annexe i gazifère inc. modifications du tarif 200 avec ... · annexe i gazifère inc....

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 EB-2010-0258 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 EB-2010-0258 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 EB-2010-0146 on the delivery rate is a decrease of approximately 0.2%.

Original : 2010-12-13 de 2

ANNEXE I

Gazifère Inc. Modifications du Tarif 200 avec commentaires


Original : 2010-12-13 de 2

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.

CALCUL DE L'IMPACT UNITAIRE SUR LES TARIFS RÉSULTANT DE LA DIMINUTION DU TARIF 200 EB-2010-0347

Col. 3 Col. 4 Col. 5 Col. 6 Col. 7 Col. 8

LINE TARIF TARIF TARIF TARIF TARIFNO. DESCRIPTION TOTAL 1 2 3 5 9

1 Gas Supply Cost decrease $ '000 (1,192.0) -488.7 -699.0 -4.3 0.0 0.0

2 Transportation Cost increase $ '000 (651.0) -266.9 -381.7 -2.4 0.0 0.0

3 Delivery Cost increase $ '000 94.6 36.7 56.5 0.0 0.8 0.5

4 Total decrease in cost of service $ '000 (1,748.4)

VOLUMES 103 m3

4.1 Sales 121,692.9 49,894.1 71,358.8 440.0 0.0 0.04.2 Deliveries 160,178.9 60,466.8 71,438.7 440.0 14,159.1 13,674.3

UNIT RATE IMPACT cents/m3

5.1 Gas Supply Cost -0.98 -0.98 -0.98 -0.98 -0.98 -0.985.2 Transportation Cost -0.53 -0.53 -0.53 -0.53 -0.53 -0.535.3 Delivery Cost 0.06 0.06 0.08 0.01 0.01 0.00

AJUSTEMENT DU COÛT DU GAZ

GAZIFÈRE INC.

ANNEXE II

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.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-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 4.1Line 5.2 Line 2 divided by Line 4.1Line 5.3 Line 3 divided by Line 4.2.

Original: 2010-12-13 Page 1 de 1

Col. 1 Col. 2 Col. 3 Col. 4 Col. 5 Col. 6 Col. 7 Col. 8 Col. 9 Col. 10 Col. 11 Col. 12 Col. 131000 m3 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC TOTAL

1 CONTRACT DEMAND 1111.2 1111.2 1111.2 1111.2 1111.2 1111.2 1111.2 1111.2 1111.2 1111.2 1111.2 1111.223 TOTAL DELIVERIES 24,734.5 25,742.6 21,964.4 15,972.5 8,985.8 6,314.2 5,840.5 5,561.9 5,597.7 8,461.4 13,994.2 19,338.0 162,507.8 (2)4 TOTAL SALES 20,570.6 21,683.0 17,919.1 12,514.1 5,977.9 3,699.3 3,345.7 3,267.8 3,277.2 5,427.5 10,612.3 15,523.1 123,817.65 T-SERVICE RECEIPTS 4,163.8 4,059.6 4,045.3 3,458.4 3,008.0 2,614.9 2,494.9 2,294.0 2,320.5 3,033.9 3,381.9 3,815.0 38,690.2678 GAS COST CALCULATION910 RATES EB-2010-034711121314 Demand Charge 14.7000 163,346 163,346 163,346 163,346 163,346 163,346 163,346 163,346 163,346 163,346 163,346 163,346 1,960.215 Delivery Charge 1.1202 277,075 288,369 246,045 178,924 100,659 70,732 65,426 62,304 62,706 94,785 156,763 216,625 1,820.416 440,422 451,715 409,391 342,270 264,006 234,078 228,772 225,650 226,052 258,131 320,109 379,971 3,780.61718 Load Balancing 0.5881 145,463 151,392 129,173 93,934 52,846 37,134 34,348 32,709 32,920 49,762 82,300 113,727 955.719 Transportation 4.5736 940,819 991,693 819,548 572,346 273,405 169,190 153,017 149,457 149,886 248,232 485,365 709,963 5,662.920 Gas supply (buy/sell) 14 2900 58 791 61 970 51 213 35 765 17 085 10 573 9 562 9 339 9 366 15 512 30 330 44 365 353 9

BASÉ SUR LES VOLUMES DE L'ANNÉE TÉMOIN 2011AJUSTEMENT DU COÛT DU GAZ

GAZIFÈRE INC.COÛT DU GAZ SELON LE TARIF 200 EB-2010-0347

ANNEXE III

20 Gas supply (buy/sell) 14.2900 58,791 61,970 51,213 35,765 17,085 10,573 9,562 9,339 9,366 15,512 30,330 44,365 353.921 Gas supply (system) 14.3123 2,885,250 3,041,268 2,513,342 1,755,237 838,462 518,864 469,264 458,347 459,663 761,263 1,488,488 2,177,273 17,366.722 CURTAILMENT -1.10002324 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 28,119.8252627 Niagara Gas Transmission 118,483 118,483 118,483 118,483 118,483 118,483 118,483 118,483 118,483 118,483 118,483 118,483 1,421.828 RATES: EB-2010-0347 4,589,229 4,816,522 4,041,149 2,918,035 1,564,286 1,088,322 1,013,446 993,986 996,370 1,451,383 2,525,075 3,543,782 29,541.62930 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 31,290.03132 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).


Col. 1 Col. 2 Col. 3 Col. 4 Col. 5 Col. 6 Col. 7 Col. 8 Col. 9 Col. 10 Col. 11 Col. 12 Col. 131000 m3 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC TOTAL

1 CONTRACT DEMAND 1111.2 1111.2 1111.2 1111.2 1111.2 1111.2 1111.2 1111.2 1111.2 1111.2 1111.2 1111.223 TOTAL DELIVERIES 24,734.5 25,742.6 21,964.4 15,972.5 8,985.8 6,314.2 5,840.5 5,561.9 5,597.7 8,461.4 13,994.2 19,338.0 162,507.8 (2)4 TOTAL SALES 20,570.6 21,683.0 17,919.1 12,514.1 5,977.9 3,699.3 3,345.7 3,267.8 3,277.2 5,427.5 10,612.3 15,523.1 123,817.65 T-SERVICE RECEIPTS 4,163.8 4,059.6 4,045.3 3,458.4 3,008.0 2,614.9 2,494.9 2,294.0 2,320.5 3,033.9 3,381.9 3,815.0 38,690.2678 GAS COST CALCULATION910 RATES EB-2010-025811121314 Demand Charge 14.7000 163,346 163,346 163,346 163,346 163,346 163,346 163,346 163,346 163,346 163,346 163,346 163,346 1,960.215 Delivery Charge 1.1218 277,471 288,781 246,396 179,179 100,803 70,833 65,519 62,393 62,795 94,920 156,987 216,934 1,823.016 440,818 452,127 409,743 342,526 264,150 234,179 228,866 225,739 226,142 258,267 320,333 380,280 3,783.21718 Load Balancing 0.5180 128,125 133,347 113,775 82,737 46,547 32,708 30,254 28,810 28,996 43,830 72,490 100,171 841.819 Transportation 5.1042 1,049,967 1,106,743 914,626 638,746 305,123 188,819 170,769 166,797 167,275 277,030 541,673 792,328 6,319.920 Gas supply (buy/sell) 15 2613 62 787 66 182 54 694 38 196 18 246 11 291 10 212 9 974 10 003 16 566 32 392 47 380 377 9

BASÉ SUR LES VOLUMES DE L'ANNÉE TÉMOIN 2011AJUSTEMENT DU COÛT DU GAZ

GAZIFÈRE INC.COÛT DU GAZ SELON LE TARIF 200 EB-2010-0258 (1)

ANNEXE IV

20 Gas supply (buy/sell) 15.2613 62,787 66,182 54,694 38,196 18,246 11,291 10,212 9,974 10,003 16,566 32,392 47,380 377.921 Gas supply (system) 15.2837 3,081,077 3,247,684 2,683,927 1,874,368 895,370 554,080 501,113 489,456 490,861 812,932 1,589,514 2,325,048 18,545.422 CURTAILMENT -1.10002324 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 29,868.2252627 Niagara Gas Transmission 118,483 118,483 118,483 118,483 118,483 118,483 118,483 118,483 118,483 118,483 118,483 118,483 1,421.828 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

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).


ANNEXE V

GAZIFÈRE INC.AJUSTEMENT SUBSÉQUENT AUX TARIFS EN VIGUEUR RÉSULTANT DE LA DÉCISION D-2010-147


January 1st 2011Rates with Proposed Rates

ITEM October 1st, 2010, rate 200 Proposed January 1st, 2011NO. DESCRIPTION D-2010-147 Adjustment Pass On

col.1 col.2 col.3Rate 1:

1 Monthly Fixed Charge ($) 17.13 0.00 17.13

Delivery Charge (¢/m³):2 from 0 to 100 m³ 19.32 0.06 19.383 from 100 to 320 m³ 18.27 0.06 18.334 from 320 to 1,000 m³ 17.24 0.06 17.305 from 1,000 to 3,200 m³ 16.17 0.06 16.236 from 3,200 to 10,000 m³ 14.12 0.06 14.187 in excess of 10,000 m³ 12.55 0.06 12.61

8 Transportation Charge 5.15 -0.53 4.62

9 Gas Supply Charge 15.48 -0.98 14.50

Rate 2:

10 Monthly Fixed Charge ($) 10.05 0.00 10.05

Delivery Charge (¢/m³):11 from 0 to 50 m³ 20.42 0.08 20.5012 from 50 to 100 m³ 19.86 0.08 19.9413 from 100 to 320 m³ 19.29 0.08 19.3714 from 320 to 1,000 m³ 18.74 0.08 18.8215 in excess of 1,000 m³ 18.17 0.08 18.25



Rate 3:

18 Monthly Fixed Charge: 20.68 0.00 20.68 (¢/m³ of the subscribed volume)

Delivery Charge (¢/m³): 8.38 0.01 8.3919 For all volumes delivered



Rate 4:


Delivery Charge (¢/m³):23 Load factor less or equal to 70% 6.61 0.01 6.6224 Load factor higher than 70% 5.61 0.01 5.62




ANNEXE V

GAZIFÈRE INC.AJUSTEMENT SUBSÉQUENT AUX TARIFS EN VIGUEUR RÉSULTANT DE LA DÉCISION D-2010-147


January 1st 2011Rates with Proposed Rates

ITEM October 1st, 2010, rate 200 Proposed January 1st, 2011NO. DESCRIPTION D-2010-147 Adjustment Pass On

col.1 col.2 col.3

Rate 5:


Delivery Charge (¢/m³):28 For all volumes delivered 3.15 0.01 3.16



Rate 6:


Delivery Charge (¢/m³):32 Maximum 3.34 0.00 3.3433 Minimum 0.42 0.00 0.42



Rate 7:

Monthly Fixed Charge 21 42 0 00 21 42Monthly Fixed Charge 21.42 0.00 21.42Delivery Charge (¢/m³):

36 from 0 to 100 m³ 20.38 0.06 20.4437 from 100 to 320 m³ 19.32 0.06 19.3838 from 320 to 1,000 m³ 18.28 0.06 18.3439 from 1,000 to 3,200 m³ 17.25 0.06 17.3140 from 3,200 to 10,000 m³ 15.17 0.06 15.2341 in excess of 10,000 m³ 13.60 0.06 13.66



Tarif 8:

Delivery Charge (¢/m³):44 Maximum 8.90 0.00 8.9045 Minimum 1.61 0.00 1.61



Tarif 9:

48 Monthly Fixed Charge: 3.15 0.00 3.15 (¢/m³ times the maximum daily volume)

Delivery Charge (¢/m³):49 from 0 to 1,000,000 m³ 2.19 0.00 2.1950 in excess of 1,000,000 m³ 2.02 0.00 2.02




ANNEXE VI

GAZIFÈRE INC.Autres composantes des tarifs


Average Proposedunit rate Unit rate

of last block of load balancing of otherLine the proposed rate (1) rate (2) componentsno Description ¢/m3 ¢/m3 ¢/m3

1 2 3=1+2

1 Billing of the deficiency in minimum annual volume

2 Rate 3 13.01 (6.19) 6.82

3 Rate 4

4 load factor less or equal to 70% 11.24 (6.49) 4.75

5 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 annualminimum bill incurred by Gazifère

9 Rate 3 13.01 s/o 13.01

10 Rate 4

11 load factor less 11.24 s/o 11.24 or equal to 70%

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


Line No. Unit rate Total Unit rate Total Variance cents/m3 $ '000 cents/m3 $ '000 $'000 %(1)

Col. 1 Col. 2 Col. 3 Col. 4 Col. 5 Col. 6Rate 1

1.1 Gas Supply Commodity 15.48 7,724 14.50 7,235 (489) -6%1.2 Gas Supply Load Balancing (2) 4.11 2,488 4.17 2,525 37 1%1.3 Transportation 5.15 2,567 4.62 2,300 (267) -10%1.4 Distribution 11.28 6,823 11.28 6,823 - 0%1.0 Total 36.02 19,602 34.57 18,883 (719) -4%

Rate 2

2.1 Gas Supply Commodity 15.48 11,047 14.50 10,347 (699) -6%2.2 Gas Supply Load Balancing (2)

4.81 3,436 4.89 3,493 57 2%2.3 Transportation 5.15 3,672 4.62 3,290 (382) -10%2.4 Distribution 20.34 14,532 20.34 14,532 - 0%2.0 Total 45.78 32,687 44.35 31,662 (1,024) -3%

Rate 3

3.1 Gas Supply Commodity 15.48 68 14.50 64 (4) -6%3.2 Gas Supply Load Balancing (2) 1.68 7 1.69 7 0 1%3.3 Transportation 5.15 23 4.62 20 (2) -10%3.4 Distribution 7.72 34 7.72 34 - 0%3.0 Total 30.03 132 28.53 126 (7) -5%

Rate 5

D-2010-147 January 1st, 2011 Pass-on

ANNEXE VII

January 1st, 2011 with October 2010 rate 200

Taux unitaire et revenus par composante et par tarifGazifère Inc.


4.1 Gas Supply Commodity 15.48 - 14.50 - - -6%4.2 Gas Supply Load Balancing (2) 1.18 167 1.18 168 1 1%4.3 Tranportation 5.15 - 4.62 - - -10%4.4 Distribution 3.32 469 3.32 469 - 0%4.0 Total 25.12 636 23.62 637 1 -6%

Rate 9

5.1 Gas Supply Commodity 15.48 - 14.50 - - -6%5.2 Gas Supply Load Balancing (2) 0.67 92 0.67 92 - 0%5.3 Transportation 5.15 - 4.62 - - -10%5.4 Distribution 2.31 317 2.31 317 - 0%5.0 Total 23.61 408 22.10 408 - -6%

Gazifère Total

6.1 Gas Supply Commodity 15.48 18,839 14.50 17,647 (1,193) -6%6.2 Gas Supply Load Balancing (2) 3.86 6,190 3.92 6,284 95 2%6.3 Transportation 5.15 6,262 4.62 5,611 (651) -10%6.4 Distribution 13.84 22,175 13.84 22,175 - 0%6.0 Total 38.33 53,465 36.89 51,717 (1,748) -4%

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.



ANNEXE VIII

05000

100001500020000250003000035000

October 10 January 11

Gazifère Inc.Revenus totaux par composantes

Tarif du 1er janvier 2011 versus tarif du 1er octobre 2010Ajustement du coût du gaz

Gas Supply Commodity, Load Balancing & Transportation

Distribution

('000

Dol

lars

)

ANNEXE IX

10

15

20

25

30

35

40

45

50

55

Gazifère Inc.Taux unitaire par composante


Gas Supply Commodity

Gas Supply Load Balancing

Transportation

Distribution

Uni

t Rat

e ce

nts/

m3


0

5

10

15

20

25

30

35

40

45

50

55

1 2 3 4 5 6 7 8 9 10 11 12

Gazifère Inc.Taux unitaire par composante


Gas Supply Commodity

Gas Supply Load Balancing

Transportation

Distribution

Oct 10 Jan Passon

Rate 1 Rate 2 Rate 3 Rate 4 Rate 9

Uni

t Rat

e ce

nts/

m3

Rate 5

Oct 10 Jan Passon Oct 10 Jan Passon Oct 10 Jan Passon Oct 10 Jan Passon Oct 10 Jan Passon

Le présent ajustement du coût du gaz s’applique à tous les volumes de gaz vendus ou livrésdurant la période du 1er janvier 2011 au 31 décembre 2011.

Service deTarifs transport

(¢/m3)

1 à 9 0,00

service achat / revente (¢/m3)

(2,16)

ANNEXE AJUSTEMENT DU COÛT DU GAZ

ANNEXE X

GAZIFÈRE INC.ANNEXE AJUSTEMENT DU COÛT DU GAZ


Service de vente et

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.


Service de vente Serviceet service de

No de achat / revente transportligne Description Total

1 2 3 = 1+2

1 Solde du compte ajustement du coût du gaz au 31 décembre 2009 ($) ($782,871) $48,840 ($734,031) (1)

2 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 52,924,005 175,097,511

5 Taux unitaire par type de client -2.46 ¢/m³ 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.

ANNEXE XI

GAZIFÈRE INC.AJUSTEMENT DU COÛT DU GAZ - JANVIER 2011

LIQUIDATION DU COMPTE AJUSTEMENT DU COÛT DU GAZ ET COMPTES DIFFÉRÉS D'EGDCALCUL DE LA RÉCUPÉRATION NETTE (DU REMBOURSEMENT NET) PAR TYPE DE CLIENT

PÉRIODE DE RÉFÉRENCE: 2009


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 Norm Ryckman North York, ON M2J 1P8 Director, Regulatory Affairs PO Box 650 Tel 416-753-6280 Scarborough ON M1 K 5E3 Fax 416-495-6072

Email [email protected]

VIA COURIER AND EMAIL

December 10, 2010

Ms. Kirsten Walli Board Secretary Ontario Energy Board 2300 Yonge Street, 27th 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.


• RP-2003-0203: The QRAM process was modified, under Issue 15.11 in the Settlement Proposal dated June 17, 2004, Exhibit N1, Tab 1, Schedule 1, pp. 56-58 of 59. The Board approved the entire Settlement Proposal on June 16, 2003; see transcript volume 1, paragraphs. 32 to 39.

• EB-2008-0106: The QRAM process was modified in the Board's Decision dated September 21, 2009 at pages 5, 16 and 22.

3. The particulars of the QRAM process are described, for ease of reference, in Appendix A to this Application. Pursuant to the Board's direction, the "Regulatory Framework" has further been modified to include procedures for processing cost claims and awards, if any.

Utility Price and Customer Impacts

4. Enbridge's utility price approved in EB-2010-0146 Final 2011 Rates is $204.190/103m3 ($5.418/GJ @ 37.69 MJ/m3

). 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

3prescribed methodology. The recalculated utility price is $192.600/103m($5.110/GJ @ 37.69 MJ/m3

) 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) ¢/m3

, on Western T-service it is 0.1553 ¢/m3 and on Ontario T-service it is 0.0682 ¢/m3

.


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: (416) 495-5499 Fax: (416) 495-6072 Electronic access: [email protected]

(2) Ms. Tania Persad Senior Legal Counsel, Regulatory .

Telephone: (416) 495-5891 Fax: (416) 495-5994 Electronic access: [email protected]

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-2010-0347 Exhibit 01-1 Tab 2 Schedule 1 Page 5 of 5

DATE: December 10, 2010

ENBRIDGE GAS DISTRIBUTION INC.

_~~~---l.......3..:.~~"':""'-::"""--=-------=:::: _Per:Norm Ryckman Director, Regulatory Affairs

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 rate-making 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 Board-approved 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


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


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 Board-approved 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 commodity-related 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.


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


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,


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 gasdistribution network for the transportation of an annual supply of natural gas to customers outside of theCompany'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 thefirm contract demand, upon the Company issuing a notice not less than 4 hours prior to the time at which suchcurtailment or discontinuance is to commence.

RATE:

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 14.7000 ¢/m³ Per cubic metre of gas delivered 1.1202 ¢/m³

Gas Supply Load Balancing Charge 0.5881 ¢/m³

Transportation Charge per cubic metre 4.5736 ¢/m³

December

Billing MonthJanuary

to

Rates per cubic metre assume an energy content of 37.69 MJ/m³.

Transportation Charge per cubic metre 4.5736 ¢/m

System Sales Gas Supply Charge per cubic metre 14.3123 ¢/m³ (If applicable)Buy/Sell Sales Gas Supply Charge per cubic metre 14.2900 ¢/m³ (If applicable)

DIRECT PURCHASE ARRANGEMENTS:

CURTAILMENT CREDIT:

1.10$ /m³

EFFECTIVE DATE: IMPLEMENTATION DATE: BOARD ORDER: REPLACING RATE EFFECTIVE: Page 1 of 2January 1, 2011 January 1, 2011 EB-2010-0347 January 1, 2011 Handbook 31

Rider "A" or Rider "B" shall be applicable to Applicants who enter into Direct Purchase Arrangements under thisRate Schedule.

Rates per cubic metre assume an energy content of 37.69 MJ/m³.

Rate for 4 hours of notice per cubic metre of Mean Daily Volume from December to March

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 Chargeis applicable to volumes of natural gas purchased from the Company. The volumes purchased shall bethe volumes delivered at the Point of Delivery less any volumes, which the Company does not own and arereceived at the Point of Acceptance for delivery to the Applicant at the Point of Delivery.

RATE NUMBER: 200

UNAUTHORIZED OVERRUN GAS RATE:

The third instance of such failure in any contract year may result in the Applicant orfeiting the right to be servedunder this Rate Schedule. In such case, service hereunder would cease, notwithstanding any Service Contractbetween the Company and the Applicant. Gas supply and/or transportation service would continue to beavailable to the Applicant pursuant to the provisions of the Company's Rate 6 until a Service Contract pursuant toanother applicable Rate Schedule was executed.

MINIMUM BILL:

In addition, if the Applicant is supplying its own gas requirements, the gas delivered by the Applicant during theperiod 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 nothave sufficient physical capacity under current operating conditions to accommodate the provision of firm serviceto existing interruptible locations.

When the Applicant takes Unauthorized Supply Overrun Gas, the Applicant shall purchase such gas at a rate of150% 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.

6.2414 ¢/m³

TERMS AND CONDITIONS OF SERVICE:

EFFECTIVE DATE:


The provisions of PARTS III and IV of the Company's HANDBOOK OF RATES AND DISTRIBUTION SERVICESapply, as contemplated therein, to service under this Rate Schedule.

To apply to bills rendered for gas consumed by customers on and after January 1, 2011 under Sales Service includingBuy/Sell Arrangements and Transportation Service. This rate schedule is effective January 1, 2011 and replaces theidentically numbered rate schedule that specifies implementation date, January 1, 2011 and that indicatesas the Board Order, EB-2010-0146, effective January 1, 2011.

In addition, if the Applicant is supplying its own gas requirements, the gas delivered by the Applicant during theperiod 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 nothave sufficient physical capacity under current operating conditions to accommodate the provision of firm serviceto existing interruptible locations.

Per cubic metre of Annual Volume Deficiency(See Terms and Conditions of Service):

When the Applicant takes Unauthorized Supply Overrun Gas, the Applicant shall purchase such gas at a rate of150% 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.

RIDER: A TRANSPORTATION SERVICE RIDER

APPLICABILITY:

This rider is applicable to any Applicant who enters into Gas Transportation Agreement with the Company under anyrate 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

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:

(FT)Firm Transportation

1.

i.

ii.

iii.

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.


Enbridge must act in a manner that maintains the integrity and reliability of the gas distribution systemand that respects the sanctity of contracts.

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;

The amount of turnback capacity that Enbridge otherwise may accommodate may be reduced to addressthe impact of stranded costs, other transitional costs or incremental gas costs resulting from the loss ofSTS capacity arising from any turnback request; and

The Company will accommodate TCPL FT capacity turnback requests from customers, butonly if it can do so in accordance with the following considerations:

RIDER: A

5. 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 effectiveJanuary 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.



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 toApril 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 theCompany's actual FT-WACOG price determined on a monthly basis in the manner approved by the Ontario EnergyBoard. 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 determinedmonthly based upon the actual FT-WACOG.

EFFECTIVE DATE:



RIDER: C GAS COST ADJUSTMENT RIDER

Western OntarioRate Class Sales Service Transportation Service Transportation Service

( ¢/m³ ) ( ¢/m³ ) ( ¢/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

The following adjustment is applicable to all gas sold or delivered during the period of January 1, 2011 to December 31, 2011.


The following adjustment is applicable to all gas sold or delivered during the period of January 1, 2011 to December 31, 2011.

RIDER: C

Western OntarioSales Transportation Transportation

Rate Class Service Service Service( ¢/m³ ) ( ¢/m³ ) ( ¢/m³ )

Rate 1 Commodity (2.1734)

Transportation 0.0871 0.0871

Load Balancing 0.0682 0.0682 0.0682

Total (2.0181) 0.1553 0.0682



Load Balancing 0.0650 0.0650 0.0650

Total (2.0128) 0.1521 0.0650



Load Balancing 0.0005 0.0005 0.0005

Total (3.2049) 0.0876 0.0005



Load Balancing 0.0650 0.0650 0.0650

Total (2.0128) 0.1521 0.0650



Load Balancing 0.0132 0.0132 0.0132

Total (3.1435) 0.1003 0.0132



Load Balancing 0.0044 0.0044 0.0044

Total (3.2028) 0.0915 0.0044



Load Balancing 0.0000 0.0000 0.0000

Total (3.4011) 0.0871 0.0000


RIDER: C

Western OntarioSales Transportation Transportation

Rate Class Service Service Service( ¢/m³ ) ( ¢/m³ ) ( ¢/m³ )



Load Balancing 0.0335 0.0335 0.0335

Total (2.4007) 0.1206 0.0335



Load Balancing 0.0190 0.0190 0.0190

Total (2.9226) 0.1061 0.0190



Load Balancing 0.0527 0.0527 0.0527

Total (2.0042) 0.1398 0.0527


RIDER: E REVENUE ADJUSTMENT RIDER

Western OntarioBundled Services Sales Transportation TransportationRate Class Service Service Service

( ¢/m³ ) ( ¢/m³ ) ( ¢/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

Unbundled Services DistributionRate Class Service

( ¢/ ³ )( ¢/m³ )

Rate 125 0.0000

Rate 300 0.0000


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 - 2 -

rate 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 - 3 -

2. 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 ($) 1,400,757.77 (1)

Liquidation du compte différé au 31 décembre 2009 -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 0.74 ¢/m3

Notes: (1) Correspond à la redevance annuelle au Fonds vert de Gazifère pour la période du 1er octobre 2010au 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 étéinclus 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.


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 legouvernement du Québec s'applique à tous les volumes de gaz livrés et vendus durant la période du 1er janvier au 31 décembre 2011.


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