Filed: 2002-12-04
EB-2002-0494
RP-2002-0133
Exhibit Q2-1
Tab 1
Schedule 1
Page 1 of 4
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, 2003.
APPLICATION FOR
RATE ADJUSTMENT
Gas Costs
Second Quarter - Test Year 2003
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, 2003. This Application is made pursuant to, and the
Order would be issued under, section 36 of the Ontario Energy Board Act, 1998,
as amended. The Order would be made interim, though, under subsection 21(7)
of this statute.
2.
This Application and the supporting evidence were prepared in accordance with
the methodology prescribed in the Settlement Proposal, under Issue 2.2, approved
by the Board in the RP-2000-0040 proceeding.1 The text of the agreement to
settle Issue 2.2 is presented in Appendix A.
Utility Price Adjustment
3.
Enbridge’s utility price during this first quarter of Test Year 2003 is
$237.963/103m3 ($6.314/GJ @ 37.69 MJ/m3). This price was approved by the
1
The "Settlement Proposal (Main Case)" is dated May 11, 2001 and was approved by the Board on May
30, 2001: 1 Tr. 107-9. See also the Board's Final Rate Order dated June 28, 2001 and its Reasons for
Decision dated August 17, 2001; a copy of the Settlement Proposal is Appendix A to the latter.
Filed: 2002-12-04
EB-2002-0494
RP-2002-0133
Exhibit Q2-1
Tab 1
Schedule 1
Page 2 of 4
Board's Decision and Interim Rate Order dated September 27, 2002 (EB-20020431).
4.
Enbridge has recalculated the utility price for the second quarter of Test Year
2003 using the prescribed methodology. The recalculated utility price is
$259.519/103m3 ($6.886/GJ @ 37.69 MJ/m3), which varies from the current
utility price by $21.556/103m3 ($0.572/GJ @ 37.69 MJ/m3) or more than 0.5¢/m3,
and the former accordingly supersedes the latter as the utility price effective
January 1, 2003.
5.
Enbridge has used the recalculated utility price, together with the consequential
effect on the prescribed commodity-related costs, as the basis for recalculating the
gas supply charges for sales service, and also the delivery charges and the gas
supply load balancing charges, effective as of January 1, 2003. The resultant rates
would increase the total bill for a typical residential customer on system gas by
$68 or 6% (approx.) annually and, for a typical residential customer on direct
purchase, by $2 or 0.3% (approx.) annually.
PGVA
6.
Enbridge has adjusted the forecast balance in its Purchased Gas Variance Account
("PGVA") as of the end of Test Year 2003 (i.e., September 30, 2003) to account
for the recalculated utility price and the consequential gas storage inventory
adjustments. There were no changes in upstream transportation tolls during the
first quarter of Test Year 2003 and, in consequence, Enbridge has made no further
adjustment in this regard.
7.
The adjusted year-end balance in the PGVA, when translated into ¢/m3 based on
forecast consumption for the remainder of Test Year 2003, is 0.30¢/m3 and thus
less than the threshold of 0.5¢/m3. Therefore, Enbridge is not proposing to clear
the adjusted year-end balance of the PGVA at this time.
Regulatory Framework
8.
The regulatory framework for processing the Application and the supporting
evidence is prescribed in the Settlement Proposal. Enbridge's list of interested
parties is presented in Appendix B; the list includes the name(s) of the parties’
respective representative(s).
9.
Enbridge is filing with the Board one copy of the Application by facsimile and 10
copies of the Application with supporting evidence in binder format by courier.
Enbridge is also serving the representative(s) of each interested party with one
Filed: 2002-12-04
EB-2002-0494
RP-2002-0133
Exhibit Q2-1
Tab 1
Schedule 1
Page 3 of 4
copy of the Application by facsimile and with one copy of the Application with
supporting evidence (binder format) by courier.
10.
The following is the prescribed regulatory framework for processing the
Application:
•
Any responsive comments from interested parties must be filed with the
Board (10 copies), and served on Enbridge and the other interested parties
(one copy), on or before December 11, 2002.
•
Any reply comments from Enbridge must be filed with the Board (10
copies), and served on all interested parties (one copy), on or before
December 18, 2002.
•
The Board would thereafter issue an interim order approving the appliedfor utility price, gas supply charges, and delivery and load balancing
charges, or modifying them as required, and likewise the applied-for rates
effective January 1, 2003.
11.
Enbridge requests that the Board issue such an order on or before December 24,
2002. Enbridge would then be able to implement the resultant rates during the
first billing cycle in January 2003.
12.
Enbridge also requests that all documents in relation to this Application and
supporting evidence, including the responsive comments of any interested party,
be served on Enbridge and its counsel as follows:
(a)
Enbridge:
Ms. Marika O. Hare
Director, Regulatory Affairs
Enbridge Gas Distribution Inc.
Address for personal service:
500 Consumers Road
Willowdale, Ontario M2J 1P8
Mailing address:
P.O. Box 650
Scarborough, Ontario
M1K 5E3
Telephone:
(416) 753-7333
Filed: 2002-12-04
EB-2002-0494
RP-2002-0133
Exhibit Q2-1
Tab 1
Schedule 1
Page 4 of 4
Fax:
Electronic access:
(b)
(416) 495-6072
marika.hare@cgc.enbridge.com
Enbridge’s counsel:
Ms. Tania H. Persad
Legal Counsel, Regulatory
Enbridge Gas Distribution Inc.
Address for personal service
and mailing (see above)
Telephone:
Fax:
Electronic access:
(416) 495-5891
(416) 495-5994
tania.persad@cgc.enbridge.com
DATE December 4, 2002.
Enbridge Gas Distribution Inc.
Per:___________________________________
Marika O. Hare
Director, Regulatory Affairs
GAZIFÈRE INC.
DERIVATION OF UNIT RATE IMPACT FROM PASS ON OF GAS COST INCREASE IN RATE 200 EB-2002-0494
AJUSTEMENT DU COÛT DU GAZ
LINE
NO.
DESCRIPTION
1
Gas Supply Charge increase $ '000
2
Delivery Charge increase $ '000
3
Total increase in cost of service $ '000
Col. 3
Col. 4
Col. 5
Col. 6
Col. 7
Col. 8
Col. 9
TOTAL
TARIF
1
TARIF
2
TARIF
3
TARIF
4
TARIF
5
TARIF
9
2 592,8
1 061,6
1 303,6
10,3
0,0
217,4
0,0
59,3
24,8
13,9
0,1
2,3
3,8
14,4
######
######
######
######
2,17
0,05
2,17
0,02
2 652,1
VOLUMES 103 m3
3,1
3,2
Sales
Deliveries
119 283,6
182 105,7
472,9
472,9
0,0
#####
2,17
0,03
2,17
0,03
10 000,0
10 000,0
0,0
50 659,6
UNIT RATE IMPACT cents/m3
4,1
4,2
Gas Supply Charge
Delivery Charge
Notes:
4,1 Line 1 divided by Line 3.1
4,2 Line 2 divided by Line 3.2
Original: 2002-12-11
2,17
0,03
2,17
0,04
2,17
0,03
GAZIFÈRE INC.
COÛT DU GAZ SELON LE TARIF 200 EB-2002-0494 (1)
BASÉ SUR LES VOLUMES DE L'ANNÉE TÉMOIN 2002
AJUSTEMENT DU COÛT DU GAZ
Col. 1
OCT
1000 m3
54,57%
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
Col. 2
NOV
Col. 3
DEC
Col. 4
JAN
Col. 5
FEB
Col. 6
MAR
Col. 7
APR
Col. 8
MAY
Col. 9
JUN
Col. 10
JUL
Col. 11
AUG
Col. 12
SEP
3
Col. 13
TOTAL
LF:
1
1
1
1
1
1
1
1
1
1
1
1
919,3
919,3
919,3
919,3
919,3
919,3
919,3
919,3
919,3
919,3
919,3
919,3
54,57%
FIRST
15
15
8 912,5
13 107,2
13 789,5
13 789,5
13 789,5
13 789,5
13 789,5
13 789,5
10 533,5
9 817,1
9 193,7
9 059,0
143 360,0
NEXT
10
25
0,0
0,0
4 587,9
9 193,0
9 193,0
6 544,6
6 922,1
1 288,8
0,0
0,0
0,0
0,0
37 729,4
OVER
25
25
0,0
0,0
0,0
836,8
1 182,6
0,0
0,0
0,0
0,0
0,0
0,0
0,0
2 019,3
0,0
0,0
0,0
2 003,2
667,7
5 341,8
0,0
0,0
0,0
0,0
0,0
0,0
8 012,7
2 682,5
3 248,8
4 196,0
4 459,6
4 317,9
3 686,6
9 083,2
8 043,8
5 992,8
6 038,0
5 737,3
5 669,1
63 155,7
CURTAILMENT
T-SERVICE
TOTAL DELIVERIES
8 912,5
13 107,2
18 377,4
23 819,3
24 165,1
20 334,1
20 711,6
15 078,3
10 533,5
9 817,1
9 193,7
9 059,0
183 108,6
TOTAL SALES
6 230,1
9 858,3
14 181,3
19 359,6
19 847,2
16 647,5
11 628,4
7 034,5
4 540,7
3 779,1
3 456,4
3 389,9
119 953,0
T-SERVICE RECEIPTS
2 682,5
3 248,8
4 196,0
4 459,6
4 317,9
3 686,6
9 083,2
8 043,8
5 992,8
6 038,0
5 737,3
5 669,1
63 155,7
CHECK
8 912,5
13 107,2
18 377,4
23 819,3
24 165,1
20 334,1
20 711,6
15 078,3
10 533,5
9 817,1
9 193,7
9 059,0
183 108,6
REVENUE CALCULATION
RATES -
ANALYSIS - 2002 Update
EB-2002-0494
WINTER
SUMMER
0,0000
0,0000
0
0
0
0
0
0
0
0
0
0
0
0
DMD
18,0000
18,0000
165 474
165 474
165 474
165 474
165 474
165 474
165 474
165 474
165 474
165 474
165 474
165 474
1 985,7
1ST
0,4390
0,3827
34 108
50 161
60 536
60 536
60 536
60 536
52 772
52 772
40 312
37 570
35 184
34 669
579,7
2ND
0,3140
0,2827
0
0
14 406
28 866
28 866
20 550
19 569
3 643
0
0
0
0
115,9
3RD
0,3418
0,2891
0
0
0
2 860
4 042
0
0
0
0
0
0
0
6,9
CURTAILMENT -1,0000
-1,0000
0
0
0
(20 032 )
0
0
0
0
0
0
(80,1)
199 582
215 635
240 416
193 142
237 815
221 890
205 786
203 044
200 658
200 143
2 608,1
gas b/s
21,3579
21,3579
332 652
526 384
757 208
888 890
620 895
375 607
242 448
201 784
184 552
181 003
6 404,9
3,8875
3,8875
346 474
509 542
714 420
790 487
805 165
586 168
409 490
381 639
357 403
352 169
7 118,3
21,3772
21,3772
998 859
728 000
605 899
554 157
543 499
19 231,9
gas sys
TOTAL REVENUE
0,0000
237 704
(6 677 )
252 241
########## ##########
925 974
939 417
(53 418 )
########## ########## ########## ########## ########## ########## ##########
1 877 567
########## ########## ########## ########## ########## ########## ########## ########## ########## ########## ##########
35 363,2
1 877 567
########## ########## ########## ########## ########## ########## ########## ########## ########## ########## ##########
35 363,2
0
1 877 567
0
0
0
0
0
0
0
0
0
0
0
########## ########## ########## ########## ########## ########## ########## ########## ########## ########## ##########
0,0
35 363,2
1 740 066
########## ########## ########## ########## ########## ########## ########## ########## ########## ########## ##########
32 711,1
NGT
RATES:
0,0000
EB-2002-0494
37
38
RATES:
EB-2002-0431
39
40
Écart entre EB-2002-0494 et EB-2002-0431
Notes: (1) Voir le Tarif 200 en vigueur le 1er janvier 2003 inclus à la requête EB-2002-0494 déposée le 4 décembre 2002.
Original: 2002-12-11
2 652,1
GAZIFÈRE INC.
COÛT DU GAZ SELON LE TARIF 200 EB-2002-0431
BASÉ SUR LES VOLUMES DE L'ANNÉE TÉMOIN 2002
AJUSTEMENT DU COÛT DU GAZ
Col. 1
OCT
1000 m3
54,57%
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
Col. 2
NOV
Col. 3
DEC
Col. 4
JAN
Col. 5
FEB
Col. 6
MAR
Col. 7
APR
Col. 8
MAY
Col. 9
JUN
Col. 10
JUL
Col. 11
AUG
Col. 12
SEP
3
Col. 13
TOTAL
LF:
1
1
1
1
1
1
1
1
1
1
1
1
919,3
919,3
919,3
919,3
919,3
919,3
919,3
919,3
919,3
919,3
919,3
919,3
54,57%
FIRST
15
15
8 912,5
13 107,2
13 789,5
13 789,5
13 789,5
13 789,5
13 789,5
13 789,5
10 533,5
9 817,1
9 193,7
9 059,0
143 360,0
NEXT
10
25
0,0
0,0
4 587,9
9 193,0
9 193,0
6 544,6
6 922,1
1 288,8
0,0
0,0
0,0
0,0
37 729,4
OVER
25
25
0,0
0,0
0,0
836,8
1 182,6
0,0
0,0
0,0
0,0
0,0
0,0
0,0
2 019,3
0,0
0,0
0,0
2 003,2
667,7
5 341,8
0,0
0,0
0,0
0,0
0,0
0,0
8 012,7
T-SERVICE
2 682,5
3 248,8
4 196,0
4 459,6
4 317,9
3 686,6
9 083,2
8 043,8
5 992,8
6 038,0
5 737,3
5 669,1
63 155,7
TOTAL DELIVERIES
8 912,5
13 107,2
18 377,4
23 819,3
24 165,1
20 334,1
20 711,6
15 078,3
10 533,5
9 817,1
9 193,7
9 059,0
183 108,6
TOTAL SALES
6 230,1
9 858,3
14 181,3
19 359,6
19 847,2
16 647,5
11 628,4
7 034,5
4 540,7
3 779,1
3 456,4
3 389,9
119 953,0
T-SERVICE RECEIPTS
2 682,5
3 248,8
4 196,0
4 459,6
4 317,9
3 686,6
9 083,2
8 043,8
5 992,8
6 038,0
5 737,3
5 669,1
63 155,7
CHECK
8 912,5
13 107,2
18 377,4
23 819,3
24 165,1
20 334,1
20 711,6
15 078,3
10 533,5
9 817,1
9 193,7
9 059,0
183 108,6
CURTAILMENT
REVENUE CALCULATION
RATES -
EB-2002-0431
WINTER
ANALYSIS - 2002 Update
SUMMER
0,0000
0,0000
0
0
0
0
0
0
0
0
0
0
0
0
DMD
18,0000
18,0000
165 474
165 474
165 474
165 474
165 474
165 474
165 474
165 474
165 474
165 474
165 474
165 474
1 985,7
1ST
0,4244
0,3681
32 807
48 248
58 523
58 523
58 523
58 523
50 759
50 759
38 774
36 137
33 842
33 346
558,8
2ND
0,2994
0,2681
0
0
13 736
27 524
27 524
19 594
18 558
3 455
0
0
0
0
110,4
3RD
0,3272
0,2745
0
0
0
2 738
3 869
0
0
0
0
0
0
0
6,6
CURTAILMENT -1,0000
-1,0000
0
0
0
(20 032 )
0
0
0
0
0
0
(80,1)
198 281
213 722
237 733
234 227
248 713
190 173
234 791
219 688
204 248
201 611
199 316
198 820
2 581,3
gas b/s
19,1989
19,1989
299 026
473 173
680 564
929 009
952 410
798 935
558 131
337 638
217 939
181 386
165 896
162 706
5 756,8
3,8685
3,8685
344 781
507 052
710 928
921 448
934 825
786 624
801 130
583 304
407 488
379 773
355 657
350 448
7 083,5
19,2182
19,2182
897 979
1 420 947
2 044 044
2 790 429
2 860 701
2 399 515
1 676 077
1 013 933
654 475
544 706
498 189
488 608
17 289,6
1 740 066
2 614 894
3 673 269
4 875 113
4 996 649
4 175 247
3 270 129
2 154 563
1 484 151
1 307 477
1 219 058
1 200 582
32 711,1
1 740 066
2 614 894
3 673 269
4 875 113
4 996 649
4 175 247
3 270 129
2 154 563
1 484 151
1 307 477
1 219 058
1 200 582
32 711,1
0
1 740 066
0
2 614 894
0
3 673 269
0
4 875 113
0
4 996 649
0
4 175 247
0
3 270 129
0
2 154 563
0
1 484 151
0
1 307 477
0
1 219 058
0
1 200 582
0,0
32 711,1
gas sys
TOTAL REVENUE
NGT
RATES:
0,0000
EB-2002-0431
0,0000
(6 677 )
37
Notes:
Original: 2002-12-11
(1) Voir GI-32, requête 3464-2001, document 1.1, page 1 de 1, ligne 36.
(53 418 )
(1)
S:\budadmin\cause\cause2000\Gazifère - Suivi D-2002-283 (pass-on 1 jan 2003) 17-12-02.xls\autres composantes
GAZIFÈRE INC.
OTHER COMPONENTS OF THE RATE
AJUSTEMENT DU COÛT DU GAZ
Line
no
Description
Average
unit rate
Unit
of last block of load balancing
the proposed rate
rate
¢/m3
¢/m3
1
2
1
Billing of the deficiency in minimum annual volume
2
Rate 3
3
Rate 4
4
5
Proposed
rate
of other
components
¢/m3
3=1+2
11,27
(4,90 )
6,37
load factor less
or equal to 70%
9,14
(4,92 )
4,22
load factor higher than 70%
8,14
(4,92 )
3,22
6
Rate 5
7,03
(5,17 )
1,86
7
Rate 9
4,99
(3,99 )
1,00
8
Maximum charge on a prorated basis of any annual
minimum bill incurred by Gazifère
9
Rate 3
10
Rate 4
11,27
s/o
11,27
11
load factor less
or equal to 70%
9,14
s/o
9,14
12
load factor higher than 70%
8,14
s/o
8,14
13
Rate 5
7,03
s/o
7,03
14
Rate 9
4,99
s/o
4,99
Line
no
Description
15
Overrun Rate
16
Rates 3, 4, 5, 6, 8 and 9
17
T-Service credit
18
TCPL
Original: 2002-12-11
Rate as per
Rate 200
Proposed
EB-2002-0494 at
rate at
37.69 MJ/m3
37.89 MJ/m3
37,3241
37,52
4,3449
4,37
RATE NUMBER:
200
Rate for Service Rights per cubic metre of
Daily Capacity Repurchase Quantity per day of curtailment:
1,0 ¢/m³
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. As of October 1, 2001, 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 Mark et 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".
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. For any location presently served or any new Applicant for service pursuant to
this Rate Schedule in these areas, the Company shall purchase the rights to take service hereunder at 125% of
the above-stated Rate for Service Rights.
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 maximum Gas Supply Charge stated in Rate 320.
On the second and subsequent occasions in a contract year when the Applicant takes Unauthorized Demand
Overrun Gas, the Contract Demand shall be adjusted to the actual maximum daily volume taken and the Demand
Charges stated above shall apply for the whole contract year, including retroactively if necessary.
Should the Applicant fail to curtail its use of natural gas within the contracted time period or as ordered by the
Company, the rate shall be increased by:
25,0 ¢/m³
The third instance of such failure in any contract year may result in the Applicant forfeiting the right to be served
under this Rate Schedule. In such case service hereunder would cease, notwithstanding any Service Contract
between the Company and the Applicant. Gas supply and/or transportation service would continue to be
available to the Applicant pursuant to the provisions of the Company's Rate 6 until a Service Contract pursuant to
another applicable Rate Schedule was executed.
MINIMUM BILL:
Per cubic metre of Annual Volume Deficiency
(See Terms and Conditions of Service):
Sales and Western Canada Buy/Sell
T-Service, Ontario Buy/Sell and Western
Buy/Sell (Applicant provides fuel)
13,8491 ¢/m³
0,2551 ¢/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, 2003 under Sales Service,
including Buy/Sell Arrangements, and Transportation Service. This rate schedule is effective January 1, 2003
and replaces the identically numbered rate schedule that specifies, as the Effective Date, October 1, 2002
and that indicates, as the Board Order, EB-2002-0431.
EFFECTIVE DATE:
IMPLEMENTATION DATE:
BOARD ORDER:
REPLACING RATE EFFECTIVE:
January 1, 2003
January 1, 2003
EB-2002-0494
October 1, 2002
Page 2 of 2
Handbook 28
RATE NUMBER:
320
BACKSTOPPING SERVICE
APPLICABILITY:
To any Applicant whose delivery of natural gas to the Company for transportation to a Terminal Location has been
interrupted prior to the delivery of such gas to the Company.
CHARACTER OF SERVICE:
The volume of gas available for backstopping in any day shall be determined by the Company exercising its sole
discretion. If the aggregate daily demand for service under this Rate Schedule exceeds the supply available for
such day, the available supply shall be allocated to firm service customers on a first requested basis and any
balance shall be available to interruptible customers on a first requested basis.
RATE:
The rates applicable in the circumstances contemplated by this Rate Schedule, in lieu of the Gas Supply Charges
specified in any of the Company's other Rate Schedules pursuant to which the Applicant is taking service, shall be as
follows:
Billing Month
April
December
to
to
November
March
Gas Supply Charge
Per cubic metre of gas sold
24,8827 ¢/m³
24,5531 ¢/m³
provided that if upon the request of an Applicant, the Company quotes a rate to apply to gas which is delivered to the
Applicant at a particular Terminal Location on a particular day or days and to which this Rate Schedule is applicable
(which rate shall not be less than the Company's avoided cost in the circumstances at the time nor greater than the
otherwise applicable rate specified above), then the Gas Supply Charge applicable to such gas shall be the rate
quoted by the Company.
EFFECTIVE DATE:
To apply to bills rendered for gas consumed by customers on and after January 1, 2003 under Sales Service,
including Buy/Sell Arrangements, and Transportation Service. This rate schedule is effective January 1, 2003
and replaces the identically numbered rate schedule that specifies, as the Effective Date, October 1, 2002
and that indicates, as the Board Order, EB-2002-0431.
EFFECTIVE DATE:
IMPLEMENTATION DATE:
BOARD ORDER:
REPLACING RATE EFFECTIVE:
January 1, 2003
January 1, 2003
EB-2002-0494
October 1, 2002
Page 1 of 1
Handbook 39
RIDER:
A
2.
The Company will accommodate all TCPL FT capacity turnback requests in a manner that minimizes stranded
and other transitional costs. The Company is committed to maintaining the integrity of its distribution system
and the sanctity of all contracts.
3.
The Company will not amend any contracts to accommodate a customer's request to turnback capacity.
4.
Notice of TCPL FT turnback capacity will be accepted on Enbridge's Election for Enbridge Firm Transportation
Assignment form or other authorized written notice.
5.
The daily contractual right to receive natural gas would still be subject to the delivery, on a firm basis, of the full
Mean Daily Volume into the Company's Central Delivery Area (CDA) and/or Eastern Delivery Area (EDA). The
delivery area must match the area in which consumption will occur.
6.
The proportion of TCPL FT capacity that an eligible customer may request to be turned back each year
("percentage turnback") shall not exceed the proportion of the TCPL capacity that Enbridge is entitled to turn
back that year. This percentage turnback will be applied to calculate the customer's turnback capacity limit
based on the renewal volume of the direct purchase agreement.
7.
If the Company is unable to accommodate all or a portion of an eligible customer's request to turnback TCPL FT
capacity in the month requested by the customer, the Company will indicate the month(s) when such customer
request can be fully satisfied and the costs, if any, associated with accommodating this request. The customer
may then advise the Company as to whether or not they wish to proceed with the TCPL FT capacity turnback
request.
8.
All TCPL FT capacity turnback requests will be treated on an equitable basis.
9.
Customers may withdraw their original election given they provide notice to the Company a minimum of one week
prior to the deadline specified in the TransCanada tariff for FT contract extension.
10. The percentage turnback of TCPL FT capacity will be applied at the Direct Purchase Agreement level.
11. Written notice to turnback capacity must be received by the Company the earlier of:
(a) Sixty days prior to the expiry date of the current contract.
or
(b) A minimum of one week prior to the deadline specified in TransCanada tariff for FT contract extension.
EFFECTIVE DATE:
To apply to bills rendered for gas delivered on and after January 1, 2003. This rate schedule is effective January 1, 2003
and replaces the identically numbered rate schedule that specifies, as the Effective Date, October 1, 2002 and that
indicates, as the Board Order, EB-2002-0431.
EFFECTIVE DATE:
IMPLEMENTATION DATE:
BOARD ORDER:
REPLACING RATE EFFECTIVE:
January 1, 2003
January 1, 2003
EB-2002-0494
October 1, 2002
Page 2 of 2
Handbook 48
RIDER:
B
BUY / SELL SERVICE RIDER
APPLICABILITY:
This rider is applicable to any Applicant who entered into a Gas Purchase Agreement with the Company, prior to
April 1, 1999, to sell to the Company a supply of natural gas.
MONTHLY DIRECT PURCHASE ADMINISTRATION CHARGE:
Base Charge
Maximum Charge
$50,00 per month
$815,00 per month
Account Charge
New Accounts
Renewal Accounts
$0,50 per month per account
$0,15 per month per account
The above Basic Charge shall be increased up to the maximum charge, by the new account charge for each new
account and by the Renewal Account charge for each renewal account in a Direct Purchase Contract.
BUY / SELL PRICE:
In Buy/Sell Arrangements between the Company and an Applicant, the Company shall buy the Applicants gas at the
Company's actual FT-WACOG price determined on a monthly basis in the manner approved by the Ontario Energy
Board. For Western Buy/Sell arrangements the FT-WACOG price shall be reduced by pipeline transmission costs.
The Company's rates include an annual FT-WACOG of 25.6738 ¢/m³ of gas containing 37.69 MJ/m³.
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. The forecast annual FT-WACOG referenced above includes an average of
1.18 ¢/m³ for fuel.
EFFECTIVE DATE:
To apply to bills rendered for gas delivered on and after January 1, 2003. This rate schedule is effective January 1, 2003
and replaces the identically numbered rate schedule that specifies, as the Effective Date, October 1, 2002 and that
indicates, as the Board Order, EB-2002-0431.
EFFECTIVE DATE:
IMPLEMENTATION DATE:
BOARD ORDER:
REPLACING RATE EFFECTIVE:
January 1, 2003
January 1, 2003
EB-2002-0494
October 1, 2002
Page 1 of 1
Handbook 49
RIDER:
C
GAS INVENTORY ADJUSTMENT RIDER
The following adjustment is applicable to all gas sold or delivered during the period January 1, 2003 to September 30, 2003
pursuant to the EB-2002-0494 Board Order.
Rate Class
Sales Service
( ¢/m³ )
Transportation Service
( ¢/m³ )
Rate 1
0,0000
0,0000
Rate 6
0,0000
0,0000
Rate 9
0,0000
0,0000
Rate 100
0,0000
0,0000
Rate 110
0,0000
0,0000
Rate 115
0,0000
0,0000
Rate 135
0,0000
0,0000
Rate 145
0,0000
0,0000
Rate 170
0,0000
0,0000
Rate 200
0,0000
0,0000
Rate 300
N/A
0,0000
Rate 310
N/A
0,0000
EFFECTIVE DATE:
IMPLEMENTATION DATE:
BOARD ORDER:
REPLACING RATE EFFECTIVE:
January 1, 2003
January 1, 2003
EB-2002-0494
October 1, 2002
Page 1 of 1
Handbook 50