRENCE: 2009
No de
ligne Description
1
Solde du compte ajustement du coût du gaz au 31 décembre 2009 ($)
2
Service de vente
et service
achat / revente
Service
de
transport
1
2
Total
3 = 1+2
($782,871)
$48,840
($734,031) (1)
Liquidation des comptes différés d'EGD ($)
($2,226,000)
$10,700
($2,215,300) (2)
3
Remboursement net total par type de client ($)
($3,008,871)
$59,540
($2,949,331)
4
Volumes de ventes du 1er janvier au 31 décembre 2009 (m³)
122,173,506
5
Taux unitaire par type de client
-2.46 ¢/m³
52,924,005
0.11 ¢/m³
Notes: (1) Voir Requête 3724-2010, Phase III (Fermeture des livres 2009), Décision D-2010-112, page 19.
(2) Voir Requête d'EGD, EB-2010-0042, Appendix B, page 3 of 6, line item 1.11, column 1, tel que retrouvé à l'annexe XII.
Original: 2010-12-13
Page 1 de 1
175,097,511
ANNEXE XII
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-2010-0042 (2009 Deferral and variance Accounts)
Original: 2010-12-13
34 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 10, 2010
Ms. Kirsten Walli
Board Secretary
Ontario Energy Board
2300 Yonge Street, 27 th Floor
Toronto, Ontario
M4P 1E4
Dear Ms. Walli:
Re:
EB-2010-0347 (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 two 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, 2011.
The Board approved the original Quarterly Rate Adjustment Mechanism
CQRAM") 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.
This QRAM application also includes the rate impacts approved in the Board's
decision and rate order in EB-2010-0146 Final 2011 Rates dated December 8,
2010. Additionally, as was ordered by the Board in the EB-2010-0042 Final Rate
Order dated December 7, 2010, the Company will clear the 2009 deferral and
variance account balances as a one-time adjustment on customers' January
2011 bills. A copy of the approved unit rates has been included under
Exhibit Q1-1 , Tab 3, Schedule 1.
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.
December 10,2010
Ms. Walli
Page 2
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 15, 2010.
•
Any reply comments from Enbridge must be filed with the Board, and
served on all interested parties, on or before December 17, 2010.
•
The Board would thereafter issue an order approving the applied-for rate
adjustments, or modifying them as required, effective January 1, 2011.
Enbridge requests the Board to issue such an order on or before December 22,
2010 (if possible). Enbridge would then be able to implement the resultant rates
during Enbridge's first billing cycle in January 2011.
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,
(L
1OR..Norm Ryckman
Director, Regulatory Affairs
Encl.
cc:
Mr. Fred Cass, Aird & Berlis LLP
All Interested Parties EB-201 0-0146
Filed: 2010-12-10
EB-2010-0347
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, 2011.
APPLICATION FOR
RATE ADJUSTMENT
Gas Costs
First Quarter· Test Year 2011
Introduction
1. Enbridge Gas Distribution Inc. ("Enbridge") hereby applies to the Board for
an order approving or fixing rates for the sale, distribution, storage, and
transmission of gas effective January 1, 2011. 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,
paragraph 687.
Filed: 2010-12-10
EB-2010-0347
Exhibit Q1-1
Tab 2
Schedule 1
Page 2 of 5
•
RP-2003-0203: The QRAM
Issue 15.11 in the Settlement
Exhibit N1, Tab 1, Schedule
approved the entire Settlement
transcript volume 1, paragraphs.
process was modified, under
Proposal dated June 17, 2004,
1, pp. 56-58 of 59. The Board
Proposal on June 16, 2003; see
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 approved in EB-2010-0146 Final 2011 Rates is
$204.190/10 3 m3 ($5.418/GJ @ 37.69 MJ/m 3 ). This represents the October 1,
2010 QRAM prices applied to the 2011 gas supply portfolio. Enbridge has
recalculated the utility price for the first quarter of Test Year 2011 using the
prescribed methodology. The recalculated utility price is $192.600/10 3m3
($5.110/GJ @ 37.69 MJ/m 3) reflecting lower gas costs.
5. Enbridge proposes to also implement the rate impacts as approved in the
Board's decision and rate order in EB-2010-0146 Final 2011 Rates dated
December 8, 2010 and as is described in evidence.
6. The resultant rates would decrease the total bill for a typical residential
customer on system gas by $42 or 3.9% (approx.) annually and, for a typical
residential customer on direct purchase (i.e., total bill excluding commodity
charges), would decrease the total bill by $12 or 1.9% (approx.) annually.
PGVA
7. The new PGVA rider methodology adopted by the Company in its January 1,
2010 QRAM filing allows it to make adjustments through rate riders for
variances in cOrTlmodity, transportation and load balancing costs for all
bundled customers.
8. Effective from January 1, 2011 to December 31, 2011 the Rider C unit rate
for a residential customer on sales service is (2.0181) ¢/m 3 , on Western
T-service it is 0.1553 ¢/m 3 and on Ontario T-service it is 0.0682 ¢/m 3 .
Filed: 2010-12-10
EB-2010-0347
Exhibit Q1-1
Tab 2
Schedule 1
Page 3 of 5
Other
9. Enbridge is implementing the clearing of its 2009 deferral and variance
account balances as a one-time adjustment on customers' January 2011 bills
as was ordered by the Board in EB-2010-0042 Final Rate Order dated
December 7,2010.
Regulatory Framework
10. 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).
11. The following is the prescribed regulatory framework for processing the
Application:
•
Any responsive comments from interested parties are filed with the
Board, and served to Enbridge and the other interested parties, on
or before December 15, 2010.
•
Any reply comments from Enbridge are filed with the Board, and
served on all interested parties, on or before December 17, 2010.
•
The Board thereafter issues an order approving the applicable rate
adjustments or modifying them as required, effective January 1,
2011.
12. Enbridge requests that the Board issue such an order on or before
December 22,2010 (if possible). Enbridge would then be able to implement
the resultant rates during the first billing cycle in January 2011.
13. 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.
Filed: 2010-12-10
EB-201 0-0347
Exhibit Q1-1
Tab 2
Schedule 1
Page 4 of 5
•
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.
14. 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:
(416) 495-5499
(416) 495-6072
Electronic access:
egdregulatoryproceedigns@enbridge.com
(2) Ms. Tania Persad
Senior Legal Counsel,
Regulatory .
Telephone:
Fax:
(416) 495-5891
(416) 495-5994
Electronic access:
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
M1K5E3
Filed: 2010-12-10
EB-20 10-0347
Exhibit 01-1
Tab 2
Schedule 1
Page 5 of 5
DATE: December 10, 2010
ENBRIDGE GAS DISTRIBUTION INC.
Per:
Norm Ryckman
Director, Regulatory Affairs
_~~~---l.......3..:.~~"':""'-::"""--=-------=::::
_
Filed: 2010-12-10
EB-2010-0347
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: 2010-12-10
EB-2010-0347
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: 2010-12-10
EB-2010-0347
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: 2010-12-10
EB-2010-0347
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: 2010-12-10
EB-2010-0347
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: 2010-12-10
EB-2010-0347
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
1.1202 ¢/m³
Gas Supply Load Balancing Charge
0.5881 ¢/m³
Transportation Charge per cubic metre
4.5736 ¢/m
¢/m³
System Sales Gas Supply Charge per cubic metre
(If applicable)
Buy/Sell Sales Gas Supply Charge per cubic metre
(If applicable)
14.3123 ¢/m³
14.2900 ¢/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, 2011
January 1, 2011
EB-2010-0347
January 1, 2011
$
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 highest 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 orfeiting 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):
6.2414 ¢/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, 2011 under Sales Service including
Buy/Sell Arrangements and Transportation Service. This rate schedule is effective January 1, 2011 and replaces the
identically numbered rate schedule that specifies implementation date, January 1, 2011 and that indicates
as the Board Order, EB-2010-0146, effective January 1, 2011.
EFFECTIVE DATE:
IMPLEMENTATION DATE:
BOARD ORDER:
REPLACING RATE EFFECTIVE:
January 1, 2011
January 1, 2011
EB-2010-0347
January 1, 2011
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:
Fixed Charge
$75.00 per month
Account Charge
$0.21 per month per account
AVERAGE COST OF TRANSPORTATION:
The average cost of transportation effective January 1, 2011:
Point of Acceptance
Firm Transportation
(FT)
CDA, EDA
4.5736 ¢/m³
TCPL FT CAPACITY TURNBACK:
APPLICABILITY:
To Ontario T-Service and Western 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 requests from customers, but
only if it can do so in accordance with the following considerations:
i.
The FT capacity to be turned back must be replaced with alternative, contracted firm transportation
(primary capacity or assignment) of equivalent quality to the TCPL FT capacity;
ii.
The amount of turnback capacity that Enbridge otherwise may accommodate may be reduced to address
the impact of stranded costs, other transitional costs or incremental gas costs resulting from the loss of
STS capacity arising from any turnback request; and
iii.
Enbridge must act in a manner that maintains the integrity and reliability of the gas distribution system
and that respects the sanctity of contracts.
2.
Requests for TCPL FT turnback must be made in writing to the attention of Enbridge's Direct Purchase group.
3.
All TCPL FT capacity turnback requests will be treated on an equitable basis.
4.
The percentage turnback of TCPL FT capacity will be applied at the Direct Purchase Agreement level.
EFFECTIVE DATE:
IMPLEMENTATION DATE:
BOARD ORDER:
REPLACING RATE EFFECTIVE:
January 1, 2011
January 1, 2011
EB-2010-0347
January 1, 2011
Page 1 of 2
Handbook 51
RIDER:
5.
A
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, 2011. This rate schedule is effective
January 1, 2011 and replaces the identically numbered rate schedule that specifies implementation date,
January 1, 2011 and that indicates as the Board Order, EB-2010-0146 effective January 1, 2011.
EFFECTIVE DATE:
IMPLEMENTATION DATE:
BOARD ORDER:
REPLACING RATE EFFECTIVE:
January 1, 2011
January 1, 2011
EB-2010-0347
January 1, 2011
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:
Fixed Charge
$75.00 per month
Account Charge
$0.21 per month per account
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, 2011. This rate schedule is effective
January 1, 2011 and replaces the identically numbered rate schedule that specifies implementation date,
January 1, 2011 and that indicates as the Board Order, EB-2010-0146 effective January 1, 2011.
EFFECTIVE DATE:
IMPLEMENTATION DATE:
BOARD ORDER:
REPLACING RATE EFFECTIVE:
January 1, 2011
January 1, 2011
EB-2010-0347
January 1, 2011
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, 2011 to December 31, 2011.
Sales Service
( ¢/m³ )
Western
Transportation Service
( ¢/m³ )
Ontario
Transportation Service
( ¢/m³ )
Rate 1
(2.0181)
0.1553
0.0682
Rate 6
(2.0128)
0.1521
0.0650
Rate 9
(3.2049)
0.0876
0.0005
Rate 100
(2.0128)
0.1521
0.0650
Rate 110
(3.1435)
0.1003
0.0132
Rate 115
(3.2028)
0.0915
0.0044
Rate 135
(3.4011)
0.0871
0.0000
Rate 145
(2.4007)
0.1206
0.0335
Rate 170
(2.9226)
0.1061
0.0190
Rate 200
(2.0042)
0.1398
0.0527
Rate Class
EFFECTIVE DATE:
IMPLEMENTATION DATE:
BOARD ORDER:
REPLACING RATE EFFECTIVE:
January 1, 2011
January 1, 2011
EB-2010-0347
January 1, 2011
Page 1 of 3
Handbook 54
RIDER:
C
Sales
Service
( ¢/m³ )
Rate Class
Rate 1
Rate 6
Rate 9
Rate 100
Rate 110
Rate 115
Rate 135
Western
Transportation
Service
( ¢/m³ )
Ontario
Transportation
Service
( ¢/m³ )
Commodity
(2.1734)
Transportation
0.0871
0.0871
Load Balancing
0.0682
0.0682
0.0682
Total
(2.0181)
0.1553
0.0682
Commodity
(2.1649)
Transportation
0.0871
0.0871
Load Balancing
0.0650
0.0650
0.0650
Total
(2.0128)
0.1521
0.0650
Commodity
(3.2925)
Transportation
0.0871
0.0871
Load Balancing
0.0005
0.0005
0.0005
Total
(3.2049)
0.0876
0.0005
Commodity
(2.1649)
Transportation
0.0871
0.0871
Load Balancing
0.0650
0.0650
0.0650
Total
(2.0128)
0.1521
0.0650
Commodity
(3.2438)
Transportation
0.0871
0.0871
Load Balancing
0.0132
0.0132
0.0132
Total
(3.1435)
0.1003
0.0132
Commodity
(3.2943)
Transportation
0.0871
0.0871
Load Balancing
0.0044
0.0044
0.0044
Total
(3.2028)
0.0915
0.0044
Commodity
(3.4882)
Transportation
0.0871
0.0871
Load Balancing
0.0000
0.0000
0.0000
Total
(3.4011)
0.0871
0.0000
EFFECTIVE DATE:
IMPLEMENTATION DATE:
BOARD ORDER:
REPLACING RATE EFFECTIVE:
January 1, 2011
January 1, 2011
EB-2010-0347
January 1, 2011
Page 2 of 3
Handbook 55
RIDER:
C
Sales
Service
( ¢/m³ )
Rate Class
Rate 145
Rate 170
Rate 200
Western
Transportation
Service
( ¢/m³ )
Ontario
Transportation
Service
( ¢/m³ )
Commodity
(2.5213)
Transportation
0.0871
0.0871
Load Balancing
0.0335
0.0335
0.0335
Total
(2.4007)
0.1206
0.0335
Commodity
(3.0287)
Transportation
0.0871
0.0871
Load Balancing
0.0190
0.0190
0.0190
Total
(2.9226)
0.1061
0.0190
Commodity
(2.1440)
Transportation
0.0871
0.0871
Load Balancing
0.0527
0.0527
0.0527
Total
(2.0042)
0.1398
0.0527
EFFECTIVE DATE:
IMPLEMENTATION DATE:
BOARD ORDER:
REPLACING RATE EFFECTIVE:
January 1, 2011
January 1, 2011
EB-2010-0347
January 1, 2011
Page 3 of 3
Handbook 56
RIDER:
E
REVENUE ADJUSTMENT RIDER
Bundled Services
Rate Class
Sales
Service
( ¢/m³ )
Western
Transportation
Service
( ¢/m³ )
Ontario
Transportation
Service
( ¢/m³ )
Rate 1
0.0000
0.0000
0.0000
Rate 6
0.0000
0.0000
0.0000
Rate 9
0.0000
0.0000
0.0000
Rate 100
0.0000
0.0000
0.0000
Rate 110
0.0000
0.0000
0.0000
Rate 115
0.0000
0.0000
0.0000
Rate 135
0.0000
0.0000
0.0000
Rate 145
0.0000
0.0000
0.0000
Rate 170
0.0000
0.0000
0.0000
Rate 200
0.0000
0.0000
0.0000
Distribution
Service
( ¢/
¢/m³³ )
Unbundled Services
Rate Class
Rate 125
0.0000
Rate 300
0.0000
EFFECTIVE DATE:
IMPLEMENTATION DATE:
BOARD ORDER:
REPLACING RATE EFFECTIVE:
January 1, 2011
January 1, 2011
EB-2010-0347
January 1, 2011
Page 1 of 1
Handbook 58
Ontario Energy
Board
Commission de l’énergie
de l’Ontario
EB-2010-0042
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 approving the
clearance or disposition of amounts recorded in certain
deferral or variance accounts.
BEFORE:
Paul Sommerville
Presiding Member
Paula Conboy
Member
FINAL RATE ORDER
2009 Earnings Sharing Mechanism and other Deferral Accounts
Enbridge Gas Distribution Inc. (“Enbridge” or the “Company”) filed an application, dated
April 16, 2010, with the Ontario Energy Board (the “Board”) under section 36 of the
Ontario Energy Board Act, S.O. 1998, c.15, Schedule B for an order approving the
disposition of balances in certain deferral or variance accounts. The Board assigned file
number EB-2010-0042 to the Application and issued a Notice of Application &
Procedural Order No. 1 on May 6, 2010.
The Board scheduled a Settlement Conference on June 21 and 22, 2010 and Enbridge
filed the Settlement Agreement on June 29, 2010. The Board accepted the Settlement
Agreement in its Decision and Procedural Order No. 2 dated July 8, 2010. On
November 26, 2010, and in accordance with section 20 of the Settlement Agreement,
Enbridge filed a Draft Rate Order with schedules showing the balances, unit rates by
Ontario Energy Board
-2rate class, and clearance timing for the clearance of the subject deferral and variance
accounts. The clearances were agreed in the Settlement Agreement to be implemented
as a one-time clearance to customers in the January 2011 billing cycle. All parties to the
proceeding were provided a copy of the Draft Rate Order. On November 29, 2010 the
Board issued Procedural Order No. 3 which outlined a process for parties to comment
on the Draft Rate Order. The materials filed by Enbridge included the following:

A schedule showing the balances and associated interest for all the accounts
approved for clearance (reference: Exhibit B, Tab 5, Schedule 1, originally filed in
the Company's 2011 rate proceeding EB-2010-0146, dated October 1, 2010);

Schedules showing the derivation of the proposed unit rates for the clearance of
the account balances to customers as a one-time billing adjustment on
customers’ January 2011 bills; and

Correspondence from the Canada Revenue Agency dated November 25, 2010 in
response to the Company's request for a GST/HST ruling relating to the account
clearances.
None of the parties provided any comments to the Board on the Draft Rate Order.
The rates in the Draft Rate Order are designed for clearance in January 2011. The
Board notes that there will be a natural gas commodity rate adjustment effective
January 1, 2011 under the Quarterly Rate Adjustment Mechanism (“QRAM”) process
and that the Settlement Agreement stated an intention that the clearances would be
included with that application. The QRAM draft order is expected to be filed on or about
December 10, 2010 under docket EB-2010-0347.
Having reviewed all of the materials, the Board considers it appropriate to proceed with
its Final Rate Order as proposed by Enbridge.
THE BOARD ORDERS THAT:
1. The deferral and variance account balance schedule relating to the January 2011
clearances, including the associated interest amounts, and as attached as
Appendix “A” to this order, is accepted as the basis for the rates in this order.
Ontario Energy Board
-32. The unit rates derived for the one-time clearance, attached as Appendix “B” to
this order, shall be implemented and made effective in the January 2011 billing
cycle.
DATED at Toronto, December 7, 2010
ONTARIO ENERGY BOARD
Original signed by
Kirsten Walli
Board Secretary
APPENDIX “A” TO
FINAL RATE ORDER
BOARD FILE NO. EB-2010-0042
DATED December 7, 2010
APPENDIX “B” TO
FINAL RATE ORDER
BOARD FILE NO. EB-2010-0042
DATED December 7, 2010
ANNEXE XIII
GAZIFÈRE INC.
Calcul du taux en ¢/m3 associé à la redevance au Fonds vert
Facturation à compter du 1er janvier 2011
Redevance annuelle au Fonds vert ($)
Liquidation du compte différé au 31 décembre 2009
1,400,757.77 (1)
-218,166.91 (2)
Redevance nette à récupérer
1,182,590.86
Volumes de ventes annuels prévus pour l'année témoin 2011 (m3)
160,178,900 (3)
Taux qui sera facturé aux clients pendant la période du 1er janvier au 31 décembre 2011
Notes:
Original: 2010-12-13
3
0.74 ¢/m
(1) Correspond à la redevance annuelle au Fonds vert de Gazifère pour la période du 1er octobre 2010
au 30 septembre 2011.
(2) Correspond au montant de (53 501$) retrouvé à la pièce GI-13, document 1.5, page 1 de 1, ligne 6,
colonne 12 de la requête 3724-2010 auquel Gazifère a déduit la facture au montant de 331 589$
qui a été payé en décembre 2009 et a exclu la liquidation de 2010 du compte différé au 31 décembre 2008
au montant de (166 923$). Ces deux derniers montants, faisant partie du solde de (53 501$), ont été
inclus dans le calcul du taux unitaire facturé durant l'année 2010.
(3) Voir requête 3724-2010, GI-36, document 1, page 1 de 1, ligne 23, colonne 2.
Page 1 de 2
ANNEXE XIII
GAZIFÈRE INC.
ANNEXE REDEVANCE AU FONDS VERT
REDEVANCE AU FONDS VERT
Une charge de 0,74 ¢/m³ visant à récupérer les sommes versées à titre de redevance au Fonds vert exigée par le
gouvernement du Québec s'applique à tous les volumes de gaz livrés et vendus durant la période du 1er janvier au
31 décembre 2011.
Original: 2010-12-13
Page 2 de 2