ANNEXE I
Gazifère Inc.
Modifications du Tarif 200 avec commentaires
Ajustement du coût du gaz
Impact on Rate 200 from EB-2014-0039 – April 1, 2014 QRAM
Enbridge Gas Distribution (“EGD”) is proposing the following changes to Rate 200 resulting
from its EB-2014-0039 QRAM application for rates effective April 1, 2014.
EGD is forecasting an increase in its PGVA reference price to $230.677/103m3 for
April 1, 2014 EB-2014-0039 relative to $182.043/103m3 embedded in its EB-2013-0406
January 1, 2014 rates.
Gas Supply Commodity
The Rate 200 gas supply commodity charge will increase from 12.6131 cents/ m³ from
EB-2013-0406 to 17.5373 cents/ m³ in EB-2014-0039 for sales service customers.
The Rate 200 gas supply commodity charge will increase from 12.5878 cents/ m³ from
EB-2013-0406 to 17.5120 cents/ m³ in EB-2014-0039 for buy/sell service customers.
Gas Supply Load Balancing Charge
The Gas Supply Load Balancing charge will increase from EB-2013-0406 to EB-2014-0039
mostly due to higher carrying cost of gas in inventory.
Transportation Charge
The transportation charge will decrease from EB-2013-0406 to EB-2014-0039 as a result of
lower transportation related costs.
Delivery Charge
The Rate 200 delivery charge will increase from EB-2013-0406 to EB-2014-0039. This is
the result of the higher PGVA reference price applied to its Lost and Unaccounted for Gas
volumes.
Rider C
Effective from April 1, 2014 to March 31, 2015 the Rate 200 Rider C unit rate for sales and
buy/sell customers is 6.0570 ¢/m³, for Western T-service it is 2.7372 ¢/m³ and for Ontario
T-service it is 2.8782 ¢/m³.
Original : 2014-03-13
Page 1 de 2
ANNEXE I
Gazifère Inc.
Modifications du Tarif 200 avec commentaires
Ajustement du coût du gaz
Other Adjustment
On March 7, 2014 under docket number EB-2013-0046, the Ontario Energy Board approved
the clearing of EGD’s 2012 Deferral and Variance Accounts. The clearance will occur in
April as a one-time adjustment to customer’s bills. Rate 200 is forecast to receive a credit of
approximately $442,700.
Original : 2014-03-13
Page 2 de 2
ANNEXE II
GAZIFÈRE INC.
CALCUL DE L'IMPACT UNITAIRE SUR LES TARIFS RÉSULTANT DE L'AUGMENTATION DU TARIF 200 EB-2014-0039
AJUSTEMENT DU COÛT DU GAZ
LINE
NO.
DESCRIPTION
1
Gas Supply Increase ($000)
2
Col. 3
Col. 4
Col. 5
Col. 6
Col. 7
Col. 8
TOTAL
TARIF
1
TARIF
2
TARIF
3
TARIF
5
TARIF
9
6,177.4
2,849.5
3,167.1
17.1
0.0
143.7
Transportation Decrease ($000)
-85.2
-39.3
-43.7
-0.2
0.0
-2.0
3
Delivery Increase ($000)
237.4
101.6
108.7
0.3
12.0
14.9
4
Total Increase in Cost of Service ($000)
4.1
4.2
VOLUMES 10 m
Sales
Deliveries
5.1
5.2
5.3
UNIT RATE IMPACT cents/m3
Gas Supply Cost
Transportation Cost
Delivery Cost
3
6,329.6
3
124,269.4
166,350.0
57,323.0
66,232.7
63,711.3
63,711.3
344.2
344.2
0.0
14,159.1
2,890.8
21,902.6
4.97
(0.07)
0.14
4.97
(0.07)
0.15
4.97
(0.07)
0.17
4.97
(0.07)
0.09
4.97
(0.07)
0.08
4.97
(0.07)
0.07
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-2006-158 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.
Line 4
Total change in Cost of Service as referenced in Annexe III, Line 32, column 13.
Line 4.1 Sales volumes underpinning the Régie's Decision D-2013-191 (see Requête 3840-2013, GI-27, document 1, page 1of 1, lines 3,4,7,9,12 ,15 and 18, column 2).
Line 4.2 Delivery volumes underpinning the Régie's Decision D-2013-191 (see Requête 3840-2013, GI-27, document 1, page 1 of 1, line 22, 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: 2014-03-13
Page 1 de 1
ANNEXE III
GAZIFÈRE INC.
COÛT DU GAZ SELON LE TARIF 200 EB-2014-0039 (1)
BASÉ SUR LES VOLUMES DE L'ANNÉE TÉMOIN 2014
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
1109.3
TOTAL DELIVERIES
TOTAL SALES
T-SERVICE RECEIPTS
Col. 2
FEB
1109.3
Col. 3
MAR
1109.3
Col. 4
APR
1109.3
Col. 5
MAY
1109.3
Col. 6
JUN
Col. 7
JUL
1109.3
1109.3
Col. 8
AUG
1109.3
Col. 9
SEP
1109.3
Col. 10
OCT
1109.3
Col. 11
NOV
1109.3
Col. 12
DEC
Col. 13
TOTAL
1109.3
26,592.3
22,331.1
4,261.2
23,976.8
19,575.6
4,401.2
20,626.4
16,248.1
4,378.3
13,163.3
9,587.9
3,575.4
8,519.0
5,146.2
3,372.8
7,068.5
4,032.0
3,036.5
6,532.6
3,544.8
2,987.8
6,781.7
4,022.1
2,759.6
6,563.5
3,771.9
2,791.6
11,081.3
7,750.4
3,330.9
16,065.3
12,327.3
3,738.0
22,036.5
18,365.9
3,670.6
169,007.2 (2)
126,703.3
42,303.9
GAS COST CALCULATION
RATES
EB-2014-0039
Demand Charge
Delivery Charge
14.7000
1.3597
163,067
361,576
524,643
163,067
326,012
489,079
163,067
280,457
443,524
163,067
178,981
342,048
163,067
115,833
278,901
163,067
96,111
259,178
163,067
88,824
251,891
163,067
92,211
255,278
163,067
89,244
252,311
163,067
150,673
313,740
163,067
218,440
381,507
163,067
299,630
462,697
1,956.8
2,298.0
4,254.8
Load Balancing
Transportation
Gas supply (buy/sell)
Gas supply (system)
CURTAILMENT
0.6279
4.8985
17.5120
17.5373
-1.1000
166,973
1,093,887
78,212
3,837,941
150,550
958,909
68,561
3,364,365
129,513
795,911
56,907
2,792,480
82,652
469,663
33,581
1,647,830
53,491
252,089
18,024
884,462
44,383
197,508
14,122
692,965
41,018
173,644
12,415
609,236
42,582
197,022
14,087
691,257
41,212
184,768
13,211
648,267
69,580
379,653
27,145
1,332,026
100,874
603,854
43,175
2,118,642
138,367
899,653
64,325
3,156,463
1,061.2
6,206.6
443.8
21,775.9
TOTAL
5,701,656
5,031,464
4,218,336
2,575,775
1,486,967
1,208,157
1,088,204
1,200,226
1,139,769
2,122,144
3,248,052
4,721,505
33,742.3
Niagara Gas Transmission
RATES:
EB-2014-0039
125,567
5,827,223
125,567
5,157,031
125,567
4,343,902
125,567
2,701,341
125,567
1,612,534
125,567
1,333,723
125,567
1,213,771
125,567
1,325,793
125,567
1,265,336
125,567
2,247,711
125,567
3,373,619
125,567
4,847,072
1,506.8
35,249.1
29
30
RATES:
EB-2013-0406
4,714,993
4,181,347
3,533,310
2,221,977
1,353,719
1,130,534
1,034,800
1,123,386
1,075,304
1,859,756
2,758,191
3,932,159
28,919.5
31
32
Écart entre EB-2014-0039 et EB-2014-0406
Notes:
6,329.6
(1) Coût du gaz total selon le tarif 200 en vigueur le 1er avril 2014.
(2) Correspond aux volumes d'achat à 37,69 MJ/m³ tel qu'approuvés par la Régie dans sa décision D-2013-191 ( Voir R-3840-2013, GI-31, document 2.1, page 1 de 1, ligne 5).
Original: 2014-03-13
Page 1 de 1
ANNEXE IV
GAZIFÈRE INC.
COÛT DU GAZ SELON LE TARIF 200 EB-2013-0406 (1)
BASÉ SUR LES VOLUMES DE L'ANNÉE TÉMOIN 2014
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
Notes:
CONTRACT DEMAND
Col. 1
JAN
1109.3
TOTAL DELIVERIES
TOTAL SALES
T-SERVICE RECEIPTS
Col. 2
FEB
1109.3
Col. 3
MAR
1109.3
Col. 4
APR
1109.3
Col. 5
MAY
1109.3
Col. 6
JUN
1109.3
Col. 7
JUL
Col. 8
AUG
1109.3
1109.3
Col. 9
SEP
1109.3
Col. 10
OCT
1109.3
Col. 11
NOV
1109.3
Col. 12
DEC
Col. 13
TOTAL
1109.3
26,592.3
22,331.1
4,261.2
23,976.8
19,575.6
4,401.2
20,626.4
16,248.1
4,378.3
13,163.3
9,587.9
3,575.4
8,519.0
5,146.2
3,372.8
7,068.5
4,032.0
3,036.5
6,532.6
3,544.8
2,987.8
6,781.7
4,022.1
2,759.6
6,563.5
3,771.9
2,791.6
11,081.3
7,750.4
3,330.9
16,065.3
12,327.3
3,738.0
22,036.5
18,365.9
3,670.6
169,007.2 (2)
126,703.3
42,303.9
GAS COST CALCULATION
RATES
EB-2013-0406
Demand Charge
Delivery Charge
14.7000
1.3026
163,067
346,391
509,458
163,067
312,322
475,389
163,067
268,679
431,747
163,067
171,465
334,532
163,067
110,969
274,036
163,067
92,075
255,142
163,067
85,094
248,161
163,067
88,339
251,406
163,067
85,496
248,563
163,067
144,345
307,412
163,067
209,266
372,334
163,067
287,047
450,114
1,956.8
2,201.5
4,158.3
Load Balancing
Transportation
Gas supply (buy/sell)
Gas supply (system)
CURTAILMENT
0.5805
4.9665
12.5878
12.6131
-1.1000
154,368
1,109,072
56,220
2,760,307
139,185
972,220
49,283
2,419,703
119,736
806,960
40,905
2,008,395
76,413
476,183
24,138
1,185,145
49,453
255,588
12,956
636,119
41,033
200,250
10,151
498,391
37,922
176,055
8,924
438,172
39,368
199,757
10,126
497,163
38,101
187,333
9,496
466,243
64,327
384,923
19,512
958,014
93,259
612,237
31,035
1,523,760
127,922
912,142
46,237
2,270,178
981.1
6,292.7
319.0
15,661.6
TOTAL
4,589,426
4,055,781
3,407,743
2,096,411
1,228,153
1,004,967
909,233
997,819
949,737
1,734,189
2,632,625
3,806,593
27,412.7
EB-2013-0406
125,567
4,714,993
125,567
4,181,347
125,567
3,533,310
125,567
2,221,977
125,567
1,353,719
125,567
1,130,534
125,567
1,034,800
125,567
1,123,386
125,567
1,075,304
125,567
1,859,756
125,567
2,758,191
125,567
3,932,159
1,506.8
28,919.5
Niagara Gas Transmission
RATES:
(1) Coût du gaz total selon le tarif 200 en vigueur le 1er janvier 2014.
(2) Correspond aux volumes d'achat à 37,69 MJ/m³ tel qu'approuvés par la Régie dans sa décision D-2013-191 ( Voir R-3840-2013, GI-31, document 2.1, page 1 de 1, ligne 5).
Original: 2014-03-13
Page 1 de 1
ANNEXE V
GAZIFÈRE INC.
AJUSTEMENT SUBSÉQUENT AUX TARIFS EN VIGUEUR RÉSULTANT DE LA DÉCISION D-2013-191
AJUSTEMENT DU COÛT DU GAZ
ITEM
NO.
DESCRIPTION
January 1st, 2014
Proposed
Proposed Rates
April 1st, 2014
Rates
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
21.14
19.99
18.88
17.71
15.46
13.76
0.15
0.15
0.15
0.15
0.15
0.15
21.29
20.14
19.03
17.86
15.61
13.91
8
Transportation Charge
5.02
(0.07)
4.95
9
Gas Supply Charge
12.81
4.97
17.78
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
26.94
26.14
25.36
24.59
23.79
0.17
0.17
0.17
0.17
0.17
27.11
26.31
25.53
24.76
23.96
16
Transportation Charge
5.02
(0.07)
4.95
17
Gas Supply Charge
12.81
4.97
17.78
20.68
0.00
20.68
Rate 3:
18
Monthly Fixed Charge:
(¢/m³ of the subscribed volume)
Delivery Charge (¢/m³):
For all volumes delivered
8.82
0.09
8.91
19
20
Transportation Charge
5.02
(0.07)
4.95
21
Gas Supply Charge
12.81
4.97
17.78
20.94
0.00
20.94
6.96
5.91
0.09
0.09
7.05
6.00
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
5.02
(0.07)
4.95
26
Gas Supply Charge
12.81
4.97
17.78
Original: 2014-03-13
Page 1 de 2
ANNEXE V
GAZIFÈRE INC.
AJUSTEMENT SUBSÉQUENT AUX TARIFS EN VIGUEUR RÉSULTANT DE LA DÉCISION D-2013-191
AJUSTEMENT DU COÛT DU GAZ
ITEM
NO.
DESCRIPTION
Proposed Rates
January 1st, 2014
Proposed
Proposed Rates
April 1st, 2014
Pass On
Adjustment
Pass On
col.3
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
3.71
0.08
3.79
29
Transportation Charge
5.02
(0.07)
4.95
30
Gas Supply Charge
12.81
4.97
17.78
20.94
0.00
20.94
3.93
0.59
0.09
0.09
4.02
0.68
Rate 6:
31
32
33
Monthly Fixed Charge:
(¢/m³ of the subscribed volume)
Delivery Charge (¢/m³):
Maximum
Minimum
34
Transportation Charge
5.02
(0.07)
4.95
35
Gas Supply Charge
12.81
4.97
17.78
21.42
0.00
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
22.30
21.16
20.01
18.89
16.60
14.89
0.15
0.15
0.15
0.15
0.15
0.15
22.45
21.31
20.16
19.04
16.75
15.04
42
Transportation Charge
5.02
(0.07)
4.95
43
Gas Supply Charge
12.81
4.97
17.78
10.48
1.91
0.09
0.09
10.57
2.00
Rate 7:
Rate 8:
44
45
Delivery Charge (¢/m³):
Maximum
Minimum
46
Transportation Charge
5.02
(0.07)
4.95
47
Gas Supply Charge
12.81
4.97
17.78
3.15
0.00
3.15
2.58
2.39
0.07
0.07
2.65
2.46
Rate 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
5.02
(0.07)
4.95
52
Gas Supply Charge
12.81
4.97
17.78
Original: 2014-03-13
Page 2 de 2
ANNEXE VI
GAZIFÈRE INC.
Autres composantes des tarifs
Ajustement du coût du gaz
Line
no
Description
1
Billing of the deficiency in minimum annual volume
2
Rate 3
3
Rate 4
4
5
Average
unit rate
of last block of
the proposed rate (1)
¢/m3
1
Unit
load balancing
rate (2)
¢/m3
2
Proposed
rate
of other
components
¢/m3
3=1+2
13.87
(6.95)
6.92
load factor less
or equal to 70%
12.00
(7.08)
4.92
load factor higher than 70%
10.96
(7.09)
3.87
6
Rate 5
8.75
(6.81)
1.94
7
Rate 9
7.41
(6.24)
1.17
8
Maximum charge on a prorated basis of any annual
minimum bill incurred by Gazifère
9
Rate 3
13.87
s/o
13.87
10
Rate 4
11
load factor less
or equal to 70%
12.00
s/o
12.00
12
load factor higher than 70%
10.96
s/o
10.96
13
Rate 5
8.75
s/o
8.75
14
Rate 9
7.41
s/o
7.41
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: 2014-03-13
Page 1 de 1
ANNEXE VII
Gazifère Inc.
Taux unitaire et revenus par composante et par tarif
Ajustement du coût du gaz
January 1, 2014 Pass-On
Line No.
Unit rate
cents/m3
Col. 1
April 1, 2014 Pass On
Total
$ '000
Col. 2
Unit rate
cents/m3
Col. 3
Total
$ '000
Col. 4
Variance
(1)
%
Col. 6
$'000
Col. 5
Rate 1
1.1
1.2
1.3
1.4
1.0
Gas Supply Commodity
(2)
Gas Supply Load Balancing
Transportation
Distribution
Total
12.81
4.53
5.02
12.56
34.91
7,339
3,002
2,872
8,316
21,529
17.78
4.69
4.95
12.56
39.96
10,189
3,104
2,832
8,316
24,442
2,850
102
(39)
2,912
39%
3%
-1%
0%
14%
12.81
5.34
5.02
27.20
50.36
8,158
3,400
3,192
17,328
32,079
17.78
5.51
4.95
27.20
55.43
11,325
3,509
3,150
17,328
35,312
3,167
109
(44)
3,232
39%
3%
-1%
0%
10%
12.81
44
17.78
61
17
39%
1.90
5.02
7.88
27.60
7
17
27
95
1.99
4.95
7.88
32.59
7
17
27
112
0
(0)
17
5%
-1%
0%
18%
12.81
1.41
5.02
3.65
22.88
199
517
716
17.78
1.49
4.95
3.65
27.86
210
517
727
12
12
39%
6%
-1%
0%
22%
12.81
0.80
5.02
2.48
21.11
370
175
144
544
1,234
17.78
0.87
4.95
2.48
26.07
514
190
142
544
1,390
144
15
(2)
156
39%
8%
-1%
0%
24%
12.80
4.08
5.01
16.07
37.96
15,912
6,783
6,226
26,732
55,653
17.79
4.22
4.95
16.07
43.03
22,089
7,020
6,141
26,732
61,982
6,178
237
(85)
6,330
39%
3%
-1%
0%
13%
Rate 2
2.1
2.2
2.3
2.4
2.0
Gas Supply Commodity
Gas Supply Load Balancing (2)
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
Rate 5
4.1
4.2
4.3
4.4
4.0
Gas Supply Commodity
Gas Supply Load Balancing (2)
Tranportation
Distribution
Total
Rate 9
5.1
5.2
5.3
5.4
5.0
Gas Supply Commodity
Gas Supply Load Balancing (2)
Transportation
Distribution
Total
Gazifère Total
6.1
6.2
6.3
6.4
6.0
Gas Supply Commodity
Gas Supply Load Balancing (2)
Transportation
Distribution
Total
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: 2014-03-13
Page 1 de 3
ANNEXE VIII
Original: 2014-03-13
Page 2 de 3
ANNEXE IX
Gas Supply Commodity
Gazifère Inc.
Taux unitaire par composantes
Tarifs du 1er janvier 2014 versus tarifs du 1er avril 2014
Ajustement du coût du gaz
60
Gas Supply Load Balancing
Transportation
Distribution
55
50
45
Unit Rate cents/m3
40
35
30
25
20
15
10
5
0
January
April
Rate 1
Original: 2014-03-13
January
April
Rate 2
January
April
Rate 3
January
April
January
Rate 5
April
January
April
Rate 9
Page 3 de 3
ANNEXE X
GAZIFÈRE INC.
ANNEXE AJUSTEMENT DU COÛT DU GAZ NATUREL
21.1 AJUSTEMENT DU COÛT DU GAZ NATUREL
Le présent ajustement du coût du gaz naturel s’applique à tous les volumes de gaz naturel
vendus ou livrés durant la période du 1er avril 2014 au 31 mars 2015.
Service de vente et service
Tarifs
de fourniture en achat-revente
Service-T
dans l'Ouest
1à9
(¢/m3)
(¢/m3)
3.34
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-2014-0039.
Le montant de 3.3198 ¢/m³ a été ajusté pour la valeur calorifique.
Original: 2014-03-13
Page 1 de 1
ANNEXE XI
GAZIFÈRE INC.
AJUSTEMENT DU COÛT DU GAZ - AVRIL 2014
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: 2012
No de
ligne
Description
1
Solde du compte ajustement du coût du gaz au 31 décembre 2012 ($)
2
Service de vente et
service de fourniture
en achat-revente
dans l'ouest
1
Service-T
Total
3 = 1+2
2
($34,778)
($34,901)
($69,679) (1)
Liquidation des comptes différés d'EGD ($)
($429,600)
($13,100)
($442,700) (2)
3
Récupération nette (Remboursement net) par type de client ($)
($464,378)
($48,001)
($512,379)
4
Volumes de ventes du 1er janvier au 31 décembre 2012 (m³)
5
Taux unitaire par type de client
116,679,328
(0.40) ¢/m³
44,801,231
161,480,559
(0.11) ¢/m³
Notes: (1) Voir Requête 3840-2013, Phase II (Fermeture des livres 2012), Décision D-2013-102, page 22.
(2) Voir Requête EGD EB-2013-0046, page 5 of 8, line item 1.11, column 1
Original: 2014-03-13
Page 1 de 1
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
-
2012 Deferral and Variance Accounts
Original: 2014-03-13
25 Pages
500 Consumers Road
North York, ON M2J 1P8
PO Box 650
Scarborough ON M1K 5E3
Andrew Mandyam
Director, Regulatory Affairs
Tel
416-495-6350
Fax 416-495-6072
Email andrew.mandyam@enbridge.com
VIA RESS, EMAIL and COURIER
March 12, 2014
Ms. Kirsten Walli
Board Secretary
Ontario Energy Board
2300 Yonge Street, 27th Floor
Toronto, Ontario
M4P 1E4
Dear Ms. Walli:
Re:
EB-2014-0039 (QRAM Application)_____________________________
Today, we are filing one electronic copy of the Application of Enbridge Gas
Distribution Inc. (“Enbridge”) in Word and PDF formats, and two paper copies of
the Application with the supporting evidence (binder format) by courier,
requesting an order approving or fixing interim rates for the sale, distribution,
storage, and transmission of gas effective April 1, 2014.
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 this
Application as Appendix A.
As approved by the Board in the Company’s EB-2013-0046 2012 Earnings
Sharing and Deferral and Variance Account Clearance proceeding, the Company
will be clearing the deferral and variance account balances as a one-time
adjustment to customers’ bills in April 2014. The clearance unit rates approved
in the EB-2013-0046 Order can be found at Exhibit Q2-1, 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.
March 14, 2014
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 March 17, 2014.

Any reply comments from Enbridge must be filed with the Board, and
served on all interested parties, on or before March 19, 2014.

The Board would thereafter issue an order approving the applied-for rate
adjustments, or modifying them as required, effective April 1, 2014.
Enbridge requests the Board to issue such an order on or before March 26,
2014. Enbridge would then be able to implement the resultant rates during
Enbridge’s first billing cycle in April 2014.
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,
(Original Signed)
Andrew Mandyam
Director, Regulatory Affairs
Encl.
cc:
Mr. Fred Cass, Aird & Berlis LLP
All Interested Parties EB-2012-0459
Filed: 2014-03-12
EB-2014-0039
Exhibit Q2-1
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 interim rates for the sale, distribution,
storage, and transmission of gas effective April 1,
2014.
APPLICATION FOR
RATE ADJUSTMENT
Gas Costs
Second Quarter - Test Year 2014
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 April 1, 2014. 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.
Filed: 2014-03-12
EB-2014-0039
Exhibit Q2-1
Tab 2
Schedule 1
Page 2 of 5

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.

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 current utility price approved in the EB-2013-0406 is
$182.043/103m3 ($4.830/GJ @ 37.69 MJ/m3). Enbridge has recalculated the
utility price for the second quarter of Test Year 2014 using the prescribed
methodology reflecting a higher commodity cost. The recalculated utility
price is $230.677/103m3 ($6.120/GJ @ 37.69 MJ/m3).
5. The resultant rates would increase the total bill for a typical residential
customer on system gas by $152.00 or 15.1% (approx.) annually and, for a
typical residential customer on direct purchase, would increase the total bill
by $1.00 or 0.2% (approx.) annually.
Filed: 2014-03-12
EB-2014-0039
Exhibit Q2-1
Tab 2
Schedule 1
Page 3 of 5
PGVA
6. 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 commodity, transportation and load balancing costs for all
bundled customers.
7. Effective from April 1, 2014 to March 31, 2015 the Rider C unit rate for
residential customers on sales service is 7.1649 ¢/m³, for Western
T-service it is 3.8721 ¢/m³ and for Ontario T-service it is 4.0131 ¢/m³.
Other
Enbridge is implementing the clearing of its 2012 deferral variance account
balances as a one-time adjustment on customers April 2014 bills as
approved by the Board on March 7, 2014 in EB-2013-0046.
Regulatory Framework
8. 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).
9. 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 March 17, 2014.

Any reply comments from Enbridge are filed with the Board, and
served on all interested parties, on or before March 19, 2014.

The Board thereafter issues an order approving the applicable rate
adjustments or modifying them as required, effective April 1, 2014.
Filed: 2014-03-12
EB-2014-0039
Exhibit Q2-1
Tab 2
Schedule 1
Page 4 of 5
10. Enbridge requests that the Board issue such an order on or before March 26,
2014 (if possible). Enbridge would then be able to implement the resultant
rates during the first billing cycle in April 2014.
11. 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
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.
12. 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. Andrew Mandyam
Director, Regulatory Affairs
Telephone:
Fax:
Electronic access:
(416) 495-5499
(416) 495-6072
egdregulatoryproceedings@enbridge.com
(2) Ms. Tania Persad
Senior Legal Counsel,
Regulatory
Telephone:
Fax:
Electronic access:
(416) 495-5891
(416) 495-5994
tania.persad@enbridge.com
Filed: 2014-03-12
EB-2014-0039
Exhibit Q2-1
Tab 2
Schedule 1
Page 5 of 5
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
DATE: March 12, 2014
ENBRIDGE GAS DISTRIBUTION INC.
(Original Signed)
Per:___________________________________
Andrew Mandyam
Director, Regulatory Affairs
Filed: 2014-03-12
EB-2014-0039
Exhibit Q2-1
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: 2014-03-12
EB-2014-0039
Exhibit Q2-1
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: 2014-03-12
EB-2014-0039
Exhibit Q2-1
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: 2014-03-12
EB-2014-0039
Exhibit Q2-1
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: 2014-03-12
EB-2014-0039
Exhibit Q2-1
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: 2014-03-12
EB-2014-0039
Exhibit Q2-1
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
1.3597 ¢/m³
Gas Supply Load Balancing Charge
0.6279 ¢/m³
Transportation Charge per cubic metre
4.8985 ¢/m³
System Sales Gas Supply Charge per cubic metre
(If applicable)
Buy/Sell Sales Gas Supply Charge per cubic metre
(If applicable)
17.5373 ¢/m³
17.5120 ¢/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:
April 1, 2014
April 1, 2014
EB-2014-0039
January 1, 2014
$
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.
Any material instance of failure to curtail in any contract year may result in the Applicant forfeiting the right
to receive interruptible service under this rate schedule.
Any Applicant taking a material volume of Unauthorized Supply Overrun Gas, during a period of ordered
curtailment, may forfeit its curtailment credits for the respective winter season, December through March inclusive.
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.
MINIMUM BILL:
Per cubic metre of Annual Volume Deficiency
(See Terms and Conditions of Service):
6.8370 ¢/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 April 1, 2014 under Sales Service including
Buy/Sell Arrangements and Transportation Service. This rate schedule is effective April 1, 2014 and replaces the
identically numbered rate schedule that specifies implementation date, January 1, 2014 and that indicates
as the Board Order, EB-2013-0406, effective January 1, 2014.
EFFECTIVE DATE:
IMPLEMENTATION DATE:
BOARD ORDER:
REPLACING RATE EFFECTIVE:
April 1, 2014
April 1, 2014
EB-2014-0039
January 1, 2014
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:
$75.00 per month
Fixed Charge
$0.21 per month per account
Account Charge
AVERAGE COST OF TRANSPORTATION:
The average cost of transportation effective April 1, 2014:
Point of Acceptance
Firm Transportation
(FT)
CDA, EDA
4.8985 ¢/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:
April 1, 2014
April 1, 2014
EB-2014-0039
January 1, 2014
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 April 1, 2014. This rate schedule is effective
April 1, 2014 and replaces the identically numbered rate schedule that specifies implementation date,
January 1, 2014 and that indicates the Board Order, EB-2013-0406 effective January 1, 2014.
EFFECTIVE DATE:
IMPLEMENTATION DATE:
BOARD ORDER:
REPLACING RATE EFFECTIVE:
April 1, 2014
April 1, 2014
EB-2014-0039
January 1, 2014
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:
$75.00 per month
Fixed Charge
$0.21 per month per account
Account Charge
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 April 1, 2014. This rate schedule is effective
April 1, 2014 and replaces the identically numbered rate schedule that specifies implementation date,
January 1, 2014 and that indicates the Board Order, EB-2013-0406 effective January 1, 2014.
EFFECTIVE DATE:
IMPLEMENTATION DATE:
BOARD ORDER:
REPLACING RATE EFFECTIVE:
April 1, 2014
April 1, 2014
EB-2014-0039
January 1, 2014
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 April 1, 2014 to March 31, 2015.
Sales Service
( ¢/m³ )
Western
Transportation Service
( ¢/m³ )
Ontario
Transportation Service
( ¢/m³ )
Rate 1
7.1649
3.8721
4.0131
Rate 6
6.9006
3.5776
3.7186
Rate 9
3.0124
(0.0840)
0.0570
Rate 100
6.9006
3.5776
3.7186
Rate 110
3.7105
0.5462
0.6872
Rate 115
3.2387
0.1100
0.2510
Rate 135
2.9590
(0.1410)
0.0000
Rate 145
5.0983
1.8170
1.9580
Rate 170
4.0219
0.9411
1.0821
Rate 200
6.0570
2.7372
2.8782
Rate Class
EFFECTIVE DATE:
IMPLEMENTATION DATE:
BOARD ORDER:
REPLACING RATE EFFECTIVE:
April 1, 2014
April 1, 2014
EB-2014-0039
January 1, 2014
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
3.2928
Transportation
(0.1410)
(0.1410)
Load Balancing
4.0131
4.0131
4.0131
Total
7.1649
3.8721
4.0131
Commodity
3.3230
Transportation
(0.1410)
(0.1410)
Load Balancing
3.7186
3.7186
3.7186
Total
6.9006
3.5776
3.7186
Commodity
3.0964
Transportation
(0.1410)
(0.1410)
Load Balancing
0.0570
0.0570
0.0570
Total
3.0124
(0.0840)
0.0570
Commodity
3.3230
Transportation
(0.1410)
(0.1410)
Load Balancing
3.7186
3.7186
3.7186
Total
6.9006
3.5776
3.7186
Commodity
3.1643
Transportation
(0.1410)
(0.1410)
Load Balancing
0.6872
0.6872
0.6872
Total
3.7105
0.5462
0.6872
Commodity
3.1287
Transportation
(0.1410)
(0.1410)
Load Balancing
0.2510
0.2510
0.2510
Total
3.2387
0.1100
0.2510
Commodity
3.1000
Transportation
(0.1410)
(0.1410)
Load Balancing
0.0000
0.0000
0.0000
Total
2.9590
(0.1410)
0.0000
EFFECTIVE DATE:
IMPLEMENTATION DATE:
BOARD ORDER:
REPLACING RATE EFFECTIVE:
April 1, 2014
April 1, 2014
EB-2014-0039
January 1, 2014
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
3.2813
Transportation
(0.1410)
(0.1410)
Load Balancing
1.9580
1.9580
1.9580
Total
5.0983
1.8170
1.9580
Commodity
3.0808
Transportation
(0.1410)
(0.1410)
Load Balancing
1.0821
1.0821
1.0821
Total
4.0219
0.9411
1.0821
Commodity
3.3198
Transportation
(0.1410)
(0.1410)
Load Balancing
2.8782
2.8782
2.8782
Total
6.0570
2.7372
2.8782
EFFECTIVE DATE:
IMPLEMENTATION DATE:
BOARD ORDER:
REPLACING RATE EFFECTIVE:
April 1, 2014
April 1, 2014
EB-2014-0039
January 1, 2014
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
( ¢/m³ )
Unbundled Services
Rate Class
Rate 125
0.0000
Rate 300
0.0000
EFFECTIVE DATE:
IMPLEMENTATION DATE:
BOARD ORDER:
REPLACING RATE EFFECTIVE:
April 1, 2014
April 1, 2014
EB-2014-0039 January 1, 2014
Page 1 of 1
Handbook 58
2012 Deferral and Variance Accounts
(717.5)
236.2
(442.7)
(1.2)
EARNINGS SHARING MECHANISM
TOTAL
RATE 1
RATE 6
RATE 9
RATE 100
RATE 110
RATE 115
RATE 125
RATE 135
RATE 145
20.
21.
1.1
1.2
1.3
1.4
1.5
1.6
1.7
1.8
1.9
1.10 RATE 170
1.11 RATE 200
1.12 RATE 300
1.
(1,036.6)
TRANSITION IMPACT OF ACCT CHANGE D/A
19.
ALLOCATION
TAX RATE & RULE CHANGE V/A
18.
0.0
(18,724.8)
46.1
41.7
(815.1)
(1,063.7)
10.2
(3.5)
(865.5)
(14,830.7)
(18,724.8)
(7,560.3)
4,435.8
305.9
(145.7)
OPEN BILL ACCESS V/A
EX-FRANCHISE THIRD PARTY BILLING SERVICES D/A
17.
0.0
0.0
158.8
(286.8)
4,441.4
181.8
(1,283.8)
0.0
6,827.6
(55.8)
497.0
(960.5)
16.
MUNICIPAL PERMIT FEES D/A
OPEN BILL SERVICE D/A
15.
UNBUNDLED RATE IMPLEMENTATION COST D/A
13.
14.
ELECTRIC PROGRAM EARNINGS SHARING D/A
SHARED SAVINGS MECHANISM 2010
7.
AVERAGE USE TRUE-UP V/A
LOST REVENUE ADJ MECHANISM 2010
6.
12.
DEMAND SIDE MANAGEMENT 2010
5.
11.
DEFERRED REBATE ACCOUNT
4.
GAS DISTRIBUTION ACCESS RULE D/A
STORAGE AND TRANSPORTATION D/A
3.
10.
UNACCOUNTED FOR GAS V/A
2.
CLASS ACTION SUIT D/A
(26,668.6)
TRANSACTIONAL SERVICES D/A
1.
ONTARIO HEARING COSTS V/A
0.0
1.
8.
0.0
1.7 INVENTORY ADJUSTMENT
9.
0.0
1.6 RIDER C 2009 DIRECT ALLOCATION
2,105.8
0.0
0.0
1.4 TRANSPORTATION TOLLS
0.0
1.3 SEASONAL DISCRETIONARY-LOAD BALANCING
1.5 CURTAILMENT REVENUE
0.0
0.0
CLASSIFICATION
1.2 SEASONAL PEAKING-LOAD BALANCING
PGVA:
TOTAL
($000)
1.1 COMMODITY
ITEM
NO.
COL.1
(23,017.3)
0.0
(391.9)
(187.6)
(157.1)
(80.1)
0.0
(51.8)
(537.2)
(6.5)
(2.0)
(9,441.8)
(12,161.3)
(23,017.3)
(23,017.3)
0.0
0.0
SALES
AND WBT
($000)
COL. 2
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
TOTAL
SALES
($000)
COL. 3
1,145.3
0.0
18.0
53.4
17.9
6.2
0.0
55.3
70.6
0.4
0.1
461.3
462.2
1,145.3
(960.5)
2,105.8
0.0
TOTAL
DELIVERIES
($000)
COL. 4
(2,063.6)
0.0
(33.6)
(45.6)
(24.0)
0.0
0.0
(0.1)
(26.4)
(0.8)
0.0
(951.4)
(981.8)
(2,063.6)
(338.9)
(1,724.6)
0.0
0.0
SPACE
($000)
COL. 5
Classification and Allocation of Deferral and Variance Account Balances
(2,305.2)
0.0
(23.7)
0.0
0.0
0.0
0.0
(5.7)
(19.4)
(0.9)
0.0
(996.0)
(1,259.5)
(2,305.2)
(378.6)
(1,926.6)
0.0
0.0
0.0
DELIVERABILITY
($000)
COL. 6
(3,124.5)
(1.4)
(8.5)
(10.4)
(10.7)
(3.1)
(30.8)
(13.4)
(29.8)
(0.8)
(0.8)
(897.7)
(2,117.1)
(3,124.5)
(7,560.3)
4,435.8
0.0
DIRECT
($000)
11,710.3
0.0
0.0
424.7
(878.6)
116.8
0.0
(798.4)
(545.2)
17.8
0.0
11,316.7
2,056.3
11,710.3
4,441.4
6,827.6
(55.8)
497.0
0.0
0.0
0.0
COL. 8
COL. 7
DISTRIBUTION
REV REQ
(DRR)
($000)
194.9
0.9
0.2
6.4
19.5
6.9
83.5
4.8
35.5
1.2
0.0
2.9
33.2
194.9
0.0
(145.7)
0.0
0.0
158.8
181.8
0.0
0.0
NUMBER OF
CUSTOMERS
($000)
COL. 9
0.0
(1,264.7)
(0.7)
(3.3)
(4.6)
(3.6)
(0.7)
(10.9)
(5.8)
(11.8)
(0.3)
(0.7)
(359.5)
(862.8)
(1,264.7)
305.9
0.0
(286.8)
(1,283.8)
RATE
BASE
($000)
COL. 10
Draft Rate Order
Filed: 2014-02-25
EB-2013-0046
Page 5 of 8
Plus Attachment