Attachment C1 cover - docs2.cer-rec.gc.ca

Attachment C1 Alberta System Interim 2011 Rates

Contract Demand Quantity and Throughput

NOVA Gas Transmission Ltd. Attachment C1 Alberta System Interim 2011 Rates

Contract Demand Quantity and Throughput Page 1 of 10

1.0 CONTRACT DEMAND QUANTITY AND THROUGHPUT 1

1.1 OVERVIEW 2

In this Section, NGTL provides Contract Demand Quantity and Throughput information 3

for the purposes of determining the 2011 interim rates, tolls and charges. The following 4

flow chart outlines the interrelationship between Firm Transportation Contract Demand, 5

Annual Throughput, the Facilities Design Forecast, and rate determination. 6

Figure 1-1

MARKET ANALYSIS &ECONOMIC INDICATORS CUSTOMER REQUESTS

ANNUALTHROUGHPUT

CONTRACTDEMAND

FORECAST

DISTRIBUTION TOSERVICE RATE DETERMINATION

FACILITIESDESIGN

FORECAST



A forecast of Firm Transportation Contract Demand is used in the determination of Firm 1

Transportation rates for the Alberta System in 2011. Firm Transportation Contract 2

Demand is forecast through an assessment of customer requests for Firm Transportation 3

at Receipt and Delivery Points after consideration of contract renewals, current market 4

conditions and downstream pipeline expansions. The 2011 average Receipt Point 5

Contract Demand (which includes all Firm Services contracted at receipt points) is 6

forecast to be 237.5 106m3/d (8.38 Bcf/d). The 2011 average Group 1 Delivery Point 7

Contract Demand (which includes all Firm Services contracted at Group 1 Delivery 8

points) is forecast to be 6.23 PJ/d. The average Delivery Contract Demand at Group 2 9

locations is forecast to be 1.85 PJ/d. 10

Throughput is forecast through an assessment of market demand in all markets served by 11

Canadian gas, a projection of the available capacity, and flows on all interconnecting 12

downstream pipelines. Considerable input in this process is received from Alberta System 13

customers, downstream pipeline operators, industry associations, and the end-users of 14

Canadian gas to determine the annual throughput forecast. The 2011 average Annual 15

Throughput for the Alberta System is forecast to be 256.98 106m3/d (9.08 Bcf/d). 16

The forecasts of the 2011 Annual Throughput and Firm Transportation Contract Demand 17

are used in the determination of Interruptible Transportation service. The volume 18

flowing under Interruptible Transportation service is determined by taking the total 19

Annual Throughput, and subtracting the volume forecast to flow under Firm 20

Transportation service. Since not all Firm Transportation Contracts are fully utilized, 21

projected system load factors are applied to estimate the volume flowing under Firm 22

Transportation service. 23



1.2 FIRM TRANSPORTATION 1

There are two primary categories of Firm Transportation Contracts (Receipt and 2

Delivery) available on the Alberta System. Firm Transportation Receipt Point Contracts 3

refer to quantities contracted by customers under Firm Transportation agreements that 4

enter the Alberta System at receipt meter stations. Firm Transportation Delivery Point 5

Contracts refer to quantities contracted by customers under Firm Transportation 6

agreements that leave the Alberta System. 7

1.2.1 Firm Transportation Receipt Point Contract Demand 8

The Receipt Point Contract Demand forecast is determined after considering the total 9

quantity contracted by customers under Firm Transportation agreements, and adjustments 10

for any new and expiring Contract Demand forecast to occur during 2011. Quantities used 11

in the forecast are based on information available as of the end of October 2010. 12

The 2011 average Receipt Point Contract Demand, which is calculated as an average of 13

twelve monthly forecasts, is forecast to be 237.5 106m3/d (8.38 Bcf/d). Table 1.2-1 shows 14

a comparison of annual figures for 2009, 2010 and 2011. Table 1.2-2 includes the monthly 15

contract forecast used to calculate the 2011 average Receipt Point Contract Demand.16



Table 1.2-1 2009-2011 Firm Transportation Receipt Point Contract Demand

2009 2010 2011

Contract Demand Bcf/d 106m3/d Bcf/d 106m3/d Bcf/d 106m3/d

Average Monthly Receipt Point Contract Demand 8.4 238.7 8.2 231.7 8.4 237.5

Table 1.2-2

2011 Monthly Firm Transportation Receipt Point Contract Demand

Month Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Average

Bcf/d 8.37 8.31 8.36 8.17 8.34 8.47 8.49 8.49 8.47 8.43 8.28 8.43 8.38

106m3/d 237.1 235.4 236.9 231.4 236.3 239.8 240.6 240.5 239.9 238.7 234.4 238.8 237.5



1.2.2 Firm Transportation Delivery Point Contract Demand 1

Firm Delivery service is currently available at two mutually-exclusive groups of delivery 2

locations (Group 1 and Group 2). Group 1 delivery points are interconnection points with 3

major downstream pipeline systems. Group 2 delivery points are non-Group 1 delivery 4

points where the customer elects to contract for the standard delivery service attributes. 5

Upon the integration of the ATCO Pipelines system and the Alberta System, Firm Delivery 6

service will be also available at a third mutually-exclusive group of delivery locations 7

(Group 3 locations). Group 3 locations will be non-Group 1 points where the customer elects 8

to contract for premium service attributes offered at a premium price. 9

Group 1 and Group 2 Firm Delivery Contract Demand is determined after considering the 10

total quantity signed by customers under Firm Transportation agreements for the 2010/11 11

and 2011/12 Gas Years, and adjustments for any new and expiring Contract Demand 12

forecast to occur during 2011. A breakdown of the total 2011 Group 1 Contract Demand of 13

6.23 PJ/d is shown in Table 1.2-3. Figures are also included for 2009 and 2010. The total 14

2011 Group 2 Contract Demand of 1.85 PJ/d is also shown in Table 1.2-3. The monthly 15

contract forecast used to calculate the 2011 average Group 1 and Group 2 Delivery Point 16

Contract Demand forecast is shown in Table 1.2-4. 17



Table 1.2-3 1 2009-2011 Firm Transportation Delivery Point Contract Demand

(PJ/d)

2009 Actual

2010 Estimate 4

2011 Forecast

Group 1

Empress 3.67 3.00 2.59

McNeill 1.11 1.37 1.33

Alberta/B.C. 2.48 2.40 2.31

Total Group 1 2 7.26 6.77 6.23

Total Group 2 3 N/A 1.95 1.85

1. Numbers may not add due to rounding. 2. Group 1 includes FT-D, FT-DW, LRS and STFT. 3. Group 2 includes FT-D and FT-P. 4. As estimated for 2010 Final Rates.

Table 1.2-4

2011 Monthly Firm Transportation Delivery Point Contract Demand (PJ/d)

Month Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Average

Group 1 7.22 7.16 6.16 5.76 5.45 5.73 6.29 6.36 6.26 6.11 5.64 6.64 6.23

Group 2 1.77 1.76 1.78 1.78 1.88 1.88 1.89 1.89 1.89 1.91 1.87 1.87 1.85



1.3 ANNUAL THROUGHPUT 1

1.3.1 Background 2

NGTL delivers gas to markets within the Western Canada Sedimentary Basin (“WCSB” or 3

“Basin”) and to major downstream pipelines that connect to other Canadian and United 4

States markets outside the Basin (Group 1 locations), as described below: 5

• Empress border, which connects with TransCanada’s Mainline system and supplies 6

gas to Canadian markets east of Alberta, the U.S. Midwest and U.S. Northeast 7

markets; 8

• McNeill border, which connects with Foothills Pipe Lines (Sask.) Ltd., which, in 9

turn, connects to Northern Border Pipeline Company and supplies the U.S. Midwest 10

market; 11

• Alberta-BC border, which connects with Foothills Pipe Lines (South B.C.) Ltd. and 12

supplies southern B.C. markets, and the Pacific Northwest and California markets 13

through TransCanada PipeLines Limited’s Gas Transmission Northwest (“GTN”) 14

pipeline system; 15

• Gordondale and Boundary Lake borders, which connect with the Spectra Energy’s 16

Westcoast System and supply the British Columbia and Pacific Northwest markets. 17

NGTL’s throughput forecast to these markets is based on economic growth assumptions 18

in Canada and the United States and an analysis of the aggregate supply, competition for 19

supply with other pipelines, gas market share expectations, taking into account customer 20

delivery contracts, downstream pipeline capacity, and competitiveness of Canadian gas 21

versus other sources of gas. 22



1.3.2 Throughput by Alberta System Delivery Point 1

The following table summarizes the Annual Throughput forecast for the Alberta System by 2

Delivery Point. Total Alberta System deliveries are forecast as illustrated in the following 3

table. 4

Table 1.3-11

Alberta System Throughput Forecast

2009 Actual

2010 Estimate

2011 Forecast

Group 1 Bcf 109m3 Bcf 109m3 Bcf 109m3

Empress 1,391 39.4 1,045 29.6 993 28.1

McNeill 494 14.0 704 19.9 611 17.3

Alberta/B.C. 712 20.2 732 20.7 660 18.7

Sub Total - Group 1 2,597 73.6 2,481 70.2 2,264 64.1

Other delivery Throughput 2 944 26.8 933 26.4 1,049 29.6

Total System 3,541 100.4 3,414 96.7 3,314 93.8

1. Numbers may not add due to rounding. 2. Includes volumes at Group 2 locations, Extraction, Taps and Fuel.

The 2011 throughput at Group 1 Delivery Points is forecast to decrease by 8.8 % from the 5

estimate for 2010, while throughput at the remaining delivery points is forecast to increase 6

by 12.4 %. The 2011 total system Annual Throughput is forecast to decrease by 2.9 % from 7

the estimate for 2010. 8



1.3.3 Distribution of 2011 Annual Throughput to Services 1

Annual throughput is made up of gas volumes flowing under the following transportation 2

services: 3

• Receipt Services (FT-R, FT-RN, IT-R); 4

• Delivery Services (FT-D at Group 1 and Group 2 locations, FT-DW, STFT, IT-D); and 5

• Other Transportation Services (LRS, LRS-2, LRS-3, FT-P). 6

The various Firm and Interruptible service options available to customers combined with 7

market volatility make it difficult to accurately forecast the utilization of these services. The 8

forecast distribution of throughput by service type shown in Tables 1.3-2 and 1.3-3 is based 9

upon historical use, trend analysis, and NGTL’s judgment of its customers’ use of these 10

services. The throughput numbers shown below correspond to the 2011 calendar year. 11



Table 1.3-21

Throughput Service Category Bcf 109m3 Percent of Annual Throughput

Firm Transportation Receipts 2 2,418 68.5 73.0%

Interruptible Transportation Receipts 514 14.6 15.5%

Other Transportation Services 3 405 11.5 12.2%

Total Services 3,337 94.5 100.7%

Net Receipts from Storage (23) (0.7) -0.7%

Total Throughput 3,314 93.9 100%

1. Numbers may not add due to rounding2. Includes FT-R and FT-RN3. Includes LRS, LRS-2, LRS-3 and FT-P

2011 Receipt Throughput by Service

Table 1.3-31

Throughput Service Category PJ 109m3 Percent of Annual Throughput

Firm Transportation Deliveries - Group 1 2 1,996 52.8 56.2%

Firm Transportation Deliveries - non-Group 1 3 658 17.4 18.5%

Interruptible Transportation Deliveries 4 440 11.6 12.4%

Other Transportation Services 5 434 11.5 12.2%

Total Delivery Services 3,528 93.3 99.4%

Fuel 20 0.5 0.6%

Total Throughput 3,548 93.9 100%

1. Numbers may not add due to rounding2. Includes FT-D, STFT and FT-DW deliveries at Group 1 locations3. Includes FT-D deliveries at Group 2 locations, Extraction and Taps4. Volumes are net of Alternate Access5. Includes LRS, LRS-2, LRS-3 and FT-P

2011 Delivery Throughput by Service


2011 Illustrative Rate Calculation

2011 Interim Rates (Fully Transitioned) - Illustrative Calculation

TOTAL REVENUE REQUIREMENT $Million $1,079.6

MINUSNON TRANSPORTATION REVENUE $Million

OS $1.0PTS $1.4CO2 $5.5

Total $8.0

EQUALS

TRANSPORTATION REVENUE REQUIREMENT $Million $1,071.6

MINUSFULL PATH TRANSPORTATION REVENUE (Bcf/d) (106m3/d) $Million

LRS REVENUELRS-1 0.61 17.22 $44.6LRS-2 0.05 1.33 $0.8LRS-3 0.05 1.41 $2.3Total 0.70 19.96 $47.7

FT-P 0.41 11.48 $30.6Total $78.3

EQUALS

NET TRANSPORTATION REVENUE REQUIREMENT $Million $993.4

MINUSMETERING REVENUE (TJ/d) (Bcf/d) (106m3/d) ($/GJ/d) $/Mcf/d $/103m3/d $Million

Receipt 8.03 227.57 0.024 0.858 $71.3Delivery 8,086 7.55 213.92 0.006 0.007 0.229 $17.9Total $89.2

EQUALS

NET TRANSMISSION REVENUE REQUIREMENT $Million $904.2

ALLOCATION OF TRANSMISSION ALLOCATION OF TRANSMISSION AND METERING COSTS TO RECEIPT AND METERING COSTS TO DELIVERY

RECEIPT REVENUE REQUIREMENT DELIVERY REVENUE REQUIREMENT$Million $Million

Transmission 50% $452.1 Transmission 50% $452.1Metering (Receipt) $71.3 Metering (Delivery) $17.9

Total $523.4 Total $470.0

MINUS MINUS(Bcf/d) (106m3/d) $Million (Bcf/d) (TJ/d) $Million

FT-DW 0.01 14 $1.1FT-RN 0.04 1.05 $2.9 STFT 2.35 2519 $174.2IT-R 1.41 39.91 $88.1 IT-D 1.13 1206 $60.6Total $91.0 Total $235.9

EQUALS EQUALS$Million $Million

FT-R Revenue Requirement $432.4 FT-D Revenue Requirement $234.2

ALLOCATED TO EACH ALLOCATED TO FT-DRECEIPT POINT SERVICES

(Bcf/d) (106m3/d)3 Year Rate

$/Mcf/d $Million (TJ/d)Metering

$/GJ/dTransmission Rate $/GJ/d

3 Year Rate $GJ/d $Million

FT-R (Avg) 7.25 205.26 0.163 $432.4 FT-D1 2,946 0.006 0.170 0.176 $189.8FT-D2 1,414 0.006 0.080 0.086 $44.4

Floor Price 0.083 (-8 cents) Total $234.2Ceiling Price 0.243 (+8 cents)

EFFECTIVE RATES EFFECTIVE RATES

FT-R Average Price ($/103m3/mo) FT-D Average Price ($/GJ/mo) FT-D1 FT-D21 Year Receipt 184.32 1 Year Delivery 5.65 2.763 Year Receipt 175.54 3 Year Delivery 5.37 2.625 Year Receipt 166.76 5 Year Delivery 5.09 2.48


Attachment C3 Alberta System Interim 2011 Rates Transition Mechanism Calculation

Summary of Distance of Haul Results

Transition Mechanism (Year 2)

Point Specific / Service Rates 2010 Final 2011

Fully Transitioned Year 2 Transition mechanism

2011Year 2 Transition

3 yr term - Price Point "Y"


1 yr term - Price Point "Z"Delivery 1 yr term- ($/GJ/mth)

40% of differenceFT-D Group 1 deliveries

Empress 0.188 0.180 0.188+ (0.18 - 0.188) * 40% = 0.185 5.92McNeill 0.188 0.180 0.188+ (0.18 - 0.188) * 40% = 0.185 5.92ABC Border 0.187 0.175 0.187+ (0.175 - 0.187) * 40% = 0.182 5.84Boundary Lake 0.168 0.086 0.168+ (0.086 - 0.168) * 40% = 0.135 4.32Gordondale 0.168 0.086 0.168+ (0.086 - 0.168) * 40% = 0.135 4.32

FT-D1 Average 0.188 0.176 0.188+ (0.176 - 0.188) * 40% = 0.183 5.87

FT-D Group 2 deliveries Alberta Montana 0.168 0.086 0.168+ (0.086 - 0.168) * 40% = 0.135 4.32Unity 0.168 0.086 0.168+ (0.086 - 0.168) * 40% = 0.135 4.32Cold Lake 0.168 0.086 0.168+ (0.086 - 0.168) * 40% = 0.135 4.32All Other Points 0.030 0.086 0.03+ (0.086 - 0.03) * 40% = 0.053 1.69

Point Specific / Service Rates 2010 Final 2011

Fully Transitioned Year 2 Transition mechanism


3 yr term - Price Point "B"


3 yr term - Price Point "B"Receipt 3 yr term - ($/103m3/mth)

FT-R Avg 1 0.193 0.163 Adjusted to account for delivery 0.168 179.99service transition.

1. Receipt Services (FT-R, FT-RN, FT-P, IT-R, LRS, LRS-2 and LRS-3) subject to the Mainline Surcharge of $0.04/Mcfd ($1.43/10 3m3/d).

2009 Distance of Haul information

Group 1 deliveries: DOH (Km) BOUNDARY LK BDR -EAST GATE 561GORDONDALE BORDER -WEST GATE 544

Group 2 deliveries 258

* FT-D Service at Group 3 Delivery Points not available until the Integration Effective Date.

3 yr term - ($/GJ/d)

3 yr term - ($/mcf/d)

2011 Interim Rates


NOVA Gas Transmission Ltd. Table of Rates, Tolls and Charges Page 1 of 1

Effective Date: Jan 1, 2011

1. Service under Rate Schedules FT-R, FT-RN, FT-P, IT-R, LRS, LRS-2 and LRS-3 subject to the Mainline Surcharge of $1.43/103m3/d. 2. Rate for all Group 2 Delivery Points with the exception of Alberta-Montana, Cold Lake and Unity. 3. FT-D Service at Group 3 Delivery Points not available until the Integration Effective Date.

Service Rates, Tolls and Charges

1. Rate Schedule FT-R1 Refer to Attachment “1” for applicable FT-R Demand Rate per month based on a three year term (Price Point “B”) & Surcharge for each Receipt Point Average Firm Service Receipt Price (AFSRP) $ 179.99/103m3

2. Rate Schedule FT-RN1 Refer to Attachment “1” for applicable FT-RN Demand Rate per month & Surcharge for each Receipt Point

3. Rate Schedule FT-D Refer to Attachment “2” for applicable FT-D Demand Rate per month based on a one year term (Price Point “Z”) & Surcharge for each Group 1 or Group 2 Delivery Point. Average FT-D Demand Rate for Group 1 Delivery Points $ 5.87/GJ FT-D Demand Rate for Group 2 Delivery Points 2 $ 1.69/GJ FT-D Demand Rate for Group 3 Delivery Points 3 N/A

4. Rate Schedule STFT STFT Bid Price = Minimum of 100% of the applicable FT-D Demand Rate based on a one year term (Price Point “Z”) for each Group 1 Delivery Point

5. Rate Schedule FT-DW FT-DW Bid Price = Minimum of 125% of the applicable FT-D Demand Rate based on a three year term (Price Point “Y”) for each Group 1 Delivery Point

6. Rate Schedule FT-P1 Refer to Attachment “3” for applicable FT-P Demand Rate per month 7. Rate Schedule LRS1 Contract Term Effective LRS Rate ($/103m3/day)

1-5 years 10.64 6-10 years 8.89 15 years 7.97 20 years 7.08

8. Rate Schedule LRS-21 LRS-2 Rate per month $ 50,000 9. Rate Schedule LRS-31 LRS-3 Demand Rate per month $ 129.55/103m3 10. Rate Schedule IT-R1 Refer to Attachment “1” for applicable IT-R Rate for each Receipt Point 11. Rate Schedule IT-D Refer to Attachment “2” for applicable IT-D Rate for each Delivery Point

12. Rate Schedule FCS The FCS Charge is determined in accordance with Attachment “1” to the applicable Schedule of Service

13. Rate Schedule PT Schedule No PT Rate PT Gas Rate . 9006-01000-0 $ 60.50/d 1.0 103m3/d 9009-01001-1 $ 660.00/d 50.0 103m3/d Schedule No. Charge

2010416547 $ 24.00 / month2010416543 $ 7.00 / month2010416549 $ 63.00 / month2010416546 $ 5.00 / month2010416548 $ 1.00 / month2010416540 $ 42.00 / month2010416550 $ 96.00 / month2010416545 $ 1,688.00 / month2010418000 $ 151.00 / month2010416551 $ 46.00 / month2010417322 $ 153.00 / month2010416544 $ 79.00 / month2010433424 $ 36.00 / month2010416541 $ 209.00 / month2010418777 $ 209.00 / month2010418778 $ 350.00 / month2003004522 $ 83,333.00 / month

14. Rate Schedule OS

15. Rate Schedule CO2 Tier 1 2 3

CO2 Rate ($/103m3) 505.25 399.89 261.29


NOVA Gas Transmission Ltd. Attachment 1Table of Rates, Tolls and Charges

Page 1 of 20

Receipt Point

NumberReceipt Point Name

FT-R Demand Rate per Month

Price Point "B"($/103m3)

FT-RN Demand Rateper Month($/103m3)

IT-R Rateper Day

($/103m3)

1337 ABEE 265.89 292.48 10.051631 ACADIA EAST 124.19 136.61 4.701613 ACADIA NORTH 124.88 137.37 4.721424 ACADIA VALLEY 180.02 198.02 6.811890 ACADIA VALLEY WEST 94.10 103.51 3.561351 AECO A 94.10 103.51 3.561426 AECO H 94.10 103.51 3.561473 AECO I 94.10 103.51 3.563880 AECO INTERCONNECTION 94.10 103.51 3.561526 AKUINU RIVER 265.89 292.48 10.051681 AKUINU RIVER W. 265.89 292.48 10.053868 ALBERTA MONTANA BORDER 97.45 107.20 3.682000 ALBERTA-B.C. BDR (CHART ACCOUNTING) 94.10 103.51 3.561588 ALBRIGHT 215.39 236.93 8.142109 ALDER FLATS 110.12 121.13 4.162200 ALDER FLATS S. 108.19 119.01 4.091075 ALDERSON 94.10 103.51 3.561208 ALDERSON NORTH 94.10 103.51 3.561103 ALDERSON SOUTH 94.10 103.51 3.565026 ALGAR LAKE 265.89 292.48 10.051851 AMISK SOUTH 242.85 267.14 9.181469 ANDREW 171.70 188.87 6.491573 ANSELL 139.05 152.96 5.262136 ANTE CREEK S. 265.89 292.48 10.051567 ARMENA 265.89 292.48 10.051770 ARMSTRONG LAKE 265.89 292.48 10.052708 ASSUMPTION 265.89 292.48 10.052734 ASSUMPTION #2 265.89 292.48 10.051326 ATHABASCA 255.59 281.15 9.661368 ATHABASCA EAST 244.13 268.54 9.231009 ATLEE-BUFFALO 94.10 103.51 3.561116 ATLEE-BUFFALO E 94.10 103.51 3.561098 ATLEE-BUFFALO S 94.10 103.51 3.561297 ATMORE 229.41 252.35 8.671792 ATUSIS CREEK E 94.10 103.51 3.563943 ATUSIS CREEK INTERCONNECTION 94.10 103.51 3.561275 BADGER EAST 94.10 103.51 3.561649 BADGER NORTH 102.00 112.20 3.861782 BAILEYS BOTTOM 218.59 240.45 8.262744 BALLATER #2 265.89 292.48 10.051100 BANTRY 94.10 103.51 3.561296 BANTRY N.E. 94.10 103.51 3.561181 BANTRY N.W. 94.10 103.51 3.561122 BANTRY NORTH 94.10 103.51 3.561398 BAPTISTE 262.06 288.27 9.911339 BAPTISTE SOUTH 265.89 292.48 10.051497 BARICH 265.89 292.48 10.051329 BASHAW 122.93 135.22 4.651393 BASHAW B 122.97 135.27 4.651330 BASSANO SOUTH 101.22 111.34 3.831794 BASSANO SOUTH 2 101.34 111.47 3.832761 BASSET LAKE 265.89 292.48 10.05

TARIFF Effective: January 1, 2011



Page 2 of 20

Receipt Point





IT-R Rateper Day

($/103m3)

2085 BASSET LAKE S. 265.89 292.48 10.052066 BASSET LAKE W. 265.89 292.48 10.051197 BAXTER LAKE 265.89 292.48 10.051334 BAXTER LAKE B 265.89 292.48 10.051382 BAXTER LAKE NW 265.89 292.48 10.051231 BAXTER LAKE S. 265.89 292.48 10.051198 BAXTER LAKE W. 265.89 292.48 10.052143 BAY TREE 265.89 292.48 10.052222 BEAR CANYON W. 251.27 276.40 9.502132 BEAR RIVER 265.89 292.48 10.052186 BEAR RIVER WEST 265.89 292.48 10.051459 BEAUVALLON 265.89 292.48 10.051089 BELLIS 186.03 204.63 7.031675 BELLIS SOUTH 178.47 196.32 6.752043 BELLOY 265.89 292.48 10.052105 BELLOY WEST 222.03 244.23 8.391720 BELTZ LAKE 140.64 154.70 5.321264 BENALTO WEST 134.64 148.10 5.092177 BENBOW SOUTH 185.81 204.39 7.031261 BENTLEY 119.14 131.05 4.501274 BENTON WEST 106.91 117.60 4.041604 BERRY CREEK S. 123.47 135.82 4.671085 BERRY-CAROLSIDE 94.10 103.51 3.561157 BIG BEND 265.89 292.48 10.051225 BIG BEND EAST 265.89 292.48 10.053933 BIG EDDY INTERCONNECTION 135.02 148.52 5.102175 BIG PRAIRIE 265.89 292.48 10.051870 BIG VALLEY 218.84 240.72 8.271835 BIGKNIFE CREEK 118.26 130.09 4.472176 BIGORAY RIVER 166.22 182.84 6.282231 BIGSTONE EAST 192.12 211.33 7.262232 BIGSTONE EAST B 192.21 211.43 7.271002 BINDLOSS N. #1 94.10 103.51 3.561001 BINDLOSS SOUTH 94.10 103.51 3.561474 BINDLOSS WEST 160.85 176.94 6.082150 BINGLEY 97.49 107.24 3.692256 BISON LAKE 265.89 292.48 10.053887 BITTERN LAKE INTERCONNECTION 265.89 292.48 10.051616 BLOOD IND CK E. 96.89 106.58 3.661505 BLOOD INDIAN CK 94.10 103.51 3.561779 BLOOR LAKE 203.92 224.31 7.711511 BLUE JAY 265.89 292.48 10.052704 BLUE RAPIDS 116.74 128.41 4.413471 BLUE RIDGE E SL 208.40 229.24 7.882119 BLUEBERRY HILL 265.89 292.48 10.051242 BODO WEST 171.64 188.80 6.492773 BOGGY HALL 114.08 125.49 4.311590 BOHN LAKE 265.89 292.48 10.055012 BOIVIN CREEK 265.89 292.48 10.051227 BOLLOQUE 265.89 292.48 10.051778 BOLLOQUE #2 265.89 292.48 10.051290 BOLLOQUE SOUTH 265.89 292.48 10.05




Page 3 of 20

Receipt Point





IT-R Rateper Day

($/103m3)

5103 BONANZA 243.74 268.11 9.221401 BONAR WEST 94.10 103.51 3.561660 BONNYVILLE 265.89 292.48 10.052709 BOOTIS HILL 265.89 292.48 10.052117 BOTHA 265.89 292.48 10.052182 BOTHA EAST 265.89 292.48 10.052217 BOTHA WEST 265.89 292.48 10.052220 BOULDER CREEK 265.89 292.48 10.053001 BOUNDARY LAKE S 252.90 278.19 9.563002 BOUNDARY LK BDR 254.91 280.40 9.641318 BOWELL SOUTH 110.67 121.74 4.181849 BOWELL SOUTH #2 110.67 121.74 4.181216 BOWMANTON 122.69 134.96 4.641842 BOWMANTON EAST 111.29 122.42 4.211204 BOWMANTON SOUTH 102.36 112.60 3.871237 BOWMANTON WEST 196.74 216.41 7.442138 BOYER EAST 265.89 292.48 10.051703 BOYLE WEST 200.79 220.87 7.592799 BRAINARD LAKE 243.54 267.89 9.211947 BRAZEAU - BRAZEAU EAST SUMMARY 129.99 142.99 4.911096 BRAZEAU SOUTH 124.46 136.91 4.711619 BRIGGS 113.73 125.10 4.302721 BROWNVALE NORTH 214.77 236.25 8.122364 BROWNVALE SALES 260.46 286.51 9.851168 BRUCE 123.83 136.21 4.681215 BRUCE NORTH 198.58 218.44 7.511409 BULLPOUND 117.14 128.85 4.431350 BULLPOUND SOUTH 198.04 217.84 7.491555 BULLSHEAD 164.01 180.41 6.206004 BURNT PINE 265.89 292.48 10.052118 BURNT RIVER 220.50 242.55 8.342032 BURNT TIMBER 100.59 110.65 3.802181 BUTTE 94.10 103.51 3.561561 BYEMOOR 140.04 154.04 5.291725 CADOGAN 265.89 292.48 10.052221 CADOTTE RIVER 265.89 292.48 10.052738 CALAIS 201.89 222.08 7.631373 CALLING LAKE 265.89 292.48 10.051522 CALLING LAKE E. 265.89 292.48 10.056019 CALLING LAKE SE (SIMMONS) 247.73 272.50 9.371443 CALLING LAKE W. 204.65 225.12 7.741676 CALLING LK N. 232.87 256.16 8.801387 CALLING LK S. 241.89 266.08 9.152743 CALLUM CREEK 94.10 103.51 3.561651 CAMROSE CREEK 265.89 292.48 10.051805 CANOE LAKE 265.89 292.48 10.053866 CARBON INTERCONNECTION 94.10 103.51 3.561622 CARBON WEST 94.10 103.51 3.561692 CARIBOU LAKE 265.89 292.48 10.052113 CAROLINE NORTH 94.10 103.51 3.563893 CARROT CREEK #3893 INTERCONNECTION 134.20 147.62 5.071840 CARSELAND RECEIPT 94.10 103.51 3.56




Page 4 of 20

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IT-R Rateper Day

($/103m3)

2018 CARSON CREEK 215.23 236.75 8.142188 CARSON CREEK E. 259.52 285.47 9.813330 CARSTAIRS INTERCONNECTION 94.10 103.51 3.561491 CASLAN 265.89 292.48 10.051492 CASLAN EAST 265.89 292.48 10.051315 CASSILS 110.44 121.48 4.181397 CASTOR 163.84 180.22 6.192786 CATTAIL LK SOUTH 187.51 206.26 7.091737 CAVALIER 127.24 139.96 4.811228 CAVENDISH SOUTH 94.10 103.51 3.562768 CECILIA 147.58 162.34 5.581863 CESSFD-BURF W#2 108.60 119.46 4.111025 CESSFORD EAST 94.10 103.51 3.561152 CESSFORD N.E. 94.10 103.51 3.561145 CESSFORD NORTH 94.10 103.51 3.561312 CESSFORD SOUTH 94.10 103.51 3.561086 CESSFORD W GAGE 94.10 103.51 3.561004 CESSFORD WARDLO 94.10 103.51 3.561012 CESSFORD WEST 94.10 103.51 3.561060 CESSFORD-BUR #2 94.52 103.97 3.571027 CESSFORD-BURF W 108.60 119.46 4.113907 CHANCELLOR INTERCONNECTION 94.10 103.51 3.561876 CHAPEL ROCK 94.10 103.51 3.561485 CHARD 265.89 292.48 10.051196 CHAUVIN 265.89 292.48 10.051666 CHEECHAM 265.89 292.48 10.051708 CHELSEA CREEK 265.89 292.48 10.051680 CHERRY GROVE E. 265.89 292.48 10.052705 CHESTER CREEK 265.89 292.48 10.052789 CHICKADEE CK #2 187.22 205.94 7.082286 CHICKADEE CK W. 265.89 292.48 10.051034 CHIGWELL 168.38 185.22 6.371040 CHIGWELL EAST 158.49 174.34 5.992108 CHINCHAGA 265.89 292.48 10.052266 CHINCHAGA WEST 265.89 292.48 10.051221 CHINOOK-CEREAL 138.29 152.12 5.235409 CHIP LAKE 133.57 146.93 5.053885 CHIP LAKE JCT 133.46 146.81 5.051609 CHISHOLM MILL W 265.89 292.48 10.051434 CHISHOLM MILLS 265.89 292.48 10.051322 CHOICE 265.89 292.48 10.051323 CHOICE B 265.89 292.48 10.051712 CHRISTINA LAKE 265.89 292.48 10.051679 CHUMP LAKE 265.89 292.48 10.051535 CLANDONALD 265.89 292.48 10.052070 CLARK LAKE 167.12 183.83 6.322063 CLEAR HILLS 265.89 292.48 10.052250 CLEAR HILLS N. 228.14 250.95 8.632764 CLEAR PRAIRIE 265.89 292.48 10.053008 CLEARDALE 265.89 292.48 10.051454 CLYDE 265.89 292.48 10.051803 CLYDE NORTH 265.89 292.48 10.05




Page 5 of 20

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IT-R Rateper Day

($/103m3)

6007 CLYDEN 265.89 292.48 10.053883 COALDALE JCT 94.10 103.51 3.565402 COALDALE S. B 116.77 128.45 4.413884 COALDALE S. JCT 94.10 103.51 3.561612 COATES LAKE 231.40 254.54 8.752735 CODESA 265.89 292.48 10.052152 CODNER 139.81 153.79 5.291417 COLD LAKE BDR 265.89 292.48 10.052003 COLEMAN 94.10 103.51 3.563052 COLEMAN SALES 94.10 103.51 3.562794 COLT 149.62 164.58 5.661624 CONKLIN 265.89 292.48 10.051634 CONKLIN WEST 265.89 292.48 10.051713 CONN LAKE 265.89 292.48 10.051635 CONTRACOSTA E. 225.72 248.29 8.531614 CONTRACOSTA LK 167.73 184.50 6.342736 COPTON CREEK 240.02 264.02 9.071763 CORNER LAKE #2 265.89 292.48 10.051697 CORRIGALL LAKE 265.89 292.48 10.051667 COTTONWOOD CRK 265.89 292.48 10.051028 COUNTESS 94.10 103.51 3.561015 COUNTESS MAKEPEACE 94.55 104.01 3.572296 COUNTESS S. #2 94.10 103.51 3.561287 COUNTESS WEST 149.22 164.14 5.641963 COUSINS B & C SALES (SUMMARY) 133.47 146.82 5.051433 COUSINS WEST 133.76 147.14 5.061088 CRAIGEND 258.50 284.35 9.771112 CRAIGEND EAST 258.50 284.35 9.771320 CRAIGEND NORTH 265.89 292.48 10.051148 CRAIGEND SOUTH 265.89 292.48 10.051541 CRAIGMYLE 247.03 271.73 9.341583 CRAIGMYLE EAST 265.89 292.48 10.051686 CRAMMOND 94.10 103.51 3.562749 CRANBERRY LK #2 265.89 292.48 10.053105 CRANBERRY LK SL 265.89 292.48 10.051701 CROOKED LK S. 176.54 194.19 6.672724 CROOKED LK W. 163.51 179.86 6.182008 CROSSFIELD 94.10 103.51 3.565101 CROSSFIELD E #3 94.10 103.51 3.563897 CROSSFIELD EAST INTERCONNECTION 94.10 103.51 3.562017 CROSSFIELD WEST 94.10 103.51 3.561773 CROW LAKE SOUTH 265.89 292.48 10.052731 CROWELL 265.89 292.48 10.052718 CULP #2 265.89 292.48 10.051807 CULP NORTH 265.89 292.48 10.051489 CUTBANK RIVER 240.90 264.99 9.112209 CYNTHIA #2 121.95 134.15 4.611501 DAKIN 265.89 292.48 10.051738 DANCING LAKE 265.89 292.48 10.051279 DAPP EAST 265.89 292.48 10.052289 DARLING CREEK 265.89 292.48 10.051864 DAVEY LAKE 94.10 103.51 3.56




Page 6 of 20

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IT-R Rateper Day

($/103m3)

1529 DAYSLAND 130.36 143.40 4.932285 DEADRICK CREEK 97.85 107.64 3.702233 DEBOLT 262.20 288.42 9.911760 DECRENE EAST 265.89 292.48 10.051646 DECRENE NORTH 265.89 292.48 10.053888 DEEP VALLEY CREEK INTERCONNECTION 225.54 248.09 8.532244 DEEP VLLY CRK S 156.71 172.38 5.921539 DELIA 195.64 215.20 7.401476 DEMMITT 243.43 267.77 9.201734 DEVENISH SOUTH 265.89 292.48 10.051733 DEVENISH WEST 265.89 292.48 10.051793 DIAMOND CITY 143.36 157.70 5.421185 DISMAL CREEK 137.89 151.68 5.212210 DIXONVILLE N #2 226.03 248.63 8.552110 DIXONVILLE N. 265.89 292.48 10.052197 DOE CREEK 265.89 292.48 10.052712 DOE CREEK SOUTH 265.89 292.48 10.051892 DOE CREEK SOUTH #2 265.89 292.48 10.052776 DOIG RIVER 261.58 287.74 9.891147 DONALDA 233.82 257.20 8.841520 DONATVILLE 243.05 267.36 9.192139 DONNELLY 265.89 292.48 10.052254 DORIS CREEK N. 265.89 292.48 10.051236 DOROTHY 168.84 185.72 6.381818 DOWLING 94.10 103.51 3.562719 DREAU 265.89 292.48 10.051689 DROPOFF CREEK 265.89 292.48 10.051475 DUHAMEL 265.89 292.48 10.055022 DUNKIRK RIVER 265.89 292.48 10.051220 DUNMORE 145.93 160.52 5.522044 DUNVEGAN 236.61 260.27 8.952716 DUNVEGAN W. #2 265.89 292.48 10.052084 DUNVEGAN WEST 265.89 292.48 10.051877 DUVERNAY 183.56 201.92 6.943062 E. CALGARY B SL 94.10 103.51 3.562081 EAGLE HILL 134.16 147.58 5.072097 EAGLESHAM 200.06 220.07 7.562787 EAGLESHAM SOUTH 198.77 218.65 7.522007 EAST CALGARY 94.10 103.51 3.561568 EDBERG 213.88 235.27 8.091265 EDGERTON 265.89 292.48 10.051266 EDGERTON WEST 265.89 292.48 10.051064 EDSON 133.58 146.94 5.051213 EDWAND 208.27 229.10 7.871467 EDWAND SOUTH 196.52 216.17 7.432760 EKWAN 265.89 292.48 10.051715 ELINOR LAKE 265.89 292.48 10.051742 ELINOR LAKE E. 261.70 287.87 9.891558 ELK RIVER SOUTH 125.57 138.13 4.751615 ELMWORTH HIGH 197.30 217.03 7.461862 ELNORA EAST #2 220.79 242.87 8.351958 EMPRESS BORDER 94.10 103.51 3.56




Page 7 of 20

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IT-R Rateper Day

($/103m3)

1024 ENCHANT 113.95 125.35 4.311507 ENDIANG 94.10 103.51 3.561074 EQUITY 119.66 131.63 4.521359 EQUITY B 137.86 151.65 5.211586 EQUITY EAST 138.48 152.33 5.241232 ERSKINE NORTH 179.61 197.57 6.791746 ESTRIDGE LAKE 265.89 292.48 10.052049 ETA LAKE 140.10 154.11 5.301547 ETZIKOM A 265.89 292.48 10.051548 ETZIKOM B 265.89 292.48 10.051549 ETZIKOM C 265.89 292.48 10.051557 ETZIKOM D 265.89 292.48 10.051677 FAIRYDELL CREEK 265.89 292.48 10.053112 FALHER SALES 265.89 292.48 10.052729 FARIA 265.89 292.48 10.051891 FAWCETT R W #3 265.89 292.48 10.051375 FAWCETT RIVER 265.89 292.48 10.051389 FAWCETT RIVER E 265.89 292.48 10.051753 FAWCETT RVR N. 265.89 292.48 10.051438 FERINTOSH NORTH 265.89 292.48 10.051868 FERINTOSH SOUTH 237.08 260.79 8.961659 FERINTOSH WEST 265.89 292.48 10.052016 FERRIER 140.79 154.87 5.321101 FERRIER NORTH 124.24 136.66 4.702115 FERRIER SOUTH A 140.87 154.96 5.331111 FERRIER SOUTH B 135.80 149.38 5.131087 FIGURE LAKE 244.52 268.97 9.241300 FITZALLAN SOUTH 201.62 221.78 7.621095 FLAT LAKE 265.89 292.48 10.051302 FLAT LAKE NORTH 265.89 292.48 10.051394 FLATBUSH 265.89 292.48 10.051752 FLORENCE CREEK 265.89 292.48 10.051632 FOISY 201.97 222.17 7.642251 FONTAS RIVER 265.89 292.48 10.053304 FORESTBURG SLS 107.37 118.11 4.061376 FORSHEE 113.66 125.03 4.301602 FORT KENT 265.89 292.48 10.052199 FOULWATER CREEK 265.89 292.48 10.052103 FOURTH CREEK 265.89 292.48 10.052178 FOURTH CREEK S. 265.89 292.48 10.052198 FOURTH CREEK W. 265.89 292.48 10.052268 FRAKES FLATS 204.00 224.40 7.712772 FREEMAN RIVER 265.89 292.48 10.051875 GALT ISLAND 107.82 118.60 4.082078 GARRINGTON 101.08 111.19 3.822079 GARRINGTON EAST 127.46 140.21 4.821623 GATINE 94.10 103.51 3.561358 GAYFORD 94.10 103.51 3.561435 GEM SOUTH 94.10 103.51 3.561490 GEM WEST 94.10 103.51 3.561073 GHOSTPINE 98.92 108.81 3.741617 GHOSTPINE B 103.31 113.64 3.91




Page 8 of 20

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IT-R Rateper Day

($/103m3)

1037 GILBY #2 122.10 134.31 4.621084 GILBY SOUTH PAC 122.10 134.31 4.622037 GILBY WEST 142.56 156.82 5.392722 GILMORE LAKE 222.57 244.83 8.413894 GILT EDGE WEST INTERCONNECTION 265.89 292.48 10.051480 GLEICHEN 189.35 208.29 7.161456 GLENDON 265.89 292.48 10.052290 GODS LAKE 265.89 292.48 10.052031 GOLD CREEK 178.32 196.15 6.741452 GOODFARE 228.50 251.35 8.641504 GOODRIDGE 265.89 292.48 10.051783 GOODRIDGE NORTH 265.89 292.48 10.051798 GOOSEQUILL 228.57 251.43 8.641880 GOOSEQUILL WEST 118.53 130.38 4.483886 GORDONDALE BORDER 242.93 267.22 9.181560 GOUGH LAKE 95.45 105.00 3.611448 GRACE CREEK 135.20 148.72 5.112771 GRACE CREEK STH 115.54 127.09 4.371482 GRAHAM 265.89 292.48 10.051352 GRAINGER 94.10 103.51 3.562129 GRANADA 166.34 182.97 6.293424 GRANDE CENTRE S 265.89 292.48 10.055005 GRANOR 265.89 292.48 10.051093 GREENCOURT 227.10 249.81 8.591267 GREGORY 100.80 110.88 3.811365 GREGORY N.E. 94.10 103.51 3.561259 GREGORY WEST 94.10 103.51 3.565025 GREW LAKE 265.89 292.48 10.055028 GREW LK EAST 265.89 292.48 10.051647 GRIST LAKE 265.89 292.48 10.052770 GRIZZLY 179.90 197.89 6.805108 GROUNDBIRCH 262.77 289.05 9.931538 HACKETT 261.31 287.44 9.881722 HACKETT WEST 265.89 292.48 10.051576 HADDOCK 163.79 180.17 6.191589 HADDOCK NORTH 169.31 186.24 6.401636 HADDOCK SOUTH 195.71 215.28 7.402086 HAIG RIVER 265.89 292.48 10.052064 HAIG RIVER EAST 265.89 292.48 10.052127 HAIG RIVER N. 265.89 292.48 10.051230 HAIRY HILL 189.42 208.36 7.161391 HALKIRK 119.06 130.97 4.501834 HALKIRK NORTH#2 102.20 112.42 3.862797 HAMBURG 265.89 292.48 10.053915 HAMILTON LAKE SUMMARY 241.89 266.08 9.151291 HAMLIN 265.89 292.48 10.056003 HANGINGSTONE 265.89 292.48 10.051182 HANNA 94.10 103.51 3.561444 HARDISTY 234.07 257.48 8.851178 HARMATTAN EAST 94.10 103.51 3.561166 HARMATTAN-ELKTN 94.10 103.51 3.562145 HARO RIVER N. 265.89 292.48 10.05




Page 9 of 20

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IT-R Rateper Day

($/103m3)

2766 HARPER CREEK 218.48 240.33 8.261850 HARTELL SOUTH 94.10 103.51 3.561709 HASTINGS COULEE 164.29 180.72 6.211418 HATTIE LAKE N. 265.89 292.48 10.052126 HAY RIVER 265.89 292.48 10.052278 HAY RIVER SOUTH 265.89 292.48 10.051603 HAYS 205.33 225.86 7.762140 HEART RIVER 265.89 292.48 10.051439 HEISLER 108.90 119.79 4.121523 HELINA 265.89 292.48 10.052174 HENDERSON CK SE 265.89 292.48 10.052164 HENDERSON CREEK 265.89 292.48 10.051673 HERMIT LAKE 237.74 261.51 8.993611 HERMIT LAKE SLS 237.34 261.07 8.971866 HIGHLAND RANCH 131.50 144.65 4.971402 HILDA WEST 94.10 103.51 3.562059 HINES CREEK 265.89 292.48 10.052219 HINES CREEK W. 265.89 292.48 10.051161 HOLDEN 180.69 198.76 6.831528 HOOLE 265.89 292.48 10.051411 HORBURG 109.29 120.22 4.132047 HOTCHKISS 265.89 292.48 10.052065 HOTCHKISS EAST 265.89 292.48 10.052094 HOTCHKISS NE B 265.89 292.48 10.052095 HOTCHKISS NE C 265.89 292.48 10.052054 HOTCHKISS NORTH 265.89 292.48 10.052169 HOWARD CREEK E. 265.89 292.48 10.051207 HUDSON 171.28 188.41 6.481413 HUDSON WEST 138.66 152.53 5.241854 HUGHENDEN EAST 207.03 227.73 7.831859 HUMMOCK LAKE 108.47 119.32 4.102277 HUNT CREEK 265.89 292.48 10.052751 HUNT CREEK #2 265.89 292.48 10.051436 HUSSAR NORTH 94.10 103.51 3.561016 HUSSAR-CHANCELL 94.10 103.51 3.561142 HUXLEY 122.06 134.27 4.611591 HUXLEY EAST 241.80 265.98 9.141241 HYLO 265.89 292.48 10.051357 HYLO SOUTH 265.89 292.48 10.051479 HYTHE 238.17 261.99 9.001277 IDDESLEIGH S. 94.10 103.51 3.561678 INDIAN LAKE 142.39 156.63 5.381717 INDIAN LAKE #2 141.83 156.01 5.363857 INLAND SALES EXCHANGE 151.80 166.98 5.741525 INLAND SOUTH 151.16 166.28 5.721685 IPIATIK LAKE 265.89 292.48 10.051441 IRISH 265.89 292.48 10.051569 IROQUOIS CREEK 191.35 210.49 7.231201 IRVINE 162.69 178.96 6.151407 ISLAND LAKE 229.74 252.71 8.691700 ISLAND LAKE #2 229.67 252.64 8.681694 JACKFISH CREEK 265.89 292.48 10.05




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IT-R Rateper Day

($/103m3)

2723 JACKPOT CREEK 265.89 292.48 10.052146 JACKSON CREEK 101.40 111.54 3.833860 JANUARY CREEK INTERCONNECTION 142.15 156.37 5.371163 JARROW 258.77 284.65 9.781159 JARROW SOUTH 243.67 268.04 9.211281 JARROW WEST 263.71 290.08 9.971799 JARVIE NORTH 265.89 292.48 10.051886 JARVIS BAY 119.65 131.62 4.521143 JENNER EAST 94.10 103.51 3.561099 JENNER WEST 94.10 103.51 3.561385 JENNER WEST B 94.10 103.51 3.561167 JOFFRE 187.10 205.81 7.071878 JOFFRE EAST 147.02 161.72 5.563864 JOFFRE INTERCONNECTION 115.42 126.96 4.362267 JONES LAKE 224.20 246.62 8.482279 JONES LAKE #2 224.39 246.83 8.482272 JONES LAKE EAST 242.33 266.56 9.162241 JONES LAKE N. 259.75 285.73 9.822087 JOSEPHINE 265.89 292.48 10.052083 JOSEPHINE EAST 265.89 292.48 10.052022 JUDY CREEK 265.89 292.48 10.052036 JUMPING POUND W 94.10 103.51 3.561811 KAKWA 222.11 244.32 8.401462 KARR 173.12 190.43 6.552013 KAYBOB 193.27 212.60 7.312027 KAYBOB 11-36 190.86 209.95 7.222020 KAYBOB SOUTH 176.50 194.15 6.672035 KAYBOB SOUTH #3 149.43 164.37 5.652053 KEG RIVER 265.89 292.48 10.052068 KEG RIVER EAST 265.89 292.48 10.052216 KEG RIVER NORTH 265.89 292.48 10.051517 KEHIWIN 265.89 292.48 10.051224 KEHO LAKE 94.10 103.51 3.561775 KEHO LAKE NORTH 120.40 132.44 4.551882 KEIVERS LAKE 94.10 103.51 3.562748 KEMP RIVER 265.89 292.48 10.051483 KENT 265.89 292.48 10.052739 KEPPLER CREEK 265.89 292.48 10.051845 KERSEY 94.10 103.51 3.561879 KERSEY #2 94.10 103.51 3.561627 KETTLE RIVER 265.89 292.48 10.051668 KETTLE RIVER N. 265.89 292.48 10.052288 KIDNEY LAKE 265.89 292.48 10.051608 KIKINO 241.00 265.10 9.111772 KIKINO NORTH 208.61 229.47 7.891162 KILLAM 265.89 292.48 10.051298 KILLAM NORTH 265.89 292.48 10.051682 KINOSIS 265.89 292.48 10.051446 KIRBY 265.89 292.48 10.051727 KIRBY NORTH #2 265.89 292.48 10.052777 KOTCHO RIVER 265.89 292.48 10.052759 KSITUAN R E #2 265.89 292.48 10.05




Page 11 of 20

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IT-R Rateper Day

($/103m3)

2134 KSITUAN RIVER 265.89 292.48 10.051721 LAC LA BICHE 265.89 292.48 10.051860 LACOMBE LAKE 105.57 116.13 3.991718 LACOREY 265.89 292.48 10.052287 LAFOND CREEK 265.89 292.48 10.051210 LAKE NEWELL E. 140.71 154.78 5.321562 LAKEVIEW LAKE 102.39 112.63 3.871828 LAKEVIEW LAKE #2 102.25 112.48 3.872737 LALBY CREEK 265.89 292.48 10.051767 LAMERTON 173.59 190.95 6.561884 LAMERTON SOUTH 117.42 129.16 4.441887 LAMERTON#2 173.59 190.95 6.561206 LANFINE 110.74 121.81 4.191564 LARKSPUR 265.89 292.48 10.052223 LAST LAKE 235.39 258.93 8.902151 LASTHILL CREEK 105.89 116.48 4.002259 LATHROP CREEK 264.17 290.59 9.991874 LAVESTA 122.46 134.71 4.631132 LAVOY 194.05 213.46 7.341324 LAWRENCE LAKE 265.89 292.48 10.051695 LAWRENCE LAKE N 265.89 292.48 10.052040 LEAFLAND 183.44 201.78 6.941833 LEE LAKE 189.59 208.55 7.172179 LEEDALE 111.64 122.80 4.222249 LENNARD CREEK 265.89 292.48 10.051272 LEO 94.10 103.51 3.565003 LIEGE 265.89 292.48 10.051536 LINARIA 265.89 292.48 10.051857 LINDEN 94.10 103.51 3.561872 LITTLE BOW 94.10 103.51 3.561494 LITTLE SUNDANCE 135.98 149.58 5.142111 LOBSTICK 133.13 146.44 5.031465 LONE BUTTE 185.99 204.59 7.031069 LONE PINE CREEK 94.10 103.51 3.561139 LONE PINE SOUTH 94.10 103.51 3.561768 LONESOME LAKE 129.06 141.97 4.881630 LONG LAKE WEST 265.89 292.48 10.051366 LOUISIANA LAKE 133.59 146.95 5.051496 LOUSANA 218.80 240.68 8.272128 LOVET CREEK 265.89 292.48 10.051386 LUCKY LAKE 265.89 292.48 10.053058 LUNDBRECK-COWLEY 94.10 103.51 3.562774 MACINTOSH LAKE 234.75 258.23 8.885021 MACKAY RIVER 265.89 292.48 10.052780 MADDENVILLE 211.40 232.54 7.992702 MAHASKA 206.57 227.23 7.812700 MAHASKA WEST 171.27 188.40 6.481229 MAJESTIC 119.03 130.93 4.501419 MAKEPEACE NORTH 99.37 109.31 3.761873 MALMO 182.64 200.90 6.911719 MANATOKEN LAKE 263.55 289.91 9.962720 MANIR 256.18 281.80 9.69




Page 12 of 20

Receipt Point





IT-R Rateper Day

($/103m3)

1273 MAPLE GLEN 94.10 103.51 3.561572 MARLBORO 187.74 206.51 7.101663 MARLBORO EAST 187.94 206.73 7.112713 MARLOW CREEK 265.89 292.48 10.052762 MARSH HD CK W#2 151.91 167.10 5.742750 MARSH HEAD CK WEST 151.79 166.97 5.742228 MARSH HEAD CRK 171.88 189.07 6.501091 MARTEN HILLS 265.89 292.48 10.051672 MARTEN HILLS N. 265.89 292.48 10.051097 MARTEN HILLS S. 265.89 292.48 10.051769 MASTIN LAKE 255.37 280.91 9.661270 MATZHIWIN EAST 130.02 143.02 4.921284 MATZHIWIN N.E. 95.86 105.45 3.621379 MATZHIWIN SOUTH 94.10 103.51 3.561150 MATZHIWIN WEST 94.10 103.51 3.561514 MAUGHAN 265.89 292.48 10.051633 MAY HILL 265.89 292.48 10.052790 MAYBERNE 139.57 153.53 5.285109 MAYBERNE NO 2 139.57 153.53 5.282706 MCLEAN CREEK 265.89 292.48 10.052144 MCLENNAN 265.89 292.48 10.052710 MCMILLAN LAKE 265.89 292.48 10.056404 MCNEILL BORDER 94.10 103.51 3.561704 MEADOW CREEK 265.89 292.48 10.051707 MEADOW CREEK E. 265.89 292.48 10.051705 MEADOW CRK WEST 265.89 292.48 10.051338 MEANOOK 265.89 292.48 10.051017 MED HAT N. #1 94.10 103.51 3.561184 MED HAT N. ARCO 94.10 103.51 3.561325 MED HAT N. F 94.10 103.51 3.561205 MED HAT N.W. 94.10 103.51 3.561018 MED HAT S. #1 94.10 103.51 3.561043 MED HAT S. #2 94.10 103.51 3.561128 MED HAT S. #4 94.10 103.51 3.561172 MED HAT WEST 94.10 103.51 3.561186 MEDICINE HAT E. 98.51 108.36 3.721214 MEDICINE RVR A 250.62 275.68 9.482778 MEGA RIVER 265.89 292.48 10.052781 MEGA RIVER #2 265.89 292.48 10.051645 METISKOW NORTH 191.27 210.40 7.231362 MEYER 265.89 292.48 10.051363 MEYER B 265.89 292.48 10.051508 MICHICHI 180.67 198.74 6.831146 MIKWAN 167.86 184.65 6.351427 MIKWAN EAST 265.89 292.48 10.051144 MIKWAN NORTH 120.82 132.90 4.572237 MILLERS LAKE 144.50 158.95 5.461524 MILLS 263.48 289.83 9.961578 MILO 94.10 103.51 3.561396 MINBURN 265.89 292.48 10.052149 MINNEHIK-BK L B 131.58 144.74 4.972010 MINNEHIK-BK LK 130.90 143.99 4.95




Page 13 of 20

Receipt Point





IT-R Rateper Day

($/103m3)

1693 MINNOW LAKE 187.86 206.65 7.101658 MIQUELON LAKE 265.89 292.48 10.052273 MIRAGE 265.89 292.48 10.051500 MIRROR 193.44 212.78 7.311090 MITSUE 265.89 292.48 10.053889 MITSUE SALES INTERCONNECTION 265.89 292.48 10.051457 MITSUE SOUTH 265.89 292.48 10.053863 MONARCH EXCHANGE 94.10 103.51 3.561605 MONITOR CREEK 123.68 136.05 4.681771 MONITOR CREEK W 196.60 216.26 7.431222 MONITOR SOUTH 129.90 142.89 4.911292 MONS LAKE 265.89 292.48 10.051355 MONS LAKE EAST 265.89 292.48 10.051823 MOOSE PORTAGE 210.24 231.26 7.951484 MOOSELAKE RIVER 260.33 286.36 9.841460 MORECAMBE 265.26 291.79 10.031458 MORRIN 180.02 198.02 6.811781 MOSS LAKE 265.89 292.48 10.051802 MOSS LAKE NORTH 236.81 260.49 8.951641 MOUNT VALLEY 231.32 254.45 8.752732 MOUNTAIN LAKE 248.22 273.04 9.382206 MULLIGAN CRK S. 265.89 292.48 10.051774 MUNSON 238.11 261.92 9.001888 MUNSON #2 238.11 261.92 9.001551 MURRAY LAKE 207.19 227.91 7.831843 MURRAY LAKE NORTH 201.19 221.31 7.612236 MUSKEG CREEK 265.89 292.48 10.051785 MUSKWA RIVER 265.89 292.48 10.052711 MUSREAU LAKE 256.36 282.00 9.691730 MYRNAM 265.89 292.48 10.052745 NARRAWAY RIVER 258.90 284.79 9.793009 NEPTUNE 253.01 278.31 9.571276 NESTOW 234.13 257.54 8.851316 NETOOK 265.89 292.48 10.051020 NEVIS NORTH 137.59 151.35 5.201019 NEVIS SOUTH 133.47 146.82 5.051502 NEWBROOK 265.89 292.48 10.051140 NEWELL NORTH 94.10 103.51 3.561747 NIGHTINGALE 94.10 103.51 3.562242 NIOBE CREEK 242.39 266.63 9.161194 NIPISI 265.89 292.48 10.052071 NITON 148.00 162.80 5.602172 NITON NORTH 161.19 177.31 6.093368 NOEL LAKE SALES 230.46 253.51 8.716006 NORTH DUNCAN 265.89 292.48 10.056009 NORTH HANGINGSTONE 265.89 292.48 10.053454 NORTH PENHOLD SALES 100.09 110.10 3.786008 NORTH THORNBURY (RIO) 265.89 292.48 10.052767 NOSE MOUNTAIN 250.24 275.26 9.461865 NOSEHILL CK NORTH 143.66 158.03 5.432192 NOTIKEWIN RIVER 265.89 292.48 10.052218 NOTIKEWIN RVR N 265.89 292.48 10.05




Page 14 of 20

Receipt Point





IT-R Rateper Day

($/103m3)

1824 OBED CREEK 171.69 188.86 6.491829 OBED NORTH 140.56 154.62 5.311532 OHATON 265.89 292.48 10.052796 OLDMAN 139.16 153.08 5.261053 OLDS 115.05 126.56 4.352202 OLE LAKE 253.02 278.32 9.571545 OPAL 265.89 292.48 10.051814 ORLOFF LAKE 265.89 292.48 10.051716 OSBORNE LAKE 265.89 292.48 10.051812 OSLAND LAKE 265.89 292.48 10.051587 OVERLEA 265.89 292.48 10.051817 OWL LAKE 265.89 292.48 10.052728 OWL LAKE SOUTH 265.89 292.48 10.052742 OWL LAKE STH #2 265.89 292.48 10.052746 OWL LAKE STH #3 265.89 292.48 10.051495 OWLSEYE 265.89 292.48 10.051007 OYEN 116.84 128.52 4.421058 OYEN NORTH 94.10 103.51 3.561126 OYEN SOUTHEAST 94.10 103.51 3.562098 PADDLE PRAIR S. 265.89 292.48 10.052093 PADDLE PRAIRIE 265.89 292.48 10.051307 PADDLE RIVER 238.00 261.80 9.001852 PAKAN LAKE 181.06 199.17 6.851728 PARADISE VALLEY 265.89 292.48 10.051853 PARKER CREEK 265.89 292.48 10.051665 PARSONS LAKE 265.89 292.48 10.052089 PASS CREEK 165.13 181.64 6.242168 PASS CREEK WEST 158.09 173.90 5.982260 PASTECHO RIVER 265.89 292.48 10.051278 PATRICIA 94.10 103.51 3.561289 PATRICIA WEST 97.47 107.22 3.692793 PEAVINE CREEK 265.89 292.48 10.053804 PEMBINA INTERCONNECTION 114.85 126.34 4.341180 PENHOLD 96.41 106.05 3.651607 PENHOLD WEST 137.03 150.73 5.182280 PETE LAKE 265.89 292.48 10.052247 PETE LAKE SOUTH 223.55 245.91 8.451714 PICHE LAKE 265.89 292.48 10.051610 PICTURE BUTTE 191.62 210.78 7.242046 PIONEER 137.51 151.26 5.202088 PIONEER EAST 177.48 195.23 6.711739 PIPER CREEK 132.63 145.89 5.011797 PITLO 265.89 292.48 10.051110 PLAIN LAKE 248.94 273.83 9.411710 PLEASANT WEST 265.89 292.48 10.051858 POE 123.24 135.56 4.662173 POISON CREEK 186.82 205.50 7.061881 PORTERS BUTTE 94.10 103.51 3.563879 PRIDDIS INTERCONNECTION 94.10 103.51 3.561246 PRINCESS EAST 94.10 103.51 3.561327 PRINCESS SOUTH 94.10 103.51 3.561183 PRINCESS WEST 94.10 103.51 3.56




Page 15 of 20

Receipt Point





IT-R Rateper Day

($/103m3)

1010 PRINCESS-DENHAR 94.10 103.51 3.561022 PRINCESS-IDDESL 94.10 103.51 3.562153 PROGRESS 229.91 252.90 8.692191 PROGRESS EAST 236.07 259.68 8.931304 PROSPERITY 242.39 266.63 9.161211 PROVOST MONITOR 246.16 270.78 9.311003 PROVOST NORTH 141.56 155.72 5.351013 PROVOST SOUTH 153.94 169.33 5.821045 PROVOST WEST 214.67 236.14 8.121038 PROVOST-KESSLER 232.72 255.99 8.801601 QUEENSTOWN 193.25 212.58 7.312026 QUIRK CREEK 94.10 103.51 3.561741 RABBIT LAKE 265.89 292.48 10.052201 RAINBOW LAKE S. 265.89 292.48 10.051106 RAINIER 94.10 103.51 3.561380 RAINIER S.W. 99.17 109.09 3.751378 RAINIER SOUTH 132.07 145.28 4.991282 RALSTON 94.10 103.51 3.561826 RALSTON SOUTH 94.10 103.51 3.562148 RAMBLING CREEK 265.89 292.48 10.052213 RAMBLING CRK E. 265.89 292.48 10.051164 RANFURLY 249.06 273.97 9.423911 RANFURLY INTERCONNECT 249.35 274.29 9.431189 RANFURLY NORTH 173.88 191.27 6.571165 RANFURLY WEST 209.06 229.97 7.902211 RASPBERRY LAKE 233.62 256.98 8.832104 RAT CREEK 119.84 131.82 4.532265 RAT CREEK SOUTH 133.53 146.88 5.052252 RAT CREEK WEST 143.42 157.76 5.422193 RAY LAKE SOUTH 265.89 292.48 10.052166 RAY LAKE WEST 265.89 292.48 10.051209 REDCLIFF 142.03 156.23 5.371219 REDCLIFF SOUTH 121.12 133.23 4.581838 REDCLIFF STH #2 121.12 133.23 4.581346 REDCLIFF WEST 130.92 144.01 4.953438 REDWATER B SL 265.89 292.48 10.053406 REDWATER SALES 265.89 292.48 10.052779 RESTHAVEN 194.44 213.88 7.352785 RESTHAVEN NORTH 188.90 207.79 7.141057 RETLAW 94.10 103.51 3.561218 RETLAW SOUTH 116.44 128.08 4.401392 RIBSTONE 265.89 292.48 10.051374 RICH LAKE 265.89 292.48 10.051306 RICHMOND 265.89 292.48 10.051135 RICINUS 110.64 121.70 4.181372 RICINUS SOUTH 110.61 121.67 4.181437 RICINUS WEST 115.43 126.97 4.362782 RIDGEVALLEY 204.42 224.86 7.731949 RIMBEY-WESTEROSE SUMMARY 122.85 135.14 4.643405 RIM-WEST SALES 122.79 135.07 4.641510 RIVERCOURSE 265.89 292.48 10.051499 ROBB 154.83 170.31 5.85




Page 16 of 20

Receipt Point





IT-R Rateper Day

($/103m3)

1336 ROCHESTER 265.89 292.48 10.051400 ROCK ISLAND LK 265.89 292.48 10.051820 ROCK ISLAND S2 265.89 292.48 10.051134 ROCKYFORD 94.10 103.51 3.562715 ROD LAKE 265.89 292.48 10.051468 ROSALIND 134.38 147.82 5.081579 ROSE LYNNE 94.10 103.51 3.561885 ROSEGLEN 94.10 103.51 3.561466 ROSEMARY 94.10 103.51 3.561461 ROSEMARY NORTH 94.10 103.51 3.562099 ROSEVEAR SOUTH 154.69 170.16 5.852725 ROSSBEAR LAKE 265.89 292.48 10.051706 ROURKE CRK EAST 265.89 292.48 10.051540 ROWLEY 166.57 183.23 6.301299 ROYAL PARK 155.85 171.44 5.891530 RUMSEY 172.44 189.68 6.521867 RUMSEY NORTH #2 230.01 253.01 8.701600 RUMSEY WEST 211.32 232.45 7.993912 RUNNING LAKE INTERCONNECTION 265.89 292.48 10.052261 RUSSELL CREEK 265.89 292.48 10.051311 SADDLE LAKE N. 214.06 235.47 8.091310 SADDLE LAKE W. 260.01 286.01 9.835004 SALESKI 265.89 292.48 10.052281 SAND CREEK 132.79 146.07 5.022758 SAWN LAKE 265.89 292.48 10.052792 SAWN LAKE EAST 265.89 292.48 10.053481 SAWRIDGE SALES 265.89 292.48 10.051263 SCHULER 94.10 103.51 3.561537 SCOTFIELD 201.87 222.06 7.631036 SEDALIA NORTH 196.65 216.32 7.431023 SEDALIA SOUTH 114.03 125.43 4.311114 SEDGEWICK 265.89 292.48 10.051395 SEDGEWICK EAST 265.89 292.48 10.051403 SEDGEWICK NORTH 253.07 278.38 9.571447 SEIU CREEK 94.10 103.51 3.561370 SEPTEMBER LK N. 265.89 292.48 10.051847 SERVICEBERRY CREEK 94.10 103.51 3.563862 SEVERN CREEK INTERCONNECTION 94.10 103.51 3.563940 SHADY OAK INTERCONNECTION 161.26 177.39 6.101871 SHARPLES 94.10 103.51 3.561846 SHARROW SOUTH#2 94.10 103.51 3.563439 SHEERNESS SALES 94.10 103.51 3.562783 SHEKILIE RVR EAST 265.89 292.48 10.052276 SHEKILIE RVR N. 265.89 292.48 10.052798 SHERRI VAIL 152.63 167.89 5.771008 SIBBALD 154.65 170.12 5.852184 SILVER VALLEY 265.89 292.48 10.052170 SILVERWOOD 265.89 292.48 10.052239 SILVERWOOD N. 249.15 274.07 9.421806 SIMON LAKES 265.89 292.48 10.052028 SIMONETTE 225.52 248.07 8.532033 SIMONETTE NORTH 225.69 248.26 8.53




Page 17 of 20

Receipt Point





IT-R Rateper Day

($/103m3)

1354 SLAWA NORTH 254.59 280.05 9.632235 SLIMS LAKE 265.89 292.48 10.052137 SLOAT CREEK 265.89 292.48 10.051521 SMITH 265.89 292.48 10.051637 SMITH WEST 265.89 292.48 10.052165 SNEDDON CREEK 265.89 292.48 10.052253 SNIPE LAKE 265.89 292.48 10.052264 SNOWFALL CREEK 265.89 292.48 10.052763 SNUFF MOUNTAIN 171.66 188.83 6.495110 SNUFF MOUNTAIN NORTH 173.47 190.82 6.561065 SOUTH ELKTON 203.98 224.38 7.711556 SOUTH SASK RVR 232.09 255.30 8.771580 SPEAR LAKE 265.89 292.48 10.051856 SPOTTED CREEK 145.72 160.29 5.511341 SPRUCEFIELD 265.89 292.48 10.051487 SPURFIELD 265.89 292.48 10.051581 SQUARE LAKE 265.89 292.48 10.052775 SQUIRREL MOUNTAIN 264.50 290.95 10.001519 ST. BRIDES 259.66 285.63 9.821414 ST. LINA 255.46 281.01 9.661415 ST. LINA NORTH 265.89 292.48 10.051416 ST. LINA WEST 262.78 289.06 9.941534 STANDARD 94.10 103.51 3.561131 STANMORE 118.19 130.01 4.471156 STANMORE SOUTH 110.09 121.10 4.161371 STEELE LAKE 265.89 292.48 10.052284 STEEN RIVER 265.89 292.48 10.051308 STETTLER SOUTH 203.73 224.10 7.701388 STEVEVILLE 94.10 103.51 3.561565 STONEY CREEK 265.89 292.48 10.051566 STONEY CREEK W. 235.02 258.52 8.891115 STRACHAN 101.65 111.82 3.841179 STROME-HOLMBERG 154.57 170.03 5.842030 STURGEON LAKE S 251.79 276.97 9.521423 SUFFIELD WEST 103.64 114.00 3.921193 SULLIVAN LAKE 170.27 187.30 6.441516 SUNDANCE CREEK 200.21 220.23 7.571595 SUNDANCE CRK E. 137.42 151.16 5.201079 SUNNYNOOK 94.10 103.51 3.562795 SUNVALLEY 157.38 173.12 5.951054 SYLVAN LAKE 117.45 129.20 4.441187 SYLVAN LAKE EAST #1 113.64 125.00 4.301855 SYLVAN LAKE EAST #2 112.32 123.55 4.251191 SYLVAN LK SOUTH 132.02 145.22 4.991055 SYLVAN LK WEST 130.09 143.10 4.922082 TANGENT 265.89 292.48 10.052121 TANGENT B 265.89 292.48 10.052208 TANGENT EAST 265.89 292.48 10.052157 TANGHE CREEK 265.89 292.48 10.052204 TANGHE CREEK #2 265.89 292.48 10.052747 TANGHE CREEK #3 265.89 292.48 10.051440 TAPLOW 94.10 103.51 3.56




Page 18 of 20

Receipt Point





IT-R Rateper Day

($/103m3)

1837 TAWADINA CREEK 101.11 111.22 3.822076 TEEPEE CREEK 265.89 292.48 10.055027 THICKWOOD HILLS 265.89 292.48 10.051377 THORHILD 265.89 292.48 10.051430 THORHILD WEST 219.49 241.44 8.306005 THORNBURY EAST 265.89 292.48 10.056002 THORNBURY MARIANA 265.89 292.48 10.056001 THORNBURY NORTH (AG THORN) 265.89 292.48 10.056000 THORNBURY WEST 265.89 292.48 10.051029 THREE HILLS CRK 129.42 142.36 4.891335 THREE HLS CRK W 94.10 103.51 3.561348 TIDE LAKE 94.10 103.51 3.561639 TIDE LAKE B 94.10 103.51 3.561331 TIDE LAKE EAST 94.10 103.51 3.561268 TIDE LAKE NORTH 94.10 103.51 3.561223 TIDE LAKE SOUTH 94.10 103.51 3.561412 TIELAND 265.89 292.48 10.051314 TILLEBROOK 94.10 103.51 3.561644 TILLEBROOK WEST 94.10 103.51 3.561169 TILLEY 94.10 103.51 3.561839 TILLEY SOUTH #2 201.04 221.14 7.602769 TIMBERWOLF 265.89 292.48 10.052116 TONY CREEK N. 205.13 225.64 7.762754 TOPLAND 264.62 291.08 10.001841 TORLEA EAST 189.23 208.15 7.151869 TORRINGTON E #2 94.10 103.51 3.561621 TORRINGTON EAST 94.10 103.51 3.561442 TRAVERS 94.10 103.51 3.565105 TREMBLAY 257.01 282.71 9.725106 TREMBLAY #2 257.09 282.80 9.725107 TREMBLAY #3 257.09 282.80 9.721574 TROCHU 156.06 171.67 5.901848 TUDOR 94.10 103.51 3.561343 TWEEDIE 265.89 292.48 10.051256 TWEEDIE SOUTH 265.89 292.48 10.051699 TWELVE MILE COULEE 132.68 145.95 5.021190 TWINING 103.35 113.69 3.911066 TWINING NORTH 109.41 120.35 4.143113 TWINLAKES CK SL 265.89 292.48 10.052224 TWO CREEKS 265.89 292.48 10.052229 TWO CREEKS EAST 265.89 292.48 10.051120 UKALTA 239.96 263.96 9.071317 UKALTA EAST 204.24 224.66 7.721250 UNITY BORDER 178.91 196.80 6.761154 VALE 103.57 113.93 3.921212 VALE EAST 136.34 149.97 5.152107 VALHALLA 228.16 250.98 8.632227 VALHALLA #2 228.11 250.92 8.622189 VALHALLA EAST 245.03 269.53 9.261801 VANDERSTEENE LK 265.89 292.48 10.052788 VEDA 259.00 284.90 9.791056 VERGER 94.10 103.51 3.56




Page 19 of 20

Receipt Point





IT-R Rateper Day

($/103m3)

1077 VERGER-HOMESTEA 94.10 103.51 3.561203 VERGER-MILLICEN 94.10 103.51 3.563916 VETERAN SUMMARY 241.89 266.08 9.151606 VICTOR 237.02 260.72 8.961347 VIKING EAST 155.83 171.41 5.893890 VIKING INTERCONNECTION 147.29 162.02 5.571257 VIKING NORTH 215.00 236.50 8.131464 VILNA 265.89 292.48 10.051527 VIMY 265.89 292.48 10.052034 VIRGINIA HILLS 265.89 292.48 10.052073 VIRGINIA HLS E. 254.06 279.47 9.611076 VULCAN 114.96 126.46 4.351724 WABASCA 265.89 292.48 10.051669 WADDELL CREEK 265.89 292.48 10.051736 WADDELL CREEK W 265.89 292.48 10.051383 WAINWRIGHT EAST 265.89 292.48 10.051199 WAINWRIGHT S. 249.86 274.85 9.456015 WANDER TOWER (TALISMAN) 265.89 292.48 10.051822 WANDERING RIVER 265.89 292.48 10.051340 WARDLOW EAST 94.10 103.51 3.562133 WARRENSVILLE 265.89 292.48 10.051353 WARSPITE 193.52 212.87 7.321118 WARWICK 148.43 163.27 5.611173 WARWICK SOUTH 169.58 186.54 6.413948 WARWICK SOUTHEAST INTERCONNECTION 141.05 155.16 5.332029 WASKAHIGAN 166.58 183.24 6.302096 WASKAHIGAN EAST 225.62 248.18 8.532160 WATER VALLEY 94.10 103.51 3.562123 WATINO 265.89 292.48 10.051945 WATR1/WATR2 SUM 94.10 103.51 3.561570 WATTS 130.36 143.40 4.931021 WAYNE NORTH 132.57 145.83 5.011039 WAYNE-DALUM 122.70 134.97 4.641107 WAYNE-ROSEBUD 94.10 103.51 3.561585 WEASEL CREEK 234.87 258.36 8.881723 WEAVER LAKE 265.89 292.48 10.051780 WEAVER LAKE S. 265.89 292.48 10.052207 WEBSTER 265.89 292.48 10.052248 WEBSTER NORTH 265.89 292.48 10.051825 WELLING 258.76 284.64 9.782158 WEMBLEY 213.57 234.93 8.072120 WEST PEMBINA S. 129.51 142.46 4.901188 WEST VIKING 186.66 205.33 7.061321 WESTLOCK 265.89 292.48 10.053871 WESTLOCK SALES INTERCONNECTION 265.89 292.48 10.051787 WHISTWOW 265.89 292.48 10.052701 WHITBURN EAST 250.50 275.55 9.471094 WHITECOURT 212.13 233.34 8.022075 WHITELAW 260.27 286.30 9.842055 WHITEMUD EAST 265.89 292.48 10.053917 WHITEMUD WEST-WHITEMUD RIVER SUM 265.89 292.48 10.051345 WHITFORD 192.71 211.98 7.29




Page 20 of 20

Receipt Point





IT-R Rateper Day

($/103m3)

1684 WIAU LAKE 265.89 292.48 10.052005 WILDCAT HILLS 94.10 103.51 3.561661 WILDHAY RIVER 146.59 161.25 5.541650 WILDUNN CREEK E 94.10 103.51 3.561049 WILDUNN CRK-BUR 94.52 103.97 3.572112 WILLESDEN GR N. 101.77 111.95 3.852014 WILLESDEN GREEN 99.41 109.35 3.761428 WILLINGDON 169.72 186.69 6.421652 WILLOW RIVER 265.89 292.48 10.051759 WILLOW RIVER N 265.89 292.48 10.052019 WILSON CREEK 162.97 179.27 6.162171 WILSON CREEK SE 164.09 180.50 6.201046 WIMBORNE 95.28 104.81 3.601234 WIMBORNE NORTH 102.77 113.05 3.892707 WINAGAMI LAKE 265.89 292.48 10.052012 WINDFALL 157.65 173.42 5.961577 WINEFRED RIVER 265.89 292.48 10.051628 WINEFRED RVR N. 265.89 292.48 10.051671 WINEFRED RVR S. 265.89 292.48 10.051070 WINTERING HILLS 94.10 103.51 3.561104 WINTERING HLS E 94.10 103.51 3.562147 WITHROW 125.66 138.23 4.752124 WOKING 265.89 292.48 10.052214 WOLVERINE RIVER 265.89 292.48 10.051035 WOOD RIVER 170.15 187.17 6.433425 WOOD RVR SALES 170.85 187.94 6.462765 WOOSTER 160.22 176.24 6.062057 WORSLEY EAST 265.89 292.48 10.051342 YOUNGSTOWN 192.46 211.71 7.282060 ZAMA LAKE 265.89 292.48 10.051944 ZAMA LAKE SUMMARY 265.89 292.48 10.05




Page 1 of 4

Group 1 Delivery Point

NumberGroup 1 Delivery Point Name

FT-D Demand Rate per Month

Price Point "Z"($/GJ)

IT-D Rateper Day($/GJ)

2000 ALBERTA-B.C. BORDER 5.84 0.21133002 BOUNDARY LAKE BORDER 4.32 0.15631958 EMPRESS BORDER 5.92 0.21433886 GORDONDALE BORDER 4.32 0.15636404 MCNEILL BORDER 5.92 0.2143






3880 AECO INTERCONNECTION 1.69 0.06103868 ALBERTA-MONTANA 4.32 0.15633059 ALLISON CREEK SALES 1.69 0.06103562 AMOCO SALES (BP SALES TAP) 1.69 0.06103488 ARDLEY SALES 1.69 0.06103943 ATUSIS CREEK INTERCONNECTION 1.69 0.06103135 AURORA SALES 1.69 0.06103423 BASHAW WEST SALES 1.69 0.06103068 BEAVER HILLS SALES 1.69 0.06103933 BIG EDDY INTERCONNECTION 1.69 0.06103067 BIGSTONE SALES 1.69 0.06103887 BITTERN LAKE INTERCONNECTION 1.69 0.06103468 BLEAK LAKE SALES 1.69 0.06103471 BLUE RIDGE EAST SALES 1.69 0.06103164 BRAINARD LAKE SALES 1.69 0.06102364 BROWNVALE SALES 1.69 0.06103918 BUFFALO CREEK INTERCONNECTION 1.69 0.06103109 CALDWELL SALES 1.69 0.06103634 CANOE LAKE SALES 1.69 0.06103165 CANOE LK SLS #2 1.69 0.06103866 CARBON INTERCONNECTION 1.69 0.06103484 CARIBOU LAKE SALES 1.69 0.06103157 CARIBOU LK SOUTH SL 1.69 0.06103106 CARMON CREEK SALES 1.69 0.06103101 CAROLINE SALES 1.69 0.06103893 CARROT CREEK INTERCONNECTION 1.69 0.06103495 CAVALIER SALES 1.69 0.06103907 CHANCELLOR INTERCONNECTION 1.69 0.06103151 CHEECHAM W. #2 SALES 1.69 0.06103622 CHEECHAM WEST SALES 1.69 0.06106014 CHEVRON AURORA SALES 1.69 0.06103097 CHICKADEE CREEK SALES 1.69 0.06103305 CHIGWELL NORTH SALES 1.69 0.06103496 CHIPEWYAN RIVER SALES 1.69 0.06103163 CHRISTINA LAKE NORTH SALES 1.69 0.06103158 CLYDE N SALES 1.69 0.06101417 COLD LAKE BDR 4.32 0.15633052 COLEMAN SALES 1.69 0.06103168 COLLICUTT SALES 1.69 0.06103904 CONKLIN WEST INTERCONNECTION 1.69 0.06103416 COUSINS A SALES 1.69 0.06101963 COUSINS B & C SALES 1.69 0.06103483 CRAMMOND SALES 1.69 0.06103105 CRANBERRY LAKE SALES 1.69 0.0610




Page 2 of 4






3897 CROSSFIELD EAST INTERCONNECTION 1.69 0.06103172 CROSSFIELD SALES 1.69 0.06105024 CROW LAKE SALES 1.69 0.06103071 CYNTHIA SALES 1.69 0.06103147 DAWES LAKE SALES 1.69 0.06103184 DAWES LAKE SALES #2 1.69 0.06103119 DEADRICK CREEK SALES (Return Run) 1.69 0.06103888 DEEP VALLEY CREEK INTERCONNECTION 1.69 0.06103085 DEEP VALLEY CREEK SALES 1.69 0.06103124 DEEP VALLEY CREEK SOUTH SALES 1.69 0.06103465 DEMMITT SALES 1.69 0.06103121 DEMMITT SALES #2 1.69 0.06106011 DOVER SALES 1.69 0.06103186 DUNKIRK RIVER SALES 1.69 0.06103098 DUTCH CREEK SALES 1.69 0.06103062 EAST CALGARY 'B' SALES 1.69 0.06103632 EAST CALGARY SALES 1.69 0.06103939 EAST EDMONTON #2 EXCHANGE 1.69 0.06103938 EAST EDMONTON EXCHANGE 1.69 0.06103175 EGG LAKE SALES 1.69 0.06103129 EKWAN SALES 1.69 0.06103456 ELK POINT SALES 1.69 0.06103082 ELK RIVER SOUTH SALES 1.69 0.06103469 EVERGREEN SALES 1.69 0.06103112 FALHER SALES 1.69 0.06103185 FAWCETT RIVER NORTH SALES 1.69 0.06103159 FAWCETT RIVER SALES 1.69 0.06103107 FERGUSON SALES 1.69 0.06103623 FERINTOSH NORTH SALES (Return Run) 1.69 0.06103430 FERINTOSH SALES 1.69 0.06103182 FERRIER SOUTH A SALES 1.69 0.06103077 FIRE CREEK SALES 1.69 0.06103154 FIREBAG SALES 1.69 0.06103138 FISHER CREEK SALES 1.69 0.06103304 FORESTBURG SALES 1.69 0.06103490 GAETZ LAKE SALE 1.69 0.06103128 GARRINGTON SALE 1.69 0.06103616 GAS CITY SALES 1.69 0.06103195 GILBY SALES 1.69 0.06103624 GODS LAKE SALES (RETURN RUN) 1.69 0.06103087 GOLD CREEK SALES 1.69 0.06103424 GRANDE CENTRE SALES 1.69 0.06103055 GRANDE PRAIRIE SALES 1.69 0.06103183 GRANOR SALES 1.69 0.06103464 GREENCOURT WEST SALES 1.69 0.06103117 GRIZZLY SALES 1.69 0.06103414 HANNA SOUTH B SALES 1.69 0.06103437 HARMATTAN SALES 1.69 0.06103615 HAYNES SALES 1.69 0.06103100 HEART RIVER SALES 1.69 0.06103611 HERMIT LAKE SALES 1.69 0.06103162 HOOLE SALES #2 1.69 0.06103181 HOOLE SALES #3 1.69 0.06103153 HORIZON SALES 1.69 0.06103125 HUGGARD CREEK SALES 1.69 0.06103857 INLAND SALES EXCHANGE 1.69 0.0610




Page 3 of 4






3472 INNISFAIL SALES 1.69 0.06103193 IPIATIK LAKE SALES 1.69 0.06103156 JACKFISH SALES 1.69 0.06103166 JACKPINE SALES 1.69 0.06103133 JACKPOT CREEK SALES (RETURN RUN) 1.69 0.06103860 JANUARY CREEK INTERCONNECTION 1.69 0.06106012 JAPAN CANADA SA 1.69 0.06103618 JENNER EAST SALES 1.69 0.06103864 JOFFRE INTERCONNECTION 1.69 0.06103152 JOSLYN CREEK SALES 1.69 0.06103078 JUDY CREEK SALEs 1.69 0.06103192 KEARL SALES 1.69 0.06103179 KENT SALES 1.69 0.06103150 KETTLE RIVER N#2 1.69 0.06103931 KV OIL SANDS EX 1.69 0.06103476 LAC LA BICHE SALES 1.69 0.06103460 LANDON LAKE SALES 1.69 0.06103605 LEMING LAKE SALES 1.69 0.06103187 LITTLE SUNDANCE SALES 1.69 0.06103474 LLOYD CREEK SALES 1.69 0.06103482 LONE PINE CREEK SALES 1.69 0.06103606 LOSEMAN LAKE SALES 1.69 0.06103080 LOUISE CREEK SALES 1.69 0.06103058 LUNDBRECK/COWLEY SALES 1.69 0.06103146 MAHIHKAN SALES 1.69 0.06103604 MARGUERITE LAKE SALES 1.69 0.06103110 MARSH HEAD CREEK WEST SALES 1.69 0.06106021 MILDRED LAKE NORTH SALES 1.69 0.06103120 MILDRED LAKE SALES 1.69 0.06103111 MINNOW LAKE SOUTH SALES 1.69 0.06103889 MITSUE SALES INTERCONNECTION 1.69 0.06103863 MONARCH EXCHANGE 1.69 0.06103167 MOOREHEAD SALES 1.69 0.06103930 MOOSA EXCHANGE 1.69 0.06103368 NOEL LAKE SALES 1.69 0.06103479 NOSEHILL CREEK NORTH SALES 1.69 0.06103470 NOSEHILL CREEK SALES 1.69 0.06103478 ONETREE SALES 1.69 0.06103300 OTAUWAU SALES 1.69 0.06103072 PADDY CREEK SALES 1.69 0.06103804 PEMBINA INTERCONNECTION 1.69 0.06103454 PENHOLD NORTH SALES 1.69 0.06103444 PINCHER CREEK SALES 1.69 0.06103086 PINE CREEK SALES 1.69 0.06103178 POINTE LA BICHE SALES 1.69 0.06103879 PRIDDIS INTERCONNECTION 1.69 0.06103174 QUIRK CREEK SALES #2 1.69 0.06103076 RAINBOW SALES 1.69 0.06103911 RANFURLY INTERCONNECT 1.69 0.06103131 RASPBERRY LAKE SALES 1.69 0.06103194 RAT CREEK WEST SALES 1.69 0.06103438 REDWATER 'B' SALES 1.69 0.06103406 REDWATER SALES 1.69 0.06103405 RIM-WEST SALES 1.69 0.06103635 ROD LAKE SALES DELIVERY 1.69 0.0610




Page 4 of 4






3448 ROSS CREEK SALES 1.69 0.06103912 RUNNING LAKE INTERCONNECTION 1.69 0.06103189 SAAMIS SALES 1.69 0.06103095 SAKWATAMAU SALES 1.69 0.06103139 SALESKI SALES 1.69 0.06103050 SARATOGA SALES 1.69 0.06103609 SARRAIL SALES 1.69 0.06103301 SAULTEAUX SALES 1.69 0.06103481 SAWRIDGE SALES 1.69 0.06103862 SEVERN CREEK INTERCONNECTION 1.69 0.06103940 SHADY OAK INTERCONNECTION 1.69 0.06103613 SHANTZ SALES 1.69 0.06103439 SHEERNESS SALES 1.69 0.06103494 SILVER VALLEY SALES 1.69 0.06103099 SOUSA CREEK EAST SALES 1.69 0.06103140 SOUTH ELKTON SALES 1.69 0.06103149 SOUTH TERMINAL SALES 1.69 0.06103429 ST. PAUL SALES 1.69 0.06103600 STORNHAM COULEE SALES 1.69 0.06103130 SUNDANCE CK E SALE 1.69 0.06103497 SUNDAY CREEK SOUTH SALES 1.69 0.06103144 TUCKER LAKE SLS 1.69 0.06102322 TURNER VALLEY CONNECTION 1.69 0.06103113 TWINLAKES CREEK SALES 1.69 0.06101250 UNITY BORDER 4.32 0.15633115 USONA SALES 1.69 0.06103088 VALHALLA SALES 1.69 0.06103639 VEGREVILLE SALES 1.69 0.06103890 VIKING INTERCONNECTION 1.69 0.06103103 VIRGO SALES 1.69 0.06103177 WARWICK SOUTH SALES 1.69 0.06103948 WARWICK SOUTHEAST INTERCONNECTION 1.69 0.06103074 WATERTON SALES 1.69 0.06103171 WATERTON SALES #1 1.69 0.06103412 WAYNE NORTH B SALES 1.69 0.06103134 WELLING SALES 1.69 0.06103114 WEMBLEY SALES 1.69 0.06103173 WEMBLEY SOUTH SALES 1.69 0.06103486 WESTERDALE SALES 1.69 0.06103871 WESTLOCK SALES INTERCONNECTION 1.69 0.06103191 WHISKEY JACK LAKE SALES 1.69 0.06103176 WHITESANDS SALES 1.69 0.06103069 WILSON CREEK SOUTH SALES 1.69 0.06103421 WIMBORNE SALES 1.69 0.06103148 WINEFRED SALES 1.69 0.06103425 WOOD RIVER SALES 1.69 0.0610

* FT-D Service at Group 3 Delivery points not available until the Integration Effective Date.




FT-P Demand Rateper Month

Price Point "B"*

FT-PReceipt Credit Rate

FT-PDeliveryCreditRate

From To ($/103m3) ($/103m3/d) ($/103m3/d)1 0 25 133.21 3.09 1.992 >25 50 142.87 3.38 1.993 >50 75 152.54 3.66 1.994 >75 100 162.20 3.94 1.995 >100 125 171.87 4.22 1.996 >125 150 181.53 4.51 1.997 >150 175 191.19 4.79 1.998 >175 200 200.86 5.07 1.999 >200 225 210.52 5.35 1.9910 >225 250 220.18 5.64 1.9911 >250 275 229.85 5.92 1.9912 >275 300 239.51 6.20 1.9913 >300 325 249.17 6.48 1.9914 >325 350 258.84 6.76 1.9915 >350 375 268.50 7.05 1.9916 >375 400 278.17 7.33 1.9917 >400 425 287.83 7.61 1.9918 >425 450 297.49 7.89 1.9919 >450 475 307.16 8.18 1.9920 >475 500 316.82 8.46 1.9921 >500 326.48 8.74 1.99

* Reflects the Year 2 Transition FT-P adjustment of $21.47 /103m3/mth (2 ¢/mcf/d)

Maximum DistanceBetween Receipt Point and Delivery Point (km)

DistanceBand

TARIFF Effective Date: January 1, 2011


Attachment C5 Alberta System Tariff Amendments

Black-lined Copy

NOVA Gas Transmission Ltd. Summary of Amendments Page 1 of 1

The following is a summary of the proposed amendments to the Alberta System Tariff

necessary to give effect to the Alberta System Components for the purpose of

establishing the Alberta System Interim 2011 Rates as set out the Application. This

summary is provided for information only and is not intended to form part of the Tariff.

1. Within the Definitions of the General Terms and Conditions (“GT&C”):

(i) Added 1.81 “Mainline Surcharge”; and

(ii) Revised 1.120 “Surcharge”.

2. Within the Rate Schedules LRS, LRS-2 and LRS-3:

(i) Revised calculation of charge for service; and

(ii) Revised numbering references.

NOVA Gas Transmission Ltd. Page 12 General Terms and Conditions

Effective Date: November January 1, 20102011

1.72 “kPa” or “kiloPascals ” shall mean kiloPascals of pressure (gauge) unless otherwise

specified.

1.73 “Line Pack Gas” shall mean at any point in time that quantity of gas determined by

Company to be the total quantity of gas contained in the Facilities.

1.74 “Low Intervention Trade Transaction” shall have the meaning attributed to it in G-14, as

may be amended from time to time.

1.75 “LRS Billing Adjustment” shall have the meaning attributed to it in subparagraph 4.2.4

of Rate Schedule LRS.

1.76 “LRS Charge” shall have the meaning attributed to it in subparagraph 4.2.3 of Rate

Schedule LRS.

1.77 “LRS Contract Demand” shall mean the maximum daily volume of gas Company may be

required to receive from Customer and deliver at the Empress or McNeill Delivery Point

under Rate Schedule LRS.

1.78 “LRS Receipt Point Obligation” shall mean the period determined in subparagraph 6.2 or

6.3 of Rate Schedule LRS as the case may be.

1.79 “LRS-3 Contract Demand” shall mean the maximum daily volume of gas Company may

be required to receive from Customer and deliver at the Empress Delivery Point under a

Schedule of Service for Service under Rate Schedule LRS-3.

1.80 “LRS-3 Demand Rate” shall mean the LRS-3 Demand Rate in the Table of Rates, Tolls

and Charges which has been fixed by Company or the Board for Service under Rate

Schedule LRS-3.

1.81 “Mainline Surcharge” shall mean the surcharge defined in the TransCanada PipeLines

Transportation Tariff and set forth in Company’s Table of Rates, Tolls and Charges,

applied to volumes of gas received by Company under Rate Schedules FT-R, FT-RN,

Attachment C5



FT-P, IT-R, LRS, LRS-2 and LRS-3 and collected by Company on behalf of

TransCanada PipeLines Limited.

1.811.82 “Maximum Carbon Dioxide Volume” shall mean the maximum total excess CO2

Volume as determined by Company that the Company may be required to accept at a

particular Receipt Point on any day, as set forth in a Schedule of Service under Rate

Schedule CO2.

1.821.83 “Maximum Delivery Pressure” shall mean relative to a Delivery Point the

maximum pressure at which Company may deliver gas to Customer, as set forth in a

Schedule of Service.

1.831.84 “Maximum Receipt Pressure” shall mean relative to a Receipt Point the maximum

pressure at which Company may require Customer to deliver gas, as set forth in Schedule

of Service.

1.841.85 “MC” shall mean Measurement Canada, an Agency of Industry Canada.

1.851.86 “Measurement Variance” shall mean, for any period, after taking into account any

adjustment made in accordance with the provisions of paragraph 2.6 of these General

Terms and Conditions, the energy equivalent of the amount determined as follows:

MV = (A + B + C) - (D + E)

Where:

“MV” = the Measurement Variance;

“A” = the energy equivalent of gas determined by Company to have been

delivered to all Customers during the period;

“B” = the energy equivalent of the aggregate of the Gas Lost and Gas Used

during the period;

“C” = the energy equivalent of Line Pack Gas at the end of the period;

Attachment C5



1.1171.118 “Storage Facility” shall mean any commercial facility where gas is stored, that is

connected to the Facilities and is available to all Customers.

1.1181.119 “Storage Receipt Point” shall mean the point where gas may be received from the

Storage Facility by Company for Customer that was previously delivered to such Storage

Facility at the Storage Delivery Point under a Schedule of Service.

1.1191.120 “Surcharge” shall mean a the Mainline Surcharge and any other Surcharge set

forth in the Table of Rates, Tolls and Charges which has been fixed by Company or the

Board for Service under a Rate Schedule.

1.1201.121 “Table of Rates, Tolls and Charges” shall mean the Table of Rates, Tolls and

Charges setting forth rates, tolls and charges that have been fixed by Company or the

Board to be imposed, observed and followed by Company.

1.1211.122 “Tariff” shall mean this Gas Transportation Tariff, including the Table of Rates,

Tolls and Charges, the Rate Schedules, the Service Agreements, Schedules of Service,

these General Terms and Conditions and the Appendices.

1.1221.123 “Tier” shall mean the Tier 1, Tier 2 or Tier 3 CO2 Rate as set forth in the Table of

Rates, Tolls and Charges.

1.1231.124 “TJ” shall mean terajoule, or one trillion joules.

1.1241.125 “Thousand Cubic Metres” or “103m3” shall mean one thousand (1000) Cubic

Metres of Gas.

1.1251.126 “Website” shall mean Company’s internet site operated by TransCanada

PipeLines Limited for Company.

1.1261.127 “Winter Season” shall mean the period commencing on November 1 of any year

and ending on the next succeeding March 31.

Attachment C5

NOVA Gas Transmission Ltd. LRS

Rate Schedule


4.3 Aggregate of Customer’s Over-Run Gas Charges

4.3.1. In the event that Company determines in respect of a Billing Month that Company has

received from Customer, in such Billing Month, a volume of gas at any Receipt Point

identified in Appendix “1” of this Rate Schedule in excess of:

(a) the aggregate of the products obtained when each of the LRS Contract

Demand and LRS-3 Contract Demand in effect for Customer in respect of

Rate Schedules LRS and LRS-3, in such Billing Month, is multiplied by

the number of Days in such month that such LRS Contract Demand and

LRS-3 Contract Demand was in effect; plus

(b) the aggregate of the products obtained when each of the Receipt Contract

Demand in effect for Customer in respect of Rate Schedule FT-R and Rate

Schedule FT-RN, in such Billing Month, is multiplied by the number of

Days in such month that the Receipt Contract Demand was in effect,

then Customer shall pay to Company an amount equal to the product of a volume equal

to such excess and the IT-R Rate for the applicable Receipt Point.

4.3.2. The calculation of Customer’s Over-Run Gas charge in subparagraph 4.3.1 shall not take

into account Customer's Inventory on the last day of the Billing Month.

4.4 Aggregate of Customer’s Surcharges

The aggregate of Customer’s Surcharges for a Billing Month shall be equal to the sum of

all Surcharges set forth in the Table of Rates, Tolls and Charges applicable to Service


4.44.5 Aggregate Charge For Service

Customer shall pay for each Billing Month:

Attachment C5


Rate Schedule


(i) the amounts calculated in accordance with paragraphs 4.1 and 4.3; less (ii)

the sum of:

(a) the billing credit, if any, calculated in accordance with the Terms

and Conditions Respecting Relief for Mainline Capacity

Restrictions in Appendix “B” of the Tariff; and

(b) the LRS Billing Adjustment, if any, calculated in accordance with

paragraph 4.2 of this Rate Schedule LRS; plus.

(ii) the amounts calculated in accordance with paragraph 4.4.

4.54.6 Allocation of Gas Received

Notwithstanding any other provision of this Rate Schedule, any Service Agreement or

General Terms and Conditions of the Tariff, and without regard to how gas may have

been nominated, the aggregate volume of gas received from Customer at a Receipt Point

shall be allocated for billing purposes as follows:

(i) first to Service to Customer under Rate Schedule LRS to a maximum of such

Customer’s LRS Contract Demand for such Receipt Point under such Rate

Schedule LRS, to service to a maximum of such Eligible LRS-2 Volumes for the

Coleman Receipt Point under such Rate Schedule LRS-2 and to Service to

Customer under Rate Schedule LRS-3 to a maximum of such Customer’s LRS-3

Contract Demand for such Receipt Point under such Rate Schedule LRS-3;

(ii) secondly to service to Customer under Rate Schedule FT-R to a maximum of such

Customer’s Receipt Contract Demand for such Receipt Point under such Rate

Schedule FT-R;

Attachment C5

NOVA Gas Transmission Ltd. LRS-2 Rate Schedule


4.0 CHARGE FOR SERVICE




under Rate Schedule LRS-2.

4.14.2 Determination of Monthly Charge

LRS-2 Customer will be charged and shall pay a monthly amount (the "Monthly

Charge") for a Billing Month equal to the sum for all days of such month of the following

amounts:

(i) the daily equivalent of the FT-R Demand Rate at the Coleman Receipt

Point multiplied by Price Point “A” (as defined in Rate Schedule FT-R)

multiplied by the Service Entitlement for the day in the Billing Month;

and

(ii) the daily volumetric equivalent of the FT-D Demand Rate at the A/BC

Delivery Point multiplied by the Service Entitlement for the day in the

Billing Month.; and

(iii) the amounts calculated in accordance with paragraph 4.1.

4.24.3 Determination of the LRS-2 Adjustment

The LRS-2 Adjustment for a Billing Month shall be equal to the Monthly Charge for

such Billing Month less $50,000. The LRS-2 Adjustment shall then be applied against

LRS-2 Customer's invoice issued in the second month following the Billing Month.

Attachment C5



4.4.14.5.1 Allocation of Gas Received

Notwithstanding any other provision of Rate Schedule LRS-2, any Service Agreement or

the General Terms and Conditions of the Tariff, and without regard to how gas may have

been nominated, the aggregate daily volume of gas received from LRS-2 Customer at the

Coleman Receipt Point shall be allocated for billing purposes as follows:

(i) first to Service to LRS-2 Customer under Rate Schedule LRS-2, to a

maximum of Eligible LRS-2 Volumes for the Coleman Receipt Point

under Rate Schedule LRS-2;

(ii) secondly to service to LRS-2 Customer under Rate Schedule FT-R to a

maximum of such Customer’s Receipt Contract Demand for such

Coleman Receipt Point under such Rate Schedule FT-R;

(iii) thirdly to service to LRS-2 Customer under Rate Schedule FT-RN to a

maximum of such Customer's Receipt Contract Demand for such Coleman

Receipt Point under Rate Schedule FT-RN; and

(iv) fourthly to service to LRS-2 Customer under Rate Schedule IT-R for such

Coleman Receipt Point. If LRS-2 Customer is not entitled to service

under Rate Schedule IT-R at such Coleman Receipt Point, LRS-2

Customer shall be deemed to have been entitled to such service for the

purposes of this subparagraph 4.45.1 (iii) and shall pay to Company an

amount determined under article 4.0 of Rate Schedule IT-R for the

volumes allocated under this subparagraph 4.45.1 (iii).

4.4.24.5.2 Allocation of Gas Delivered



Attachment C5



been nominated, the aggregate daily quantity of gas delivered to LRS-2 Customer at the

A/BC Delivery Point shall be allocated for billing purposes as follows:

(i) first to Service to LRS-2 Customer under Rate Schedule LRS-2 to a

maximum of Eligible LRS-2 Volumes for the A/BC Delivery Point under

such Rate Schedule LRS-2;

(ii) secondly to service to LRS-2 Customer under Rate Schedule FT-DW and

Rate Schedule STFT to a maximum of such Customer’s allocated FT-DW

Capacity and STFT Capacity for such A/BC Delivery Point under each

such Rate Schedule FT-DW and Rate Schedule STFT;

(iii) thirdly to service to LRS-2 Customer under Rate Schedule FT-D to a

maximum of such Customer’s Delivery Contract Demand for such A/BC

Delivery Point under such Rate Schedule FT-D; and

(iv) fourthly to service to LRS-2 Customer under Rate Schedule IT-D for such

A/BC Delivery Point. If LRS-2 Customer is not entitled to service under

Rate Schedule IT-D at such A/BC Delivery Point, LRS-2 Customer shall

be deemed to have been entitled to such service for the purposes of this

subparagraph 4.45.2 (iv) and shall pay to Company an amount determined

under article 4.0 of Rate Schedule IT-D for the quantities allocated under

this subparagraph 4.45.2 (iv).

5.0 TERM OF SERVICE AGREEMENT

5.1 The term of the Service Agreement under Rate Schedule LRS-2 shall commence on the

effective date of the Board's Order approving Service under Rate Schedule LRS-2 and

shall expire on October 31, 2013, provided however nothing herein shall relieve LRS-2

Customer or Company from any obligation which arose or accrued on or prior to

Attachment C5


Effective Date: November January 1, 2010 2011

Gas for each Receipt Point at which Customer is entitled to Service under any Rate

Schedule, determined as follows:

MOC = V x Z

Where:

“MOC” = the monthly charge for Over-Run Gas at such Receipt Point;

“V” = total volume of gas allocated to Customer by Company as Over-

run Gas in accordance with paragraph 4.5 6 for Service under all

Rate Schedules at such Receipt Point for such Billing Month; and

“Z” = the IT-R Rate at such Receipt Point.







4.44.5 Aggregate Charge For Service


(i) the sum of the amounts calculated in accordance with paragraphs 4.1 and

4.3; less(ii) the sum of:

Attachment C5


Effective Date: November January 1, 2010 2011




(b) the LRS-3 Billing Adjustment, if any, calculated in accordance

with paragraph 4.2 of this Rate Schedule LRS-3; plus.



Notwithstanding any other provision of this LRS-3 Rate Schedule, any Service

Agreement or General Terms and Conditions of the Tariff, and without regard to how gas

may have been nominated, the aggregate volume of gas received from Customer at a

Receipt Point shall be allocated for billing purposes as follows:

(i) first to service to Customer under Rate Schedules LRS and LRS-3 to a maximum

of such Customer's LRS Contract Demand for such Receipt Point under such Rate

Schedule LRS and to a maximum of such Customer’s LRS-3 Contract Demand

for such Receipt Point under such Rate Schedule LRS-3;



Schedule FT-R;

(iii) thirdly to service to Customer under Rate Schedule FT-RN to a maximum of such

Customer's Receipt Contract Demand for such Receipt Point under Rate Schedule

FT-RN; and

(iv) fourthly to service to Customer under Rate Schedule IT-R at such Receipt Point.

If Customer is not entitled to service under Rate Schedule IT-R at such Receipt

Attachment C5

Attachment C6 Alberta System Tariff Amendments

Clean Copy


Effective Date: January 1, 2011

GENERAL TERMS AND CONDITIONS

Article Title Page

1.0 DEFINITIONS............................................................................................................. 2

2.0 MEASURING EQUIPMENT.................................................................................... 19

3.0 GAS QUALITY......................................................................................................... 21

4.0 MEASUREMENT ..................................................................................................... 23

5.0 BILLING AND PAYMENT...................................................................................... 26

6.0 POSSESSION AND CONTROL............................................................................... 28

7.0 GAS PRESSURES..................................................................................................... 28

8.0 GAS USED, GAS LOST AND MEASUREMENT VARIANCE ............................ 29

9.0 DELIVERY OBLIGATION...................................................................................... 30

10.0 FINANCIAL ASSURANCES ................................................................................... 32

11.0 INTERRUPTIONS AND CURTAILMENTS........................................................... 34

12.0 FORCE MAJEURE ................................................................................................... 38

13.0 INDEMNIFICATION................................................................................................ 41

14.0 EXCHANGE OF INFORMATION........................................................................... 42

15.0 MISCELLANEOUS PROVISIONS.......................................................................... 42

Attachment C6



GENERAL TERMS AND CONDITIONS

1.0 DEFINITIONS

In this Tariff:

1.1 “Act” shall mean the National Energy Board Act.

1.2 “Annual Plan” shall mean a document prepared by Company outlining the planned

Facility additions and major modifications as determined by Company.

1.3 “Banking Day” shall mean any day that the Royal Bank of Canada, Main Branch,

Calgary, Canada, or other financial institutions agreed to by Company, conducts

business.

1.4 “Billing Commencement Date” shall mean the earlier of:

(a) the Ready for Service Date; and

(b) the date Company commences to provide Service to Customer pursuant to a

Service Agreement or Schedule of Service.

1.5 “Billing Month” shall mean that month which immediately precedes the month in which

Company is required to provide a bill for Service.

1.6 “Board” shall mean the National Energy Board.

1.7 “Central Clock Time” or “CCT” shall mean the clock time in the Central Zone.

1.8 “Closing Date” shall mean the date an open season ends as posted by Company.

1.9 “CO2 Volume” shall mean the portion of the total excess volume of carbon dioxide

allocated by a CSO to a Customer at a particular Receipt Point for any month under a

Schedule of Service for Service under Rate Schedule CO2. The total excess volume of

carbon dioxide at a Receipt Point for any month shall be determined by Company as

follows:

Attachment C6



Total Excess CO2 Volume = A x ( B - C )

Where:

“A” = the total volume of gas received by Company at such Receipt Point;

“B” = the percentage of carbon dioxide by volume of gas received as determined

by Company at such Receipt Point; and

“C” = two (2) percent.

If “B” is less than or equal to “C”, the Total Excess CO2 Volume shall be zero.

1.10 “CO2 Rate” shall mean the CO2 Rate in the Table of Rates, Tolls and Charges which has

been fixed by Company or the Board for Service under Rate Schedule CO2.

1.11 “Common Stream Operator” or “CSO” shall mean the person who, with respect to a

Receipt Point:

(i) provides Company with the estimates of Flow at the Receipt Point;

(ii) provides Company with the allocation of the estimated Flow and Total Quantity

for the Receipt Point to each Customer receiving Service at the Receipt Point; and

(iii) accepts Nominations made by Company on behalf of Customers and confirms the

availability of gas to meet Customer’s Nominations.

1.12 “Company” shall mean NOVA Gas Transmission Ltd. and any successor to it.

1.13 “Company’s Gas Use Price” shall mean the monthly weighted average of the

“AECO/NGX Intra-Alberta Same Day Index Values” for every day of the month

recorded by the Natural Gas Exchange Inc. (or its successor) as published on its website

(or any replacement thereof) for the Billing Month multiplied by the average heating

value of all physical gas received by Company for the Billing Month.

Attachment C6



1.14 “Connecting Pipeline Operator” or “CPO” shall mean the person who, with respect to a

Delivery Point, places Nominations with Company on behalf of Customers.

1.15 “Cubic Metre of Gas” shall mean that quantity of gas which, at a temperature of fifteen

(15) degrees Celsius and at an absolute pressure of one hundred one and three hundred

twenty-five thousandths (101.325) kiloPascals occupies a volume of one cubic metre.

1.16 “Customer” shall mean any Person named as a Customer in a Service Agreement or

Schedule of Service.

1.17 “Customer Account” shall mean an account established by Company for Customer to

record Customer’s transactions related to Service under one or more Rate Schedules.

1.18 “Customer’s Inventory” shall mean, for each Customer Account at a given time on a day,

an estimated energy amount determined by Company as follows:

CI = (A + B) - (C + D) - E ± F

Where:

“CI” = the Customer’s Inventory;

“A” = the gas received by Company from Customer at all of Customer’s

Receipt Points;

“B” = the gas received by Customer from another Customer through title

transfers;

“C” = the gas delivered by Company to Customer at all of Customer’s

Delivery Points;

“D” = the gas delivered by Customer to another Customer through title

transfers;

Attachment C6



“E” = the gas allocated to Customer for Gas Used, Gas Lost, and

Measurement Variance; and

“F” = the daily recovery of Customer’s Inventory imbalance as a result

of:

(i) any differences in measurement or allocations between the

daily estimated gas received by Company from Customer at

all of Customer’s Receipt Points and the month end actual

quantity of gas received by Company from Customer at

such Receipt Points;

(ii) any differences in measurement or allocations between the

daily estimated quantity of gas delivered by Company to

Customer at all of Customer’s Delivery Points and the

month end actual gas delivered by Company to Customer at

such Delivery Points;

(iii) any corrections due to measurement or allocations of gas for

any prior months; and

(iv) Company’s administration of Customer’s Inventory at

month end pursuant to paragraphs 8.2 and 8.3 in Appendix

“D” of the Tariff.

1.19 “Daily Open Season” shall have the meaning attributed to it in subparagraph 2.6.1 of

Appendix “A” of the Tariff.

1.20 “Daily Open Season Bid Form” shall have the meaning attributed to it in subparagraph

2.6.2(a) of Appendix “A” of the Tariff.

1.21 “Day” shall mean a period of twenty-four (24) consecutive hours, beginning and ending

at eight hours (08:00) Mountain Standard Time.

Attachment C6



1.22 “Delivery Contract Demand” shall mean the maximum quantity of gas, expressed in GJ,

Company may be required to deliver to Customer at the Delivery Point on any Day,

under a Schedule of Service.

1.23 “Delivery Demand Charge” shall have the meaning attributed to it in subparagraph 4.2.2

(ii) of Rate Schedule LRS.

1.24 “Delivery Design Area” or “DDA” shall mean each of:

(i) the Northwest Alberta and Northeast B.C. Area;

(ii) the Northeast Alberta Area;

(iii) the Southwest Alberta Area;

(iv) the Southeast Alberta Area; and

(v) Edmonton and Area.

as described in Company’s current Annual Plan. The Delivery Design Areas may be

amended from time to time by Company in consultation with the Tolls, Tariff, Facilities

and Procedures Committee (or any replacement of it), provided Company has given six

(6) months Notice of such amendment to its Customers.

1.25 “Delivery Point” shall mean the point where gas may be delivered to Customer by

Company under a Service Agreement or Schedule of Service.

1.26 “EDO” shall mean an emergency diversion order, or direction, of the Energy Resources

Conservation Board that requires Company to divert gas pursuant to Section 9 of the Gas

Resources Preservation Act, RSA 2000, Chapter G-4, as amended, superseded or

replaced from time to time.

1.27 “Effective LRS Rate” shall mean the Effective LRS Rate set forth in the Table of Rates,

Tolls and Charges which has been fixed by Company or the Board for Service under Rate

Schedule LRS.

1.28 “Eligible LRS Contract Demand” shall have the meaning attributed to it in subparagraph

4.2.1 of Rate Schedule LRS.

Attachment C6



1.29 “Eligible LRS-3 Contract Demand” shall have the meaning attributed to it in

subparagraph 4.2.1 of Rate Schedule LRS-3.

1.30 “Eligible LRS-2 Volume” shall have the meaning attributed to it in subparagraph 4.3.2 of

Rate Schedule LRS-2.

1.31 “Eligible Points to Point Volume” shall mean for each Schedule of Service under Rate

Schedule FT-P, the lesser of:

(i) the sum of each Points to Point Contract Demand in effect for all or a

portion of the Billing Month multiplied by the number of days that the

Customer was entitled to such Points to Point Contract Demand under

such Schedule of Service in such month;

(ii) the actual volume of gas received by Company from Customer at the

Receipt Points under such Schedule of Service; or

(iii) the actual volume of gas delivered by Company to Customer at the

Delivery Point under such Schedule of Service.

1.32 “ERC Adjustment” shall have the meaning attributed to it in Appendix “G” of the tariff.

1.33 “ERC Event” shall have the meaning attributed to it in Appendix “G” of the Tariff.

1.34 “Existing Capacity” shall have the meaning attributed to it in paragraph 2.1 of Appendix

“A” of the Tariff.

1.35 Existing Capacity Open Season” shall have the meaning attributed to it in paragraph 2.1

of Appendix “A” of the Tariff.

1.36 “Expansion Capacity” shall have the meaning attributed to it in paragraph 3.1 of


1.37 “Expansion Capacity Open Season” shall have the meaning attributed to it in paragraph

3.1 of Appendix “A” of the Tariff.

Attachment C6



1.38 “Expansion Closing Date” shall have the meaning attributed to it in subparagraph 3.1(c)

of Appendix “A” of the Tariff.

1.39 “Extraction Delivery Point” shall mean the point where gas may be delivered to the

Extraction Plant by Company for Customer under a Schedule of Service.

1.40 “Extraction Plant” shall mean a facility connected to the Facilities where Gas liquids are

extracted.

1.41 “Extraction Receipt Point” shall mean the point where gas may be received from the

Extraction Plant by Company for Customer under a Schedule of Service.

1.42 “Facilities” shall mean Company’s pipelines and other facilities or any part or parts

thereof for the receiving, gathering, treating, transporting, storing, distributing,

exchanging, handling or delivering of gas.

1.43 “Financial Assurance” shall have the meaning attributed to it in paragraph 10.1.

1.44 “Flow” shall mean, with respect to a Receipt Point, the rate in 103m3/d or GJ/d, as the

case may be, that gas is being delivered into Company’s Facilities through such Receipt

Point at any point in time and means with respect to a Delivery Point, the rate in 103m3/d

or GJ/d, as the case may be, that gas is being delivered off Company’s Facilities through

such Delivery Point at any point in time.

1.45 “FT-D Demand Rate” shall mean the FT-D Demand Rate for a particular Delivery Point

in the Table of Rates, Tolls and Charges which has been fixed by Company or the Board

for Service under Rate Schedule FT-D.

1.46 “FT-D3 Sub-Group” shall mean a sub-group of Group 3 Delivery Points determined by

Company and set forth in Customer’s Schedule of Service under Rate Schedule FT-D.

1.47 “FT-DW Bid Price” shall have the meaning attributed to it in article 3.0 of Rate Schedule

FT-DW.

Attachment C6



1.48 “FT-DW Capacity” shall have the meaning attributed to it in paragraph 4.1 of Appendix


1.49 “FT-DW Open Season” shall have the meaning attributed to it in paragraph 4.1 of


1.50 “FT-P Customer Account” shall mean an account established by Company for Customer

to record Customer’s transactions related to Service under Rate Schedule FT-P.

1.51 “FT-P Delivery Credit Rate” shall mean the applicable Delivery Credit Rate set out in the

Table of Rates, Tolls and Charges which has been fixed by Company or the Board for

Service under Rate Schedule FT-P.

1.52 “FT-P Demand Rate” shall mean the FT-P Demand Rate for the distance between the

particular Receipt Points and the particular Delivery Point in the Table of Rates, Tolls


Schedule FT-P.

1.53 “FT-P Receipt Credit Rate” shall mean the applicable Receipt Credit Rate set out in the


Service under Rate Schedule FT-P.

1.54 “FT-R Demand Rate” shall mean the FT-R Demand Rate for a particular Receipt Point in

the Table of Rates, Tolls and Charges which has been fixed by Company or the Board for

Service under Rate Schedule FT-R.

1.55 “FT-RN Demand Rate” shall mean the FT-RN Demand Rate in the Table of Rates, Tolls


Schedule FT-RN for a particular Receipt Point.

1.56 “G-14” shall mean Measurement Canada’s Bulletin G-14, as may be amended from time

to time.

Attachment C6



1.57 “Gas” or “gas” shall mean all natural gas both before and after it has been subjected to

any treatment or process by absorption, purification, scrubbing or otherwise, and includes

all fluid hydrocarbons other than hydrocarbons that can be recovered from a pool in

liquid form by ordinary production methods.

1.58 “GIA” shall mean the Electricity and Gas Inspection Act, R.S.C. 1985, c. E-4, as

amended, and all Regulations issued pursuant to it.

1.59 “Gas Lost” shall mean that quantity of gas determined by Company to be the aggregate

of:

(i) the total quantity of gas lost as a result of a Facilities rupture or leak; and

(ii) any Customer’s Inventory that Company reasonably determines to be

unrecoverable.

1.60 “Gas Used” shall mean that quantity of gas determined by Company to be the total

quantity of gas used by Company in the operation, maintenance and construction of the

Facilities.

1.61 “Gas Year” shall mean a period of time beginning at eight hours (08:00) Mountain

Standard Time on the first day of November in any year and ending at eight hours

(08:00) Mountain Standard Time on the first day of November of the next year.

1.62 “GJ” shall mean gigajoule, or one billion joules.

1.63 “Gross Heating Value” shall mean the total MJ obtained by complete combustion of one

cubic metre of gas with air, the gas to be free of all water vapour and the gas, air and

products of combustion to be at standard conditions of fifteen (15) degrees Celsius and

one hundred one and three hundred twenty-five thousandths (101.325) kiloPascals

(absolute) and all water vapour formed by the combustion reaction condensed to the

liquid state.

Attachment C6



1.64 “Group 1 Delivery Point” shall mean any Delivery Point that interconnects with the

following major downstream pipelines:

(i) TransCanada PipeLines Limited;

(ii) Foothills Pipe Lines Ltd. (B.C.);

(iii) Foothills Pipe Lines Ltd. (Saskatchewan);

(iv) Spectra Energy Transmission; and

(v) Alliance Pipeline Limited Partnership.

1.65 “Group 2 Delivery Point” shall mean any Delivery Point determined by Company that is

not a Group 1 Delivery Point nor a Group 3 Delivery Point.

1.66 “Group 3 Delivery Point” shall mean any Delivery Point that is not a Group 1 Delivery

Point and at which Service is subject to the provisions of paragraph 2.3 of Rate Schedule

FT-D.

1.67 “Group 3 Peak Day Demand Requirement” shall mean the daily flow equivalent of

Customer’s estimated highest four (4) consecutive hour demand during the contract term.

1.68 “Interconnecting Pipeline Open Season” shall have the meaning attributed to it in

subparagraph 2.3.1 of Appendix “A” of the Tariff.

1.69 “IT-D Rate” shall mean the IT-D Rate for a particular Delivery Point in the Table of

Rates, Tolls and Charges which has been fixed by Company or the Board for Service

under Rate Schedule IT-D.

1.70 “IT-R Rate” shall mean the IT-R Rate for a particular Receipt Point in the Table of Rates,

Tolls and Charges which has been fixed by Company or the Board for Service under Rate

Schedule IT-R.

1.71 “J” or “Joule” shall mean the base unit for energy as defined by the International System

of Units (SI).

Attachment C6



1.72 “kPa” or “kiloPascals ” shall mean kiloPascals of pressure (gauge) unless otherwise

specified.

1.73 “Line Pack Gas” shall mean at any point in time that quantity of gas determined by

Company to be the total quantity of gas contained in the Facilities.

1.74 “Low Intervention Trade Transaction” shall have the meaning attributed to it in G-14, as

may be amended from time to time.

1.75 “LRS Billing Adjustment” shall have the meaning attributed to it in subparagraph 4.2.4

of Rate Schedule LRS.

1.76 “LRS Charge” shall have the meaning attributed to it in subparagraph 4.2.3 of Rate

Schedule LRS.

1.77 “LRS Contract Demand” shall mean the maximum daily volume of gas Company may be

required to receive from Customer and deliver at the Empress or McNeill Delivery Point


1.78 “LRS Receipt Point Obligation” shall mean the period determined in subparagraph 6.2 or

6.3 of Rate Schedule LRS as the case may be.

1.79 “LRS-3 Contract Demand” shall mean the maximum daily volume of gas Company may

be required to receive from Customer and deliver at the Empress Delivery Point under a

Schedule of Service for Service under Rate Schedule LRS-3.

1.80 “LRS-3 Demand Rate” shall mean the LRS-3 Demand Rate in the Table of Rates, Tolls


Schedule LRS-3.

1.81 “Mainline Surcharge” shall mean the surcharge defined in the TransCanada PipeLines

Transportation Tariff and set forth in Company’s Table of Rates, Tolls and Charges,

applied to volumes of gas received by Company under Rate Schedules FT-R, FT-RN,

Attachment C6



FT-P, IT-R, LRS, LRS-2 and LRS-3 and collected by Company on behalf of

TransCanada PipeLines Limited.

1.82 “Maximum Carbon Dioxide Volume” shall mean the maximum total excess CO2 Volume

as determined by Company that the Company may be required to accept at a particular

Receipt Point on any day, as set forth in a Schedule of Service under Rate Schedule CO2.

1.83 “Maximum Delivery Pressure” shall mean relative to a Delivery Point the maximum

pressure at which Company may deliver gas to Customer, as set forth in a Schedule of

Service.

1.84 “Maximum Receipt Pressure” shall mean relative to a Receipt Point the maximum

pressure at which Company may require Customer to deliver gas, as set forth in Schedule

of Service.

1.85 “MC” shall mean Measurement Canada, an Agency of Industry Canada.

1.86 “Measurement Variance” shall mean, for any period, after taking into account any

adjustment made in accordance with the provisions of paragraph 2.6 of these General

Terms and Conditions, the energy equivalent of the amount determined as follows:

MV = (A + B + C) - (D + E)

Where:

“MV” = the Measurement Variance;

“A” = the energy equivalent of gas determined by Company to have been

delivered to all Customers during the period;

“B” = the energy equivalent of the aggregate of the Gas Lost and Gas Used

during the period;

“C” = the energy equivalent of Line Pack Gas at the end of the period;

Attachment C6



“D” = the energy equivalent of gas determined by Company to have been

received from all Customers during the period; and

“E” = the energy equivalent of Line Pack Gas at the beginning of the period.

1.87 “MJ” shall mean megajoule, or one million joules.

1.88 “Month” or “month” shall mean a period of time beginning at eight hours (08:00)

Mountain Standard Time on the first day of a calendar month and ending at eight hours

(08:00) Mountain Standard Time on the first day of the next calendar month.

1.89 “Nomination” shall mean, with respect to a Receipt Point or a Delivery Point, a request

for Flow made on behalf of a Customer.

1.90 “Notice” shall have the meaning attributed to it in the applicable Service Agreement.

1.91 “Officer’s Certificate” shall have the meaning attributed to it in subparagraph 4.2.1 of

Rate Schedule LRS for Service under Rate Schedule LRS and subparagraph 4.3.1 of Rate

Schedule LRS-2 for Service under Rate Schedule LRS-2.

1.92 “Open Season Bid Form” shall have the meaning attributed to it in subparagraph 2.2(a) of


1.93 “Over-Run Gas” shall mean, in respect of a Customer in a month, the aggregate quantity

of gas for which an amount for over-run gas is payable by Customer in the Billing

Month.

1.94 “OS Charge” shall mean an OS Charge in the Table of Rates, Tolls and Charges which

has been fixed by Company or the Board for Service under Rate Schedule OS.

1.95 “Person” shall mean and include Company, a Customer, a corporation, a company, a

partnership, an association, a joint venture, a trust, an unincorporated organization, a

government, or department of a government or a section, branch, or division of a

department of a government.

Attachment C6



1.96 “Points to Point Contract Demand” shall mean the maximum volume of gas Company

may be required to receive from Customer at particular Receipt Points and deliver to

Customer at a particular Alberta Delivery Point on any day under a Schedule of Service

under Rate Schedule FT-P.

1.97 “Price Point” shall mean for the purposes of any Service provided under any Schedule of

Service under:

(i) Rate Schedule FT-R or Rate Schedule FT-P, Price Point “A”, Price Point “B”, or

Price Point “C”, each as defined in paragraph 3.2 of Rate Schedule FT-R and Rate

Schedule FT-P; and

(ii) Rate Schedule FT-D, Price Point “X”, Price Point “Y”, or Price Point “Z”, each as

defined in paragraph 3.2 of Rate Schedule FT-D.

1.98 “Primary Term” shall mean for the purposes of any Service provided under any

Schedule of Service under:

(i) Rate Schedule FT-R, the term calculated in accordance with the Criteria for

Determining Primary Term in Appendix “E” of the Tariff;

(ii) Rate Schedule FT-P, for receipt metering facilities, the term calculated in

accordance with the Criteria for Determining Primary Term in Appendix “E” of

the Tariff; and for other facilities, the term as defined in paragraph 5.1 of Rate

Schedule FT-D; and

(iii) Rate Schedule FT-D, the term defined in paragraph 5.1 of Rate Schedule FT-D.

1.99 “Prime Rate” shall mean the rate of interest, expressed as an annual rate of interest,

announced from time to time by the Royal Bank of Canada, Main Branch, Calgary,

Alberta as the reference rate then in effect for determining interest rates on Canadian

dollar commercial loans in Canada.

1.100 “Project Area” shall mean each of:

Attachment C6



(i) the Peace River Project Area;

(ii) the North and East Project Area; and

(iii) the Mainline Project Area,

as described in Company’s current Annual Plan. The Project Areas may be amended

from time to time by Company in consultation with the Tolls, Tariff, Facilities and

Procedures Committee (or any replacement of it), provided Company has given six (6)

months Notice of such amendment to its Customers.

1.101 “PT Gas Rate” shall mean the PT Gas Rate in the Table of Rates, Tolls and Charges

which has been fixed by Company or the Board for Service under Rate Schedule PT,

based on the incremental gas requirements associated with the Facilities required to

provide such Service.

1.102 “PT Rate” shall mean the PT Rate in the Table of Rates, Tolls and Charges which has

been fixed by Company or the Board for Service under Rate Schedule PT, based on the

incremental operating costs associated with providing such Service plus ten percent.

1.103 “Rate Schedule” shall mean any of the schedules identified as a “Rate Schedule”

included in the Tariff.

1.104 “Ready for Service Date” shall mean the Day designated as such by Company by Notice

to Customer stating that Company has Facilities which are ready for and are capable of

rendering the Service applied for by Customer.

1.105 “Receipt Contract Demand” shall mean the maximum volume of gas Company may be

required to receive from Customer at a Receipt Point on any Day, under a Schedule of

Service.

1.106 “Receipt Demand Charge” shall have the meaning attributed to it in subparagraph 4.2.2

(i) of Rate Schedule LRS.

1.107 “Receipt Point” shall mean the point at which gas may be received from Customer by

Company under a Service Agreement or Schedule of Service.

Attachment C6



1.108 “STFT Bid Price” shall have the meaning attributed to it in article 3.0 of Rate Schedule

STFT.

1.109 “STFT Capacity” shall have the meaning attributed to it in paragraph 5.1 of Appendix


1.110 “STFT Capacity Open Season” shall have the meaning attributed to it in paragraph 5.1 of


1.111 “Schedule of Service” shall mean the attachment(s) to a Service Agreement for Service

under any Rate Schedule designated as “Schedule of Service” and any amendments

thereto.

1.112 “Secondary Term” shall mean for the purposes of Service provided under any Schedule

of Service any portion of the term of the Schedule of Service that is not Primary Term.

1.113 “Service” shall have the meaning attributed to it in article 2.0 of the applicable Rate

Schedule.

1.114 “Service Agreement” shall mean an agreement between Company and Customer

respecting Service to be provided under any Rate Schedule.

1.115 “Service Commencement Date” shall mean the service commencement date requested by

Customer on Customer bid.

1.116 “Service Termination Date” shall mean the last Day in a month upon which Service shall

terminate, as set forth in a Schedule of Service and subject to any renewal thereof.

1.117 “Storage Delivery Point” shall mean the point where gas may be delivered to the Storage

Facility by Company for Customer for ultimate receipt from such Storage Facility at the

Storage Receipt Point under a Schedule of Service.

1.118 “Storage Facility” shall mean any commercial facility where gas is stored, that is

connected to the Facilities and is available to all Customers.

Attachment C6



1.119 “Storage Receipt Point” shall mean the point where gas may be received from the

Storage Facility by Company for Customer that was previously delivered to such Storage

Facility at the Storage Delivery Point under a Schedule of Service.

1.120 “Surcharge” shall mean the Mainline Surcharge and any other Surcharge set forth in the


Service under a Rate Schedule.

1.121 “Table of Rates, Tolls and Charges” shall mean the Table of Rates, Tolls and Charges

setting forth rates, tolls and charges that have been fixed by Company or the Board to be

imposed, observed and followed by Company.

1.122 “Tariff” shall mean this Gas Transportation Tariff, including the Table of Rates, Tolls

and Charges, the Rate Schedules, the Service Agreements, Schedules of Service, these

General Terms and Conditions and the Appendices.

1.123 “Tier” shall mean the Tier 1, Tier 2 or Tier 3 CO2 Rate as set forth in the Table of Rates,

Tolls and Charges.

1.124 “TJ” shall mean terajoule, or one trillion joules.

1.125 “Thousand Cubic Metres” or “103m3” shall mean one thousand (1000) Cubic Metres of

Gas.

1.126 “Website” shall mean Company’s internet site operated by TransCanada PipeLines

Limited for Company.

1.127 “Winter Season” shall mean the period commencing on November 1 of any year and

ending on the next succeeding March 31.

Attachment C6



2.0 MEASURING EQUIPMENT

2.1 Installation

Company, at its option, may furnish, install, maintain and operate all measuring

equipment located at each Receipt Point, Delivery Point or other point where gas is

measured.

2.2 Compliance with Standards

Company may use such measuring equipment as it deems appropriate provided that all

measuring equipment shall comply with all applicable requirements under the GIA.

2.3 Check Measuring Equipment

Customer may install and operate check measuring equipment provided that such

equipment does not interfere with the operation of the Facilities.

2.4 Pulsation Dampening

Customer shall provide or cause to be provided such pulsation dampening equipment as

may be necessary to ensure that any facilities upstream of a Receipt Point do not interfere

with the operation of the Facilities.

2.5 Verification

The accuracy of Company’s measuring equipment shall be tested and verified by

Company at such intervals as may be appropriate for such equipment. Reasonable Notice

of the time and nature of each test shall be given to Customer to permit Customer to

arrange for a representative to observe the test and any adjustments resulting from such

test. If, after Notice, Customer fails to have a representative present, the results of the

test shall nevertheless be considered accurate.

Attachment C6



2.6 Correction

If at any time any of the measuring equipment is found to be out of service or registering

inaccurately with the result that a significant measurement error has occurred, such

equipment shall be adjusted as soon as practicable to read as accurately as possible and

the readings of such equipment shall be adjusted to correct for such significant error for a

period definitely known or agreed upon, or if not known or agreed upon, one-half (1/2) of

the elapsed time since the last test. The measurement during the appropriate period shall

be determined by Company on the basis of the best data available using the most

appropriate of the following methods:

(a) by using the data recorded by any check measuring equipment if installed and

accurately registering;

(b) by making the appropriate correction if the deviation from the accurate reading is

ascertainable by calibration test or mathematical calculation;

(c) by estimating based on producer measurements; or

(d) by estimating based on deliveries under similar conditions during a period when

the equipment was measuring accurately.

2.7 Expense of Additional Tests

If Customer requests a test in addition to the tests provided for by paragraph 2.5 and if

upon testing the deviation from the accurate reading is found to be less than two (2)

percent, Customer shall bear the expense of the additional test.

2.8 Inspection of Equipment and Records

Company and Customer shall have the right to inspect measuring equipment installed or

furnished by the other, and the charts and other measurement or test data of the other at

all times during normal business hours upon reasonable Notice, but the reading,

Attachment C6



calibration and adjustment of such equipment and the changing of the charts shall be

done only by the Person installing and furnishing same.

2.9 Quality Equipment and Tests

(a) Company may furnish, install, maintain and operate such equipment as it

considers necessary to ensure that gas received by Company conforms to the

quality requirements set forth in the Tariff.

(b) Company may establish and utilize such reasonable methods, procedures and

equipment as Company determines are necessary in order to determine whether

gas received by Company conforms with the quality requirements set forth in the

Tariff.

3.0 GAS QUALITY

3.1 Quality Requirements

Gas received at a Receipt Point:

(a) shall be free, at the pressure and temperature in the Facilities at the Receipt Point,

from sand, dust, gums, crude oil, contaminants, impurities or other objectionable

substances which will render the gas unmerchantable, cause injury, cause damage

to or interfere with the operation of the Facilities;

(b) shall not have a hydrocarbon dew point in excess of minus ten (-10) degrees

Celsius at operating pressures;

(c) shall not contain more than twenty-three (23) milligrams of hydrogen sulphide per

one (1) cubic metre;

(d) shall not contain more than one hundred and fifteen (115) milligrams of total

sulphur per one (1) cubic metre;

Attachment C6



(e) shall not contain more than two (2) percent by volume of carbon dioxide unless a

valid Service Agreement and Schedule of Service under Rate Schedule CO2 is

executed by Customer and in effect at such Receipt Point;

(f) shall not contain more than:

(i) sixty-five (65) milligrams of water vapour per one (1) cubic metre; or

(ii) forty-eight (48) milligrams of water vapour per one (1) cubic metre if a

valid Service Agreement and Schedule of Service under Rate Schedule

CO2 is executed and in effect at such Receipt Point;

(g) shall not have a water dew point in excess of minus ten (-10) degrees Celsius at

operating pressures greater than eight thousand two hundred seventy five (8275) kPa;

(h) shall not exceed forty-nine (49) degrees Celsius in temperature;

(i) shall be as free of oxygen as practicable and shall not in any event contain more

than four-tenths of one (0.4) percent by volume of oxygen; and

(j) shall have a Gross Heating Value of not less than thirty-six (36) megaJoules per

cubic metre.

3.2 Nonconforming Gas

(a) If gas received by Company fails at any time to conform with any of the quality

requirements set forth in paragraph 3.1 above, then Company shall give Notice to

Customer of such failure and Company may, at Company’s option, refuse to

accept such gas pending the remedying of such failure to conform to quality

requirements. If the failure to conform is not promptly remedied, Company may

accept such gas and may take such steps as Company determines are necessary to

ensure that such gas conforms with the quality requirements and Customer shall

reimburse Company for any reasonable costs and expenses incurred by Company.

Attachment C6



(b) Notwithstanding subparagraph 3.2 (a), if gas received by Company fails to

conform to the quality requirements set forth in paragraph 3.1 above, Company

may at its option immediately suspend the receipt of gas, provided however that

any such suspension shall not relieve Customer from any obligation to pay any

rate, toll, charge or other amount payable to Company.

(c) Notwithstanding subparagraphs 3.2 (a) and 3.2 (b), if gas received by Company

fails to conform to the quality requirements set forth in subparagraph 3.1(e)

above, Company shall give Notice to Customer of such failure. If the failure to

conform is not remedied by Customer within thirty (30) days, Company shall

refuse to accept such gas pending the remedying of such failure, provided

however that any such suspension shall not relieve Customer from any obligation

to pay any rate, toll, charge or other amount payable to Company.

3.3 Quality Standard of Gas Delivered at Delivery Points

Gas which Company delivers at Delivery Points shall have the quality that results from

gas having been transported and commingled in the Facilities.

4.0 MEASUREMENT

4.1 Method of Measurement

Company may make such measurements and calculations and use such procedures as it

deems appropriate in determining volume, provided that the measurements and

calculations made and the procedures used comply with any applicable requirements

under the GIA.

4.2 Unit of Measurement

4.2.1 The unit of volume for purposes of measurement hereunder shall be a Thousand

Cubic Metres.

Attachment C6



4.2.2 The unit of quantity for purposes of measurement hereunder shall be a GJ.

4.3 Atmospheric Pressure

For the purpose of measurement atmospheric pressure shall be determined by a

recognized formula applied to the nearest one hundredth (0.01) kPa absolute and deemed

to be constant at the time and location of measurement.

4.4 Flowing Temperature

The temperature of flowing gas shall be determined by means of a recording thermometer

or other equipment appropriate for the determination of temperature.

4.5 Determination of Gas Characteristics

The gas characteristics including, without limiting the generality of the foregoing, Gross

Heating Value, relative density, nitrogen and carbon dioxide content, shall be determined

by continuous recording equipment, laboratory equipment or through computer

modeling.

4.6 Exchange of Measurement Information

Company and Customer shall make available to the other, as soon as practicable

following written request, all measurement and test charts, measurement data and

measurement information pertaining to the Service being provided to Customer.

4.7 Preservation of Measurement Records

Company and Customer shall preserve all measurement test data, measurement charts

and other similar records for a minimum period of six (6) years or such longer period as

may be required by record retention rules of any duly constituted regulatory body having

jurisdiction.

Attachment C6



4.8 Low Intervention Trade Transaction Level

If, pursuant to the GIA and G-14, Company has received from MC, conditional

permission for the use of gas metering equipment without verification and sealing, at the

Low Intervention Trade Transaction level, then the following shall apply:

(a) The Low Intervention Trade Transactions shall be subject to the provisions and

conditions listed in G-14, as published on MC’s website (or any replacement

thereof);

(b) Customer agrees that the gas metering equipment has been initially calibrated and

will be periodically recalibrated (and reprogrammed where necessary) in

accordance with a process and procedures acceptable to Customer;

(c) Any measurement disputes arising between Company and Customer shall be

resolved in accordance with the provisions of paragraph 2.6 of these General

Terms and Conditions;

(d) Company and Customer acknowledge and agree that the conditional permission

granted by MC may restrict MC’s ability to successfully conclude a measurement

dispute investigation, if MC involvement has been requested; and

(e) Company and Customer agree to the implementation of Low Intervention Trade

Transactions in accordance with G-14 and either Company or Customer has the

right to request a revocation of the conditional permission for Low Intervention

Trade Transactions in accordance with G-14.

Attachment C6



5.0 BILLING AND PAYMENT

5.1 Billing

On or before the twenty-first day of each month, Company shall provide on the Website a

bill to Customer for Service rendered during the Billing Month. Customer shall furnish

such information to Company as Company may require for billing on or before the

twenty-first day of the Billing Month.

5.2 Payment

Customer shall make payment to Company in Canadian dollars of its bill on or before the

last day of the month following the Billing Month.

5.3 Late Billing

If Company provides a bill after the twenty-first day of a month, then the date for

payment shall be that day which is ten (10) days after the day that such bill was provided.

5.4 Interest on Unpaid Amounts

Company shall have the right to charge interest on the unpaid portion of any bill

commencing from the date payment was due and continuing until the date payment is

actually received, at a rate per annum equal to the Prime Rate plus one (1) percent. The

principal and accrued interest to date shall be due and payable immediately upon

demand.

5.5 Adjustment Where Bill Estimated

Information used for billing may be actual or estimated. If actual information necessary

for billing is unavailable to Company sufficiently in advance of the twenty-first day of

the month to permit the use of such information in the preparation of a bill, Company

shall use estimated information. In the month that actual information becomes available

respecting a previous month where estimated information was used, the bill for the month

in which the actual information became available shall be adjusted to reflect the

Attachment C6



difference between the actual and estimated information as if such information related to

such later month. Neither Company nor Customer shall be entitled to interest on any

adjustment.

5.6 Corrections

Notwithstanding any provision contained in this Tariff to the contrary, the correction of

an error in a bill for Service provided in a prior month, shall be made to the bill in

accordance with the appropriate provision of this Tariff in effect at the time that the error

was made. Company shall proceed with such correction in the month following the

month that Company confirms the error. In the case of a disputed bill the provisions of

paragraph 5.7 shall apply.

5.7 Disputed Bills

5.7.1 In the event Customer disputes any part of a bill, Customer shall nevertheless pay

to Company the full amount of the bill when payment is due.

5.7.2 If Customer fails to pay the full amount of any bill when payment is due,

Company may upon four (4) Banking Days Notice immediately suspend any or

all Service being or to be provided to Customer provided however that such

suspension shall not relieve Customer from any obligation to pay any rate, toll,

charge or other amount payable to Company. If at any time during such

suspension Customer pays the full amount payable to Company, Company shall

within two (2) Banking Days recommence such suspended Service.

Following suspension, Company may, in addition to any other remedy that may

be available to it, upon four (4) Banking Days Notice to Customer immediately:

(i) terminate any or all Service being or to be provided to Customer; and

(ii) declare any and all amounts payable now or in the future by Customer to

Company for any and all Service to be immediately due and payable as

liquidated damages and not as a penalty.

Attachment C6



5.7.3 In the event that it is finally determined that Customer’s monthly bill was

incorrect and that an overpayment has been made, Company shall make

reimbursement of such overpayment. Company shall pay interest on the

overpayment to Customer, commencing from the date such overpayment was

made and continuing until the date reimbursement is actually made, at a rate per

annum equal to the Prime Rate plus one (1) percent.

6.0 POSSESSION AND CONTROL

6.1 Control

Gas received by Company shall be deemed to be in the custody and under the control of

Company from the time it is received into the Facilities until it is delivered out of the

Facilities.

6.2 Warranty

Customer warrants and represents it has the right to tender all gas delivered to Company.

7.0 GAS PRESSURES

7.1 The Gas Pressure At Receipt Points

The pressure of gas tendered by Customer to Company at any Receipt Point shall be the

pressure, up to the Maximum Receipt Pressure, that Company requires such gas to be

tendered, from time to time, at that Receipt Point.

7.2 Pressure Protection

Customer shall provide or cause to be provided suitable pressure relief devices, or

pressure limiting devices, to protect the Facilities as may be necessary to ensure that the

Attachment C6



pressure of gas delivered by Customer to Company at any Receipt Point will not exceed

one hundred ten (110%) percent of the Maximum Receipt Pressure.

7.3 The Gas Pressure At Delivery Points

The pressure of gas delivered by Company at any Delivery Point shall be the pressure

available from the Facilities at that Delivery Point, provided that such pressure shall not

exceed the Maximum Delivery Pressure.

8.0 GAS USED, GAS LOST AND MEASUREMENT VARIANCE

8.1 Company’s Gas Requirements

Company may, at its option, either:

(a) take from all Customers at Receipt Points a quantity of gas equal to the aggregate

quantity of any or all Gas Used, Gas Lost and Measurement Variance for any

period; or

(b) arrange with a Customer or Customers or any other Persons at Receipt Points to

take and pay for a quantity of gas equal to the aggregate quantity of any or all Gas

Used, Gas Lost and Measurement Variance for any period.

8.2 Allocation of Gas Taken

If Company in any period exercises its option to take a quantity of gas as provided for in

subparagraph 8.1 (a), each Customer’s share of the quantity of such gas taken in such

period will be a quantity equal to the product of the quantity of such gas taken in such

period and a fraction, the numerator of which shall be the aggregate quantity of gas

received by Company from Customer in such period at all of Customer’s Receipt Points

and the denominator of which shall be the aggregate quantity of gas received by

Company from all Customers in such period at all Receipt Points.

Attachment C6



8.3 Gas Received from Storage Facilities

Notwithstanding anything contained in this article 8.0, any gas received into the Facilities

from a gas storage facility that was previously delivered into the gas storage facility

through the Facilities shall not be included in any calculation, and shall not be taken into

account in any allocation, of Company’s gas requirements.

9.0 DELIVERY OBLIGATION

9.1 Company’s Delivery Obligation

Subject to paragraph 9.2:

(a) Company’s delivery obligation for any period where Company has exercised its

option as provided for in subparagraph 8.1 (a), shall be to deliver to all Customers

at all Delivery Points the quantity of gas Company determines was received from

all Customers in such period at all Receipt Points, less all Customers share as

determined under paragraph 8.2; and

(b) Company’s delivery obligation, for any period where Company has exercised its

option to purchase gas as provided for in subparagraph 8.1 (b), shall be to deliver

to all Customers at all Delivery Points the quantity of all gas received from all

Customers, other than gas taken from such Customers and paid for pursuant to

subparagraph 8.1 (b), in such period at all Receipt Points.

9.2 Variance

Due to variations in operating conditions, the aggregate daily and monthly quantities of

gas delivered to all Customers at all Delivery Points, adjusted as provided for in

paragraph 9.1, will differ from the aggregate of the corresponding daily and monthly

quantities of gas received from all Customers. Customers and Company shall co-operate

Attachment C6



to keep such differences to the minimum permitted by operating conditions and to

balance out such differences as soon as practicable.

9.3 Operating Balance Agreements

Company may enter into agreements and other operating arrangements with any operator

of a downstream pipeline facility interconnecting with the Facilities (“downstream

operator”) respecting the balancing of gas quantities to be delivered by Company and to

be received by the downstream operator on any Day at the interconnection of the

downstream facility and the Facilities (the “interconnection point”). This may include

agreements and operating arrangements providing that for any Day a quantity of gas

nominated by a Customer for delivery at the interconnection point may be deemed to

have been delivered by Company and received by the downstream operator regardless of

the actual flow of gas at the interconnection point on the Day.

9.4 Energy Content and Gas Quality

Gas delivered by Company to Customer at any of Customer’s Delivery Points shall have

the energy content and quality that results from the gas having been commingled in the

Facilities.

9.5 Supply/Demand Balancing

The Terms and Conditions Respecting Customer’s Inventories and Related Matters in

Appendix “D” of the Tariff apply to all Service provided under this Tariff. Each

Customer receiving Service is responsible for ensuring that Customer’s Inventory is at all

times within the Balanced Zone set out in Appendix “D”. If Company determines that

Customer’s Inventory for any Customer is not within the Balanced Zone, Company may

upon Notice suspend all or any portion of Service to Customer until Customer brings

Customer’s Inventory within the Balanced Zone, provided however that no such

suspension shall relieve Customer of its obligation to pay any rate, toll, charge or other

amount payable to Company.

Attachment C6



9.6 Balancing Procedures

Company may from time to time establish procedures, consistent with the Terms and

Conditions Respecting Customer’s Inventories and Related Matters set forth in Appendix

“D” of the Tariff.

9.7 Limitation on Delivery Obligation

Company shall be obligated to provide only such Service as can be provided through

Company’s operation of the existing Facilities pursuant to the terms and conditions of the

Tariff.

9.8 Uniform Flow Rate

All deliveries of gas to Company at a Receipt Point shall be made in uniform hourly

quantities to the extent practicable.

9.9 Emergency Response Compensation Event

If there is an ERC Event, Company shall determine Customer’s Final ERC Adjustments

in accordance with the Terms and Conditions Respecting Emergency Response

Compensation set forth in Appendix “G” of the Tariff.

10.0 FINANCIAL ASSURANCES

10.1 Financial Assurance for Performance of Obligations

Company may request that Customer (or any assignee) at any time and from time to time

provide Company with an irrevocable letter of credit or other assurance acceptable to

Company, in form and substance satisfactory to Company and in an amount determined

in accordance with paragraph 10.3 (the “Financial Assurance”).

Attachment C6



10.2 Failure to Provide Financial Assurance

Company may withhold the provision of new Service until Company has received a

requested Financial Assurance.

If Customer fails to provide a requested Financial Assurance to Company within four (4)

Banking Days of Company’s request, Company may upon four (4) Banking Days Notice

immediately suspend any or all Service being or to be provided to Customer provided

however that any such suspension shall not relieve Customer from any obligation to pay

any rate, toll, charge or other amount payable to Company. If at any time during such

suspension Customer provides such Financial Assurance to Company, Company shall

within two (2) Banking Days recommence such suspended Service.

If Customer fails to provide such Financial Assurance during such suspension, Company

may, in addition to any other remedy that may be available to it, upon four (4) Banking

Days Notice to Customer immediately:

(i) terminate any or all Service being or to be provided to Customer; and

(ii) declare any and all amounts payable now or in the future by Customer to

Company for any and all Service to be immediately due and payable as liquidated

damages and not as a penalty.

10.3 Amount of Financial Assurance

The maximum amount of Financial Assurance Company may request from a Customer

(or assignee) shall be as determined by Company an amount equal to:

(i) for the provision of all Services, other than for Service referred to in paragraph

(ii), the aggregate of all rates, tolls, charges or other amounts payable to Company

for a period of seventy (70) Days. Provided however, the amount of Financial

Assurance for all rates, tolls and charges other than demand charges shall be

based on the daily average of the actual charges billed for Service for the

Attachment C6



preceding twelve (12) Month period with the initial forecast to be provided by

Customer; and

(ii) for the provision of Service under subparagraphs 5.1(ii) and 5.1(iii) of Rate

Schedule FT-D, the aggregate of all rates, tolls, charges or other amounts payable

to Company for a period of seventy (70) Days plus one (1) Month for each

remaining year of the term of such Service, up to a maximum of twelve (12)

Months total.

The Financial Assurances for any new Facilities required to be installed or constructed by

Company shall be determined in accordance with an agreement between Company and

Customer for such Facilities.

11.0 INTERRUPTIONS AND CURTAILMENTS

11.1 Planned Interruptions

Provided that Company shall have given Customer at least forty-eight (48) hours Notice,

Company may interrupt, curtail or reduce Service for such periods of time as it may

reasonably require for the purpose of effecting any repairs, maintenance, replacement or

upgrading or other work related to the Facilities.

11.2 Unplanned Interruptions

Notwithstanding paragraph 11.1, in the event of unforeseen circumstances Company may

interrupt, curtail or reduce Service for such periods of time as it may reasonably require

without giving Customer the Notice provided for in paragraph 11.1 provided that

Company shall give Notice of such interruption, curtailment or reduction as soon as is

reasonably possible.

Attachment C6



11.3 Notice of Change in Operations

Customer and Company shall give each other as much Notice as is reasonably possible in

the circumstances of expected temporary changes in the rates of delivery or receipt of

gas, pressures or other operating conditions, together with the expected duration and the

reason for such expected temporary changes.

11.4 Priority During Interruptions

11.4.1 At Receipt Points

During periods of interruption and curtailment Company may reduce any or all

Service at Receipt Points in the following order:

(i) Firstly, Service under Rate Schedules IT-R and IT-S prorata based on

Nominations; and

(ii) Secondly, Service under Rate Schedules FT-R, FT-RN, FT-X, FT-P, LRS,

LRS-2 and LRS-3 prorata based on Receipt Contract Demand. Within the

interrupted and curtailed area as determined by Company, Customer may,

subject to Company’s consent, nominate Customer’s prorated Service at

any Receipt Point or combination of Receipt Points within such area

during the period of interruption and curtailment, provided that the total

volume nominated at each Receipt Point does not exceed:

(a) the sum of Customer’s Receipt Contract Demand for each

Schedule of Service at such Receipt Point for Service under Rate

Schedules FT-R, FT-RN, FT-X, LRS, LRS-2 and LRS-3; or

(b) the Customer’s Receipt Contract Demand for each Receipt Point

for Service under Rate Schedule FT-P.

Attachment C6



11.4.2 At Delivery Points

Subject to paragraph 11.4.3, during periods of interruption and curtailment

Company may reduce any or all Service at Delivery Points in the following order:

(i) Firstly, Service under Rate Schedules IT-D, IT-S and Service nominated

in excess of the Delivery Contract Demand under Rate Schedule FT-D at

Group 3 Delivery Points prorata based on Nominations; and

(ii) Secondly, Service under Rate Schedules FT-D at Group 1 Delivery Points,

FT-D at Group 2 Delivery Points, FT-DW, FT-P, LRS-2 and STFT prorata

based on Delivery Contract Demand and Service under Rate Schedule

FT-X prorata based on Nominations. Within the interrupted and curtailed

area as determined by Company, Customer may, subject to Company’s

consent, nominate Customer’s prorated Service at any Delivery Point or

combination of Delivery Points within such area during the period of

interruption and curtailment, provided that the total volume nominated at

each Delivery Point does not exceed the sum of Customer’s Delivery

Contract Demand for each Schedule of Service at such Delivery Point for

Service under Rate Schedules FT-D, FT-DW, LRS-2, STFT, FT-P and

FT-X; and

(iii) Thirdly, Service under Rate Schedule FT-D at Group 3 Delivery Points

prorata based on Delivery Contract Demand. Within the interrupted and

curtailed area as determined by Company, Customer may, subject to

Company’s consent, nominate Customer’s prorated Service at any

Delivery Point or combination of Delivery Points within such area during

the period of interruption and curtailment, provided that the total volume

nominated at each Delivery Point does not exceed the sum of Customer’s

Delivery Contract Demand for each Schedule of Service at such Delivery

Point under Rate Schedule FT-D.

Attachment C6



11.4.3 At Delivery Points If An EDO

In the event of an EDO, Company may reduce any or all Service at Delivery

Points in the following order:

(i) Firstly, Service under Rate Schedules IT-D and IT-S prorata based on

Nominations;

(ii) Secondly, Service under Rate Schedules FT-D at Group 1 Delivery Points,

FT-D at Group 2 Delivery Points, FT-DW, FT-P, LRS-2 and STFT prorata

based on Delivery Contract Demand and Service under Rate Schedule

FT-X prorata based on Nominations. Within the interrupted and curtailed

area as determined by Company, Customer may, subject to Company’s

consent, nominate Customer’s prorated Service at any Delivery Point or

combination of Delivery Points within such area during the period of

interruption and curtailment, provided that the total volume nominated at

each Delivery Point does not exceed the sum of Customer’s Delivery

Contract Demand for each Schedule of Service at such Delivery Point for

Service under Rate Schedule FT-D, FT-DW, LRS-2, STFT, FT-P and

FT-X; and

(iii) Thirdly, Service under Rate Schedule FT-D at Group 3 Delivery Points

prorata based on Delivery Contract Demand. Within the interrupted and

curtailed area as determined by Company, Customer may, subject to

Company’s consent, nominate Customer’s prorated Service at any

Delivery Point or combination of Delivery Points within such area during

the period of interruption and curtailment.

11.5 Customer’s Obligations

Notwithstanding any other provision in the Tariff, Customer agrees and acknowledges

that any interruption and curtailment shall not under any circumstances suspend or

relieve Customer from the obligation to pay any rate, toll, charge or other amount

Attachment C6



payable to Company.

12.0 FORCE MAJEURE

12.1 Notice of Force Majeure

In the event that either Company or Customer is rendered unable by reason of force

majeure to perform in whole or in part any covenant or obligation in the Tariff, the

performance of such covenant or obligation shall be suspended during the continuance of

such force majeure, except as provided for in paragraph 12.3, upon the following terms

and conditions:

(a) the party claiming suspension shall give Notice to the other party specifying full

particulars of such force majeure as soon as is reasonably possible;

(b) the party claiming suspension shall as far as possible remedy such force majeure

as soon as is reasonably possible; and

(c) the party claiming suspension shall give Notice to the other party as soon as is

reasonably possible after such force majeure has been remedied.

12.2 Events of Force Majeure

For the purposes of these General Terms and Conditions, the term “force majeure” shall

mean any cause not reasonably within the control of the party claiming suspension which

by the exercise of due diligence such party is unable to prevent or overcome, including

but without limiting the generality of the foregoing:

(a) lightning, storms, earthquakes, landslides, floods, washouts, and other acts of

God;

(b) fires, explosions, ruptures, breakages of or accidents to the Facilities;

(c) freezing of pipelines or wells, hydrate obstructions of pipelines or appurtenances

thereto, temporary failure of gas supply;

Attachment C6



(c) freezing of pipelines or wells, hydrate obstructions of pipelines or appurtenances

thereto, temporary failure of gas supply;

(d) shortages of necessary labour, strikes, lockouts or other industrial disturbances;

(e) civil disturbances, sabotage, acts of public enemies, war, blockades, insurrections,

vandalism, riots, epidemics;

(f) arrests and restraints of governments and people;

(g) the order of any court, government body or regulatory body;

(h) an EDO;

(i) inability to obtain or curtailment of supplies of electric power, water, fuel or other

utilities or services;

(j) inability to obtain or curtailment of supplies of any other materials or equipment;

(k) inability to obtain or revocation or amendment of any permit, licence, certificate

or authorization of any governmental or regulatory body, unless the revocation or

amendment of such permit, licence, certificate or authorization was caused by the

violation of the terms thereof or consented to by the party holding the same;

(l) the failure for any reason of a supplier of gas to Customer or a purchaser of gas

from Customer to supply and deliver gas to Customer or to purchase and take

delivery of gas from Customer;

(m) any claim by any third party that any covenant or obligation of such third party is

suspended by reason of force majeure, including without limiting the generality of

the foregoing any such claim by any transporter of gas to, from or for Company or

Customer; and

Attachment C6



(n) any other cause, whether herein enumerated or otherwise, not reasonably within

the control of the party claiming suspension which by the exercise of due

diligence such party is unable to prevent or overcome.

12.3 Customer’s Obligations

Notwithstanding any other provision herein, Customer acknowledges and agrees that the

occurrence of an event of force majeure shall not under any circumstances suspend or

relieve Customer from the obligation to pay any rate, toll, charge or other amount

payable to Company.

12.4 Lack of Funds not Force Majeure

Notwithstanding any other provision herein, Company and Customer agree that a lack of

funds or other financial cause shall not under any circumstances be an event of force

majeure.

12.5 Strikes and Lockouts

Notwithstanding any other provision herein, Company and Customer agree that the

settlement of strikes, lockouts and other industrial disturbances shall be entirely within

the discretion of the party involved.

12.6 Service During Force Majeure

In the event that the provision of Service is curtailed or interrupted by reason of force

majeure, Company may during the continuance of such force majeure provide such

Service as it deems appropriate.

Attachment C6



13.0 INDEMNIFICATION

13.1 Customer’s Liability

Customer shall be liable for and shall indemnify and save harmless Company from and

against any and all claims, demands, suits, actions, damages, costs, losses and expenses

of whatsoever nature arising out of or in any way connected, either directly or indirectly,

with any act, omission or default arising out of the negligence of Customer.

13.2 Company’s Liability

Company shall be liable for and shall indemnify and save harmless Customer from and

against any and all claims, demands, suits, actions, damages, costs, losses and expenses

of whatsoever nature arising out of or in any way connected, either directly or indirectly,

with any act, omission or default arising out of the negligence of Company.

13.3 Limitations

Notwithstanding the provisions of paragraphs 13.1 and 13.2:

(a) Company and Customer shall have no liability for, nor obligation to indemnify

and save harmless the other from, any claim, demand, suit, action, damage, cost,

loss or expense which was not reasonably foreseeable at the time of the act,

omission or default;

(b) Company shall have no liability to Customer, nor obligation to indemnify and

save harmless Customer, in respect of Company’s failure for any reason

whatsoever, other than Company’s wilful default, to provide Service pursuant to

the provisions of Customer’s Service Agreement;

(c) the failure by Company for any reason whatsoever to receive gas from Customer

or deliver gas to Customer shall not suspend or relieve Customer from the

obligation to pay any rate, toll, charge or other amount payable to Company; and

Attachment C6



(d) Company shall have no liability to Customer, nor obligation to indemnify and

save harmless Customer, in respect of Company providing Service to any

Customer under Rate Schedule CO2 and/or Rate Schedule PT.

14.0 EXCHANGE OF INFORMATION

14.1 Provision of Information

Company and Customer shall make available, on request by either made to the other,

certificates, estimates and information as shall be in their possession, and as shall be

reasonably required by the other.

14.2 Additional Information

Notwithstanding paragraph 14.1, Customer shall furnish Company with such estimated

daily, monthly and annual quantities as Company may require, with respect to any Service

provided or to be provided, together with any data that Company may require in order to

design, operate and construct facilities to meet Customer’s requirements.

15.0 MISCELLANEOUS PROVISIONS

15.1 Effect of Headings

The headings used throughout the Tariff are inserted for reference only and are not to be

considered or taken into account in construing any terms or provision nor be deemed in

any way to qualify, modify or explain any term or provision.

15.2 Words in Singular or Plural

In the interpretation of the Tariff words in the singular shall be read and construed in the

plural and words in the plural shall be read and construed in the singular where the

context so requires.

Attachment C6



15.3 Preservation of Rights and Authority Under Act

Notwithstanding any of the provisions of the Tariff, Company and Customer reserve all

their respective rights and authorities under the Act.

15.4 Governing Law

The Tariff shall be governed by and construed in accordance with the laws of the

Province of Alberta and the applicable laws of Canada, and Company and Customers

irrevocably submit to the jurisdiction of the courts of the Province of Alberta for the

interpretation and enforcement of the Tariff.

15.5 Assignment

Customer shall not assign any Service Agreement, Schedule of Service or any Service

without the prior written consent of Company.

15.6 No Interest in Facilities

Customer does not acquire any right to, title to or interest in the Facilities or any part

thereof nor does Company dedicate any portion of the Facilities to Service for any

Customer.

15.7 Forbearance

Forbearance to enforce any provision of the Tariff shall not be construed as a continuing

forbearance to enforce any such provision.

15.8 Inconsistency

In the event that there is any inconsistency between any provision of these General Terms

and Conditions, any provision of any Rate Schedule or any provision of any Service

Agreement, the provision of the Service Agreement shall prevail over the Rate Schedule

which in turn shall prevail over the General Terms and Conditions.

Attachment C6



15.9 Amendment of Service Agreement

No amendment or variation of any term, condition or provision of any Schedule of

Service or Service Agreement shall be of any force or effect unless in writing and signed

by Company.

15.10 Priority for New or Additional Service

Company may from time to time establish procedures respecting priority of entitlement

for Customers seeking new or additional Service.

15.11 Establishment of Procedures and Pilot Projects

Company may from time to time establish procedures, including procedures for carrying

out and evaluating any pilot projects Company determines to be necessary or desirable,

respecting or relating to or affecting any Service or any term, condition or provision

contained within the Tariff.

15.12 Conversion of Service Agreements to Energy Units

Effective November 1, 2006, for any Service Agreements under Rate Schedules FT-D,

FT-DW and STFT, the Delivery Contract Demand set out in each existing Schedule of

Service shall be converted to GJ using the following Delivery Point energy conversion

rates:

Alberta-British Columbia 37.98 MJ per m3

Alberta-Montana 37.71 MJ per m3

Empress 37.52 MJ per m3

McNeill 37.57 MJ per m3

Attachment C6


Rate Schedule


RATE SCHEDULE LRS

LOAD RETENTION SERVICE

1.0 DEFINITIONS

1.1 The capitalized terms used in this Rate Schedule have the meanings attributed to them in

the General Terms and Conditions of the Tariff unless otherwise defined in this Rate

Schedule.

2.0 SERVICE DESCRIPTION

2.1 Subject to the stated terms and conditions, service under Rate Schedule LRS shall mean:

(i) the receipt of gas from Customer at Customer's Receipt Points as

identified in Appendix “1” of this Rate Schedule; and

(ii) the delivery of gas to the Empress and/or the McNeill Delivery Points.

2.2 Subparagraphs (i) and (ii) are collectively referred to as the “Service” which includes

transportation of gas that Company determines necessary to provide services under the

Tariff.

2.3 A standard form Service Agreement for Service under this Rate Schedule LRS is

attached.

Attachment C6


Rate Schedule

3.0 AVAILABILITY

3.1 Service is available to those Customers who signed a precedent agreement with Palliser

Pipeline Inc. prior to December 12, 1996 (the “Palliser Precedent Agreement”) requiring

firm service for the transportation of natural gas. Service under Rate Schedule LRS

involves the receipt of quantities of gas at the Receipt Points authorized under this Rate

Schedule LRS, being those Receipt Points identified in Appendix “1” attached to this

Rate Schedule, and the delivery of such quantities of gas to either the Empress or

McNeill Delivery Points. It is a condition of Service that Customers have or are deemed

to have executed a Service Agreement and Schedule of Service under Rate Schedule

LRS.

3.2 New or additional Service under Rate Schedule LRS at Receipt Points shall be made

available in accordance with the provisions of article 5.0.


4.1 Aggregate of Customer's Monthly Receipt Demand Charge

The aggregate of Customer’s monthly receipt demand charges for a Billing Month for

Service under Rate Schedule LRS at Customer’s Receipt Points as identified in Appendix

“1” shall be equal to the sum of the monthly receipt demand charges for each of

Customer’s Schedules of Service under Rate Schedule LRS, determined as follows:

⎟⎠⎞

⎜⎝⎛ ××= ∑ C

BA)PF(MDC

Where:

“MDC” = the aggregate of the receipt demand charges applicable to such

Schedule of Service for such Billing Month;


Attachment C6


Rate Schedule


“F” = the FT-R Demand Rate applicable to such Schedule of Service;

“P” = Price Point “A” (as defined in Rate Schedule FT-R);

“A” = each LRS Contract Demand in effect for all or a portion of such

Billing Month as set out in such Schedule of Service;

“B” = the number of days in such Billing Month that Customer was

entitled to such LRS Contract Demand under such Schedule of

Service; and

“C” = the number of days in such Billing Month.

4.2 Determination of LRS Billing Adjustment

Customer’s monthly LRS Billing Adjustment for a Billing Month for Service under Rate

Schedule LRS shall be calculated by the application of the following four steps:

(i) determination of the Eligible LRS Contract Demand as described in

subparagraph 4.2.1;

(ii) calculation of the amount that has been charged in respect of the Eligible

LRS Contract Demand using the applicable FT-R Demand Rates and

the volumetric equivalent of the FT-D Demand Rate as described in

subparagraph 4.2.2;

(iii) calculation of the amount that should be charged in respect of Service

under Rate Schedule LRS by applying the Effective LRS Rate to the

Eligible LRS Contract Demand as described in subparagraph 4.2.3; and

Attachment C6


Rate Schedule

(iv) determination of the LRS Billing Adjustment that will be applied to

Customer’s bill, as described in subparagraph 4.2.4, by determining the

difference between the amounts calculated in steps (ii) and (iii).

4.2.1. Determination of Eligible LRS Contract Demand

Eligible LRS Contract Demand will be determined based on the information provided by

Customer by way of an Officer’s Certificate in such form as Company may prescribe from

time to time. Eligibility is achieved only when Customer has provided a valid Officer’s

Certificate which satisfies Company that the requirements under Rate Schedule LRS have

been met. Customer shall provide an Officer’s Certificate no later than the twenty-fifth day

of each Month.

The Eligible LRS Contract Demand will be determined as follows:

ECD = ⎟⎠⎞

⎜⎝⎛ −+

−E

DCBA

Where:

“ECD” = the Eligible LRS Contract Demand;

“A” = the aggregate LRS Contract Demand for Service under Rate

Schedule LRS at the Customer’s Receipt Points identified in

Appendix “1” of this Rate Schedule adjusted as per paragraph 4.1;

“B” = the volumes of gas received by Company under Rate Schedule LRS

verified by an Officer’s Certificate to have been delivered from the

Facilities into a storage facility for Customer;


Attachment C6


Rate Schedule


“C” = the volumes of gas not verified by an Officer’s Certificate to have

been delivered to the Empress or McNeill Delivery Points under

Rate Schedule LRS;

“D” = the volumes of gas under Rate Schedule LRS verified by an

Officer’s Certificate to have been delivered from a storage facility

into the Facilities for Customer (provided that these storage volumes

of gas originated from Customer’s Receipt Points identified in

Appendix “1” of this Rate Schedule for Customer) and were

ultimately delivered to the Empress or McNeill Delivery Points; and

“E” = the average number of days in a month.

4.2.2. Calculation of Amount Charged in respect of the Eligible LRS Contract Demands using

the FT-R Demand Rate(s) and the FT-D Demand Rate

After having determined the Eligible LRS Contract Demand, Company will calculate the

amount that has been charged with respect to paragraph 4.1 of this Rate Schedule LRS.

The amount that has been charged is the sum of:

(i) for all of Customer’s Receipt Points identified in Appendix “1” the

aggregate of the product of the FT-R Demand Rate and Price Point “A” and

the Eligible LRS Contract Demand for each Receipt Point (the “Receipt

Demand Charge”); and

(ii) the volumetric equivalent of the FT-D Demand Rate multiplied by the

Eligible LRS Contract Demand (the “Delivery Demand Charge”).

Attachment C6


Rate Schedule


4.2.3. Calculation of the Amounts To Be Charged for LRS Service

The amount to be paid for Service under Rate Schedule LRS (the “LRS Charge”) will be

the product of the Effective LRS Rate and the Eligible LRS Contract Demand. The

Effective LRS Rate is included in the Table of Rates, Tolls and Charges of this Tariff.

The Effective LRS Rate commences on January 1, 1998 and escalates at the rate of two (2)

per cent per annum starting January 1, 1999.

4.2.4. Determination of LRS Billing Adjustment

The LRS Billing Adjustment will be calculated as follows:

(i) Company will calculate the sum of the Receipt Demand Charge and the

Delivery Demand Charge; and

(ii) Company will calculate the difference between the LRS Charge and the

amount calculated in accordance with subparagraph 4.2.4 (i).

The result of the calculations made in accordance with subparagraph 4.2.4 (ii) shall be the

LRS Billing Adjustment.

Eligible LRS Contract Demand will not be considered for the determination of the LRS

Billing Adjustment unless Customer has satisfied Company in the form of a valid Officer’s

Certificate, that the volumes of gas received were delivered to the Empress and McNeill

Delivery Point within the Month with the exception of any volume of gas to have been

delivered from Facilities into a storage facility.

Attachment C6


Rate Schedule



4.3.1. In the event that Company determines in respect of a Billing Month that Company has

received from Customer, in such Billing Month, a volume of gas at any Receipt Point

identified in Appendix “1” of this Rate Schedule in excess of:

(a) the aggregate of the products obtained when each of the LRS Contract

Demand and LRS-3 Contract Demand in effect for Customer in respect of

Rate Schedules LRS and LRS-3, in such Billing Month, is multiplied by

the number of Days in such month that such LRS Contract Demand and

LRS-3 Contract Demand was in effect; plus

(b) the aggregate of the products obtained when each of the Receipt Contract

Demand in effect for Customer in respect of Rate Schedule FT-R and Rate

Schedule FT-RN, in such Billing Month, is multiplied by the number of

Days in such month that the Receipt Contract Demand was in effect,

then Customer shall pay to Company an amount equal to the product of a volume equal

to such excess and the IT-R Rate for the applicable Receipt Point.







Attachment C6


Rate Schedule


4.5 Aggregate Charge For Service


(i) the amounts calculated in accordance with paragraphs 4.1 and 4.3 less the

sum of:




(b) the LRS Billing Adjustment, if any, calculated in accordance with

paragraph 4.2 of this Rate Schedule LRS; plus


4.6 Allocation of Gas Received

Notwithstanding any other provision of this Rate Schedule, any Service Agreement or

General Terms and Conditions of the Tariff, and without regard to how gas may have

been nominated, the aggregate volume of gas received from Customer at a Receipt Point

shall be allocated for billing purposes as follows:

(i) first to Service to Customer under Rate Schedule LRS to a maximum of such

Customer’s LRS Contract Demand for such Receipt Point under such Rate

Schedule LRS, to service to a maximum of such Eligible LRS-2 Volumes for the

Coleman Receipt Point under such Rate Schedule LRS-2 and to Service to

Customer under Rate Schedule LRS-3 to a maximum of such Customer’s LRS-3

Contract Demand for such Receipt Point under such Rate Schedule LRS-3;

Attachment C6


Rate Schedule




Schedule FT-R;



FT-RN; and



Point, gas shall be allocated as Over-Run Gas and charged in accordance with

paragraph 4.3.

5.0 AVAILABILITY OF NEW SERVICE

New Service under Rate Schedule LRS shall be made available to Customer receiving

Service under this Rate Schedule LRS providing the following conditions are met:

(i) the Receipt Point location is south of Township 34 west of the 4th

meridian and is east of range 29 west of the 4th meridian or is the East

Calgary Receipt Point No. 2007;

(ii) if a new Receipt Point or if new Facilities are required at an existing

Receipt Point, Customer has provided a capital contribution equal in

amount to the capital costs associated with the installation or construction

of any new Facilities;

(iii) gas received from Customer is for ultimate delivery to the Empress and/or

McNeill Delivery Points;

Attachment C6


Rate Schedule


(iv) Customer has signed a precedent agreement with Palliser Pipeline Inc.

prior to December 12, 1996 (the “Palliser Precedent Agreement”)

requiring firm Service for the transportation of natural gas; and

(v) the aggregate of Customer’s Service under this Rate Schedule LRS shall

not exceed the initial volumes and term set out in such Customer’s Palliser

Precedent Agreement and any additional volumes acquired by Customer

pursuant to paragraph 12 of this Rate Schedule.


6.1 The term of a Service Agreement under Rate Schedule LRS shall expire on the date

which is the latest Service Termination Date of Customer’s LRS Receipt Point

Obligations under such Service Agreement.

6.2 The initial term of an LRS Receipt Point Obligation in respect of any Customer Receipt

Point identified in Appendix “1” shall be the period equal to the term set out in

Customer’s Palliser Precedent Agreement.

6.3 The term of an LRS Receipt Point Obligation in respect of any Customer Receipt Point,

where new Service is obtained in accordance with the provisions of article 5.0 of this

Rate Schedule, shall be a period equal to the term specified by Customer, provided that

the minimum term that can be specified is one (1) year, (expressed in whole years) and

provided that the Service Termination Date is no later than December 31, 2017.

7.0 CAPACITY RELEASE

7.1 If Customer desires a reduction of Customer’s LRS Contract Demand for all or any

portion of its Service under a Schedule of Service under Rate Schedule LRS Customer

Attachment C6


Rate Schedule


shall give Notice to Company of its request for such reduction specifying the particular

Receipt Point, Schedule of Service and the LRS Contract Demand available to any other

Person qualifying for Service under Rate Schedule LRS. Company assumes no

obligation to find such Person to assume the LRS Contract Demand that Customer

proposes to make available. If after Notice is given to Company a Person qualifying for

Service under Rate Schedule LRS is found who agrees to assume the LRS Contract

Demand Customer proposes to make available, Company may reduce Customer's LRS

Contract Demand under such Schedule of Service, on terms and conditions satisfactory to

Company, by an amount equal to the LRS Contract Demand specified in a Schedule of

Service, executed by Company and such Person. Notwithstanding such reduction,

Customer shall at Company's sole option pay to Company within the time determined by

Company an amount equal to the net book value of such Facilities in the event Company

retires any Facilities required to provide such Service adjusted for all costs and expenses

associated with such retirement.

8.0 RELIEF FOR MAINLINE RESTRICTIONS

8.1 Company may grant relief to a Customer entitled to Service under Rate Schedule LRS, in

accordance with the Terms and Conditions Respecting Relief for Mainline Capacity

Restrictions in Appendix "B" of the Tariff.

9.0 TRANSFER OF SERVICE BETWEEN RECEIPT POINTS

9.1 If Customer desires to transfer all or any portion of any Service under Rate Schedule LRS

from one Receipt Point to another Receipt Point, Customer shall give Notice to Company

of its request for such transfer specifying the particular Receipt Points and the Service

that Customer wishes to transfer.

9.2 Company shall not be required to permit the transfer requested in paragraph 9.1 if:

Attachment C6


Rate Schedule


(i) the transferred-to Receipt Point location is north of Township 33 west of

the 4th meridian and west of range 28 west of the 4th meridian except for

the East Calgary Receipt Point No. 2007; or

(ii) Company is required to install or construct Facilities at a new Receipt

Point to provide the Service requested unless Customer provides a capital

contribution equal in amount to the capital costs associated with the

installation or construction of new Facilities.

10.0 TITLE TRANSFERS

10.1 A Customer entitled to receive Service under Rate Schedule LRS may transfer all or a

portion of Customer’s Inventory to another Customer or may accept a transfer of all or a

portion of Customer’s Inventory from another Customer provided such Customer is

entitled to receive service under any Rate Schedule that permits title transfers and such

title transfer is in accordance with the Terms and Conditions of Service Respecting Title

Transfers in Appendix “C” of the Tariff.

11.0 ASSIGNMENTS

11.1 Customer shall not be permitted to assign any Service Agreements or Schedule of Service

pertaining to a LRS Contract Demand at a Receipt Point identified in Appendix “1” of

this Rate Schedule unless such assignment is to an affiliate (as defined in the Business

Corporation Act, (Alberta) S.A. 1981, c. B-15 as amended from time to time) or to

another Customer entitled to receive Service under Rate Schedule LRS.

Attachment C6


Rate Schedule


12.0 RENEWAL OF SERVICE

12.1 Provided the Customer shall have given Company Notice advising Company that

Customer desires to renew the term of all or a portion of any Service provided to

Customer under this Rate Schedule LRS at least one (1) year prior to the expiry of the

current term for which Company has agreed to provide such Service, Customer shall be

entitled to renew such Service on a one time basis only for an additional term, which

additional term:

(i) shall not exceed the initial term;

(ii) when added to the initial term shall not exceed twenty (20) years; and

(iii) shall not have a Service Termination Date later than December 31, 2017.

13.0 APPLICATION FOR SERVICE

13.1 Applications for Service under Rate Schedule LRS shall be in such form as Company

may prescribe from time to time.

14.0 GENERAL TERMS AND CONDITIONS

14.1 The General Terms and Conditions of the Tariff and the provisions of any Service

Agreement for Service under Rate Schedule LRS are applicable to Rate Schedule LRS to

the extent that such terms and conditions and provisions are not inconsistent with this

Rate Schedule.

Attachment C6


Rate Schedule


APPENDIX 1 TO RATE SCHEDULE LRS RECEIPT POINT STATION NUMBER

Alderson 1075 Atlee Buffalo East 1116 Atlee Buffalo South 1098 Atusis Creek 1792 Atusis Creek East 1792 Badger East 1275 Bantry NE 1296 Bantry North 1122 Bantry NW 1181 Bassano South 1330 Bassano South #2 1794 Berry-Carolside 1085 Berry Creek East 1136 Bowell South 1318 Bowmanton 1216 Carbon 1170 Cassils 1315 Cavalier 1737 Cessford Burfield West 1027 Cessford West 1012 Countess 1028 Countess South 1155 Countess South #2 2296 Countess West 1287 Countess Makepeace 1015 East Calgary 2007 Gatine 1623 Gayford 1358 Gem South 1435 Gem West 1490 Gleichen 1480 Hilda West 1402 Hussar Chancellor 1016 Iddlesleigh South 1277 Jenner West 1099 Lake Newell East 1210 Lonesome Lake 1768 Louisiana Lake 1366 Makepeace North 1419 Makepeace South 1419 Matzhiwin South 1379 Matzhiwin West 1150 Medicine Hat East 1186 Medicine Hat South #2 1043 Nightingale 1747

Attachment C6


Rate Schedule


APPENDIX 1 TO RATE SCHEDULE LRS (continued)

Patricia West 1289 Princess South 1327 Princess West 1183 Rainier South 1378 Rainier SW 1380 Rosemary 1466 Rosemary North 1461 Schuler 1263 Standard 1534 Stanmore South 1156 Suffield 1202 Suffield East 1200 Suffield West 1423 Tide Lake 1348 Trochu 1574 Twelve Mile Coulee 1699 Vale 154 Vale East 1212 Verger 1056 Verger-Millicent 1203 Vulcan 1076 Wayne-Dalum 1039 Wayne-Rosebud 1107 Wintering Hills 1070

Attachment C6


Service Agreement


SERVICE AGREEMENT

RATE SCHEDULE LRS

BETWEEN:

NOVA Gas Transmission Ltd., a body corporate having an office in

Calgary, Alberta (“Company”)

- and -

•, a body corporate having an office in •, • (“Customer”)

IN CONSIDERATION of the premises and the covenants and agreements herein contained, the

parties covenant and agree as follows:

1. Customer acknowledges receipt of a current copy of the Tariff.

2. The capitalized terms used in this Service Agreement have the meanings attributed to

them in the General Terms and Conditions of the Tariff, unless otherwise defined.

3. Customer requests and Company agrees to provide Service pursuant to Rate Schedule

LRS in accordance with the attached Schedules of Service. The Service will commence

on the Billing Commencement Date and will terminate, subject to the provisions of this

Service Agreement, on the Service Termination Date.

Attachment C6


Service Agreement


4. Customer agrees to pay to Company each Billing Month, for all Service rendered under

this Service Agreement, an amount equal to the aggregate charges for Service described

in Rate Schedule LRS.

5. Customer shall:

(a) provide such assurances and information as Company may reasonably require

respecting any Service to be provided pursuant to Rate Schedule LRS including,

without limiting the generality of the foregoing, an assurance that necessary

arrangements have been made among Customer, producers of gas for Customer,

purchasers of gas from Customer and any other Person relating to such Service,

including all gas purchase, gas sale, operating, processing and common stream

arrangements;

(b) at Company's request provide Company with an assurance that Customer has

provided the Person operating facilities upstream of any Receipt Point in respect

of which Customer has the right to receive Service with all authorizations

necessary to enable such Person to provide Company with all data and

information reasonably requested by Company for the purpose of allocating

volumes of gas received by Company among Company's Customers and to bind

Customer in respect of all such data and information provided; and

(c) represent and demonstrate on a monthly basis that volumes moved under this

service were delivered to either the Empress or McNeill Delivery Points. Should

Customer not demonstrate as required, or should the demonstration be

inadequate or found to be invalid, the resulting credit will not apply for the

subject volumes and associated contract demands.

If Customer fails to provide such assurances and information forthwith following request

by Company, from time to time, Company may at its option, to be exercised by Notice to

Customer, suspend the Service to which such assurances and information relate until

Attachment C6


Service Agreement


such time as Customer provides the assurances and information requested, provided

however that any such suspension of Service shall not relieve Customer from any

obligation to pay any rate, toll, charge or other amount payable to Company.

6. Customer acknowledges that the Facilities have been designed based on certain

assumptions and forecasts described in Company’s Annual Plan, and that interruption

and curtailment of Service may occur if the aggregate gas volume actually received or the

aggregate gas volume actually delivered at the Facilities is different than forecast.

7. Every notice, request, demand, statement, bid or bill provided for in Rate Schedule LRS,

this Service Agreement and the General Terms and Conditions, or any other notice which

either Company or Customer may desire to give to the other (collectively referred to as

“Notice”) shall be in writing and each of them and every payment provided for shall be

directed to the Person to whom given, made or delivered at such Person's address as

follows:

Customer:

•

•

•

Attention: •

Fax: •

Company:

•

•

•

Attention: Customer Account Representative

Fax: •

Attachment C6


Service Agreement


Notice may be given by fax or other telecommunication and any such Notice shall be

deemed to be given four (4) hours after transmission. Notice may also be given by

personal delivery or by courier and any such Notice shall be deemed to be given at the

time of delivery. Any Notice may also be given by prepaid mail and any such Notice

shall be deemed to be given four (4) business days after mailing, Saturdays, Sundays and

statutory holidays excepted. In the event of disruption of regular mail, every payment not

made electronically shall be personally delivered, and any other Notice shall be given by

one of the other stated means.

(a) Notwithstanding the foregoing:

(i) Company may give any Notice on the Website; and

(ii) Company and Customer shall give Notice for the matters listed in the

Notice Schedule for Electronic Commerce in Appendix “F” of the Tariff

via the Website unless the Website is inoperative, in which case Notice

shall be given by any other alternative means set out herein.

Any Notice posted on the Website shall be deemed to be given one (1) hour after

posting.

(b) Notice may also be given by telephone followed immediately by fax, personal

delivery, courier or prepaid mail, and in the case of Company, by posting on the

Website, and any Notice so given shall be deemed to have been given as of the

date and time of the telephone Notice.

8. The terms and conditions of Rate Schedule LRS, the General Terms and Conditions and

Schedule of Service under Rate Schedule LRS are by this reference incorporated into and

made a part of this Service Agreement.

Attachment C6


Service Agreement


IN WITNESS WHEREOF the parties have executed this Service Agreement by their proper

signing officers duly authorized in that behalf all as of the • day of , • •.

• NOVA Gas Transmission Ltd.

Per: Per :

Per: Per :

Attachment C6


Schedule of Service


SCHEDULE OF SERVICE RATE SCHEDULE LRS

CUSTOMER: •

Schedule of Service Number

Receipt Point

Number and Name

Legal

Description

Maximum Receipt

Pressure kPa

Service

Termination Date

LRS Contract Demand 103m3/d

LRS Term

Additional Conditions

• • • • • • • •

THIS SCHEDULE FORMS PART OF THE SERVICE AGREEMENT DATED • AND SHALL BE DEEMED TO BE ATTACHED THERETO. • NOVA Gas Transmission Ltd. Per: Per : Per: Per :

Attachment C6



RATE SCHEDULE LRS-2

LOAD RETENTION SERVICE - 2

1.0 DEFINITIONS



Schedule.

2.0 SERVICE DESCRIPTION AND AVAILABILITY

2.1 Subject to the stated terms and conditions, service under Rate Schedule LRS-2 shall

mean:

(i) the daily receipt of gas from LRS-2 Customer at the Coleman receipt point

located at SW-l/4-12-08-05-W5M (the "Coleman Receipt Point");

(ii) the daily transportation of such gas through the Facilities; and

(iii) the daily delivery of such gas to LRS-2 Customer at the Alberta-British

Columbia delivery point located at LSD-12-08-05-W5M (the

"A/BC Delivery Point").

Subparagraphs (i), (ii) and (iii) are collectively referred to as the “Service”.

2.2 The Service is available to Northstar Energy Corporation and assignees of it (the "LRS-2

Customer") provided the assignment complies with article 9.0. It is a condition of

Service that LRS-2 Customer has executed a Service Agreement and Schedule of Service

under Rate Schedule LRS-2. A standard form Service Agreement for Service under this

Attachment C6



Rate Schedule LRS-2 is attached.

3.0 SERVICE ENTITLEMENT

3.1 Company shall provide LRS-2 Customer with gas transportation service up to:

(i) 1127 103m

3/d (40 MMcf/d) from date of commencement of Service under

Rate Schedule LRS-2 to December 31, 1999;

(ii) 1550 103m

3/d (55 MMcf/d) from January 1, 2000 to December 31, 2000;

(iii) 2113 103m

3/d (75 MMcf/d) from January 1, 2001 to December 31, 2001;

and

(iv) 2817 103m

3/d (100 MMcf/d) from January 1, 2002 to October 31, 2013.

The amount identified in each of the subparagraphs (i) through (iv) shall, for the

applicable period, be referred to as the "Maximum Eligible LRS-2 Volume".

3.2 LRS-2 Customer shall be entitled to increase its then current entitlement to LRS-2 from

time to time by giving Company four (4) months prior Notice of the desired increase,

provided that any such increase shall not result at any time in the LRS-2 Customer's

entitlement to Service under Rate Schedule LRS-2 exceeding the Maximum Eligible

LRS-2 Volume in effect at the end of such four (4) month Notice period. LRS-2

Customer's entitlement to Service under Rate Schedule LRS-2, at any point in time,

determined in accordance with this paragraph 3.2, shall be referred to as "Service

Entitlement''. LRS-2 Customer’s initial Service Entitlement shall be 1127 103m

3/d (40

MMcf/d), and LRS-2 Customer's Service Entitlement shall never be less than be 1127

103m

3/d (40 MMcf/d).

Attachment C6








4.2 Determination of Monthly Charge

LRS-2 Customer will be charged and shall pay a monthly amount (the "Monthly

Charge") for a Billing Month equal to the sum for all days of such month of the following

amounts:

(i) the daily equivalent of the FT-R Demand Rate at the Coleman Receipt

Point multiplied by Price Point “A” (as defined in Rate Schedule FT-R)

multiplied by the Service Entitlement for the day in the Billing Month;

(ii) the daily volumetric equivalent of the FT-D Demand Rate at the A/BC

Delivery Point multiplied by the Service Entitlement for the day in the

Billing Month; and

(iii) the amounts calculated in accordance with paragraph 4.1.

4.3 Determination of the LRS-2 Adjustment

The LRS-2 Adjustment for a Billing Month shall be equal to the Monthly Charge for

such Billing Month less $50,000. The LRS-2 Adjustment shall then be applied against

LRS-2 Customer's invoice issued in the second month following the Billing Month.

Attachment C6



4.4 Determination of Eligible LRS-2 Volume

4.4.1 Officer's Certificate

LRS-2 Customer shall provide Company with a valid officer's certificate setting out the

Eligible LRS-2 Volume for each day in a Billing Month, in such form as Company may

prescribe from time to time (the "Officer's Certificate") on or before the last day of the

month following the Billing Month, for purposes of determining the Eligible LRS-2

Volume.

4.4.2 Eligible LRS-2 Volume

The volume of gas eligible for Service under this Rate Schedule LRS-2 (the "Eligible

LRS-2 Volume") for each day, as set forth in the Officer's Certificate, shall be equal to

the lesser of:

(i) the actual volume of gas received by Company from LRS-2 Customer at

the Coleman Receipt Point on each day in a Billing Month up to the

Service Entitlement; and

(ii) the actual volumetric equivalent of LRS-2 Customer's allocation of gas to

be delivered to the A/BC Delivery Point for Service under Rate Schedule

LRS-2 on such day up to the Service Entitlement.

In the event that LRS-2 Customer fails to provide Company with an Officer's Certificate

as provided herein, the Eligible LRS-2 Volume shall be deemed to be zero.

Attachment C6



4.5 Allocation of Gas




been nominated, the aggregate daily volume of gas received from LRS-2 Customer at the

Coleman Receipt Point shall be allocated for billing purposes as follows:

(i) first to Service to LRS-2 Customer under Rate Schedule LRS-2, to a

maximum of Eligible LRS-2 Volumes for the Coleman Receipt Point

under Rate Schedule LRS-2;

(ii) secondly to service to LRS-2 Customer under Rate Schedule FT-R to a

maximum of such Customer’s Receipt Contract Demand for such

Coleman Receipt Point under such Rate Schedule FT-R;

(iii) thirdly to service to LRS-2 Customer under Rate Schedule FT-RN to a

maximum of such Customer's Receipt Contract Demand for such Coleman

Receipt Point under Rate Schedule FT-RN; and

(iv) fourthly to service to LRS-2 Customer under Rate Schedule IT-R for such

Coleman Receipt Point. If LRS-2 Customer is not entitled to service

under Rate Schedule IT-R at such Coleman Receipt Point, LRS-2

Customer shall be deemed to have been entitled to such service for the

purposes of this subparagraph 4.5.1 (iii) and shall pay to Company an

amount determined under article 4.0 of Rate Schedule IT-R for the

volumes allocated under this subparagraph 4.5.1 (iii).

Attachment C6



4.5.2 Allocation of Gas Delivered



been nominated, the aggregate daily quantity of gas delivered to LRS-2 Customer at the

A/BC Delivery Point shall be allocated for billing purposes as follows:

(i) first to Service to LRS-2 Customer under Rate Schedule LRS-2 to a

maximum of Eligible LRS-2 Volumes for the A/BC Delivery Point under

such Rate Schedule LRS-2;

(ii) secondly to service to LRS-2 Customer under Rate Schedule FT-DW and

Rate Schedule STFT to a maximum of such Customer’s allocated FT-DW

Capacity and STFT Capacity for such A/BC Delivery Point under each

such Rate Schedule FT-DW and Rate Schedule STFT;

(iii) thirdly to service to LRS-2 Customer under Rate Schedule FT-D to a

maximum of such Customer’s Delivery Contract Demand for such A/BC

Delivery Point under such Rate Schedule FT-D; and

(iv) fourthly to service to LRS-2 Customer under Rate Schedule IT-D for such

A/BC Delivery Point. If LRS-2 Customer is not entitled to service under

Rate Schedule IT-D at such A/BC Delivery Point, LRS-2 Customer shall

be deemed to have been entitled to such service for the purposes of this

subparagraph 4.5.2 (iv) and shall pay to Company an amount determined

under article 4.0 of Rate Schedule IT-D for the quantities allocated under

this subparagraph 4.5.2 (iv).

Attachment C6




5.1 The term of the Service Agreement under Rate Schedule LRS-2 shall commence on the

effective date of the Board's Order approving Service under Rate Schedule LRS-2 and

shall expire on October 31, 2013, provided however nothing herein shall relieve LRS-2

Customer or Company from any obligation which arose or accrued on or prior to

October 31, 2013; and further provided that the LRS-2 Adjustments for the last two

Billing Months of the Service Agreement under Rate Schedule LRS-2 shall be paid by

the Company to LRS-2 Customer on or before December 31, 2013.

6.0 TRANSFER OF LRS-2 SERVICE

6.1 LRS-2 Customer shall not be entitled to transfer all or any portion of Service under Rate

Schedule LRS-2 to any other Receipt Point or Delivery Point. LRS-2 Customer shall not

be entitled to convert Service under Rate Schedule LRS-2 to any other service under any

other Rate Schedule.

7.0 TERM SWAP OF LRS-2 SERVICE

7.1 LRS-2 Customer entitled to receive Service under Rate Schedule LRS-2 shall not be

entitled to swap the Service Termination Date of any Schedules of Service under Rate

Schedule LRS-2 with the Service Termination Date under any Schedule of Service.

8.0 TITLE TRANSFERS

8.1 LRS-2 Customer shall not be entitled to transfer or accept a transfer of Customer’s

Inventory to or from any other Customer.

Attachment C6



9.0 ASSIGNMENTS

9.1 LRS-2 Customer shall only be permitted to assign Service under Rate Schedule LRS-2

under the following conditions:

(i) such assignment is to an affiliate as defined by the Business Corporations

Act, (Alberta) S.A. 1981, c.B-15 as amended from time to time; or

(ii) in the event that LRS-2 Customer divests all or a portion of its interest in the

Coleman gas plant or the reserves which supply such plant, then LRS-2

Customer shall be entitled to assign all or any portion of its Service under

Rate Schedule LRS-2 to the party acquiring such interest provided however;

(a) such assignment does not increase Company's administrative costs related

to the provision of Service under Rate Schedule LRS-2 as determined by

Company acting reasonably; and

(b) Company shall only be required to deal with one (1) party with respect to

any matter regarding the Service under Rate Schedule LRS-2.

10.0 RENEWAL OF SERVICE

10.1 LRS-2 Customer shall not be entitled to renew Service under Rate Schedule LRS-2.

11.0 GAS USED

11.1 In respect of quantities that are transported utilizing Service under Rate Schedule LRS-2,

LRS-2 Customer shall not be charged for nor shall any deduction be made for that

portion of Gas Used which is attributable to gas used for compression. In respect of

quantities that are transported utilizing Service under Rate Schedule LRS-2, Company

Attachment C6



shall also not charge LRS-2 Customer nor shall it make any deduction for that portion of

Gas Used which is attributable to gas used for heating and pipeline losses until

Company's systems are capable of separating Gas Used into the following components:

(i) gas used for compression;

(ii) gas used for heating; and

(iii) pipeline losses.

12.0 AUDIT RIGHTS

12.1 Company shall be entitled to audit, at its sole discretion and expense, at any time it

determines necessary, any and all documents related to any Officer's Certificate and the

contents thereof, in order to verify the accuracy of such Officer's Certificate, provided

that any such audit shall be carried out within 24 months of the month to which such

Officer's Certificate relates.

13.0 PRIORITY DURING INTERRUPTIONS

13.1 For the purposes of paragraph 11.4 of the General Terms and Conditions of the Tariff,

Service under Rate Schedule LRS-2 shall have equal priority to service under Rate

Schedule FT-R, FT-RN, FT-P, FT-X, STFT, LRS, LRS-3, service at Group 1 Delivery

Points and Group 2 Delivery Points under Rate Schedule FT-D, and FT-DW as the case

may be.

Attachment C6





Agreement for Service under Rate Schedule LRS-2 are applicable to Rate Schedule

LRS-2 to the extent that such terms and conditions and provisions are not inconsistent

with Rate Schedule LRS-2.

Attachment C6

NOVA Gas Transmission Ltd. LRS-2 Service Agreement


SERVICE AGREEMENT

RATE SCHEDULE LRS-2

BETWEEN:

NOVA Gas Transmission Ltd., a body corporate having an office in Calgary,

Alberta (“Company”)

- and -






them in the General Terms and Conditions of the Tariff, unless otherwise defined in this

Service Agreement.


LRS-2 in accordance with the attached Schedules of Service. The Service will

commence on the effective date of the Board's Order approving Service under Rate

Schedule LRS-2 and will terminate, subject to the provisions of this Service Agreement,

Attachment C6



on the Service Termination Date.



in Rate Schedule LRS-2.

5. Customer shall:


respecting any Service to be provided pursuant to Rate Schedule LRS-2

including, without limiting the generality of the foregoing, an assurance that

necessary arrangements have been made among Customer, producers of gas for

Customer, purchasers of gas from Customer and any other Person relating to such

Service, including all gas purchase, gas sale, operating, processing and common

stream arrangements; and


provided the Person operating facilities upstream of any Receipt Point or

downstream of any Delivery Point in respect of which Customer has the right to

receive service with all authorizations necessary to enable such Person to provide

Company with all data and information reasonably requested by Company for the

purpose of allocating quantities of gas received or delivered by Company among

Company's Customers and to bind Customer in respect of all such data and

information provided; and

(c) provide the Officer's Certificate as defined in 4.3.1 of Rate Schedule LRS-2.

If Customer fails to provide such assurances and information forthwith following

request by Company, from time to time, Company may at its option, to be

exercised by Notice to Customer, suspend the Service to which such assurances

and information relate until such time as Customer provides the assurances and

information requested, provided however that any such suspension of Service

Attachment C6



shall not relieve Customer from any obligation to pay any rate, toll, charge or

other amount payable to Company.


assumptions and forecasts described each year in Company’s Annual Plan, and that

interruption and curtailment of Service may occur if the aggregate gas quantity actually

received or the aggregate gas quantity actually delivered at the Facilities is different than

forecast..

7. Every notice, request, demand, statement, bid or bill provided for in Rate Schedule LRS-

2, this Service Agreement and the General Terms and Conditions, or any other notice

which either Company or Customer may desire to give to the other (collectively referred

to as “Notice”) shall be in writing and each of them and every payment provided for shall

be directed to the Person to whom given, made or delivered at such Person's address as

follows:

Customer:

•

•

•

Attention: •

Fax: •

Company:

•

•

•


Fax: •

Attachment C6


















posting.





8. The terms and conditions of Rate Schedule LRS-2, the General Terms and Conditions

and Schedule of Service under Rate Schedule LRS-2 are by this reference incorporated

into and made a part of this Service Agreement.

Attachment C6




signing officers duly authorized in that behalf all as of the • day of •, •.


Per: Per : Per: Per :

Attachment C6

NOVA Gas Transmission Ltd. LRS-2 Schedule of Service


SCHEDULE OF SERVICE RATE SCHEDULE LRS-2

CUSTOMER: •

Schedule of Service Number

Receipt Point Number and Name

Delivery Point

Number and Name

Legal Descriptions

Maximum Receipt / Delivery Pressures

kPa

Service Termination

Date

LRS-2

Contract Demand 103m3/d


• 2003 Coleman SW-12-008-05-W5 6205 October 31, 2013 • •

2001 Alberta/BC 09-11-008-05-W5 6205


Attachment C6



RATE SCHEDULE LRS-3

LOAD RETENTION SERVICE – 3

1.0 DEFINITIONS



Schedule.

2.0 SERVICE DESCRIPTION

2.1 Subject to the stated terms and conditions, service under Rate Schedule LRS-3 shall

mean:

(i) the receipt of gas from Customer at Customer's Receipt Points as

identified in Appendix “1” of this Rate Schedule and any new Receipt

Points made available in accordance with Article 5.0 (the “LRS-3 Receipt

Points”); and

(ii) the delivery of gas to the Empress Delivery Point.

2.2 Subparagraphs (i) and (ii) are collectively referred to as the “Service” which includes

transportation of gas that Company determines necessary to provide services under the

Tariff.

2.3 A standard form Service Agreement for Service under this Rate Schedule LRS-3 is

attached.

Attachment C6


3.0 AVAILABILITY

3.1 Service is available to Petro-Canada Oil and Gas, a general partnership (“Petro-Canada”)

and any assignees thereof in accordance with Article 11.0. It is a condition of Service

that Customers have or are deemed to have executed a Service Agreement and Schedule

of Service under Rate Schedule LRS-3. The aggregate LRS-3 Contract Demand shall not

exceed 1410.0 103m3/d (50 MMcf/d).

3.2 New LRS-3 Receipt Points or additional Facilities required at existing Receipt Points for

Service under Rate Schedule LRS-3 shall be made available in accordance with the

provisions of Article 5.0.


4.1 Aggregate of Customer's Monthly Receipt Demand Charge

The aggregate of Customer’s monthly receipt demand charges for a Billing Month for

Service under Rate Schedule LRS-3 at Customer’s LRS-3 Receipt Points shall be equal

to the sum of the monthly receipt demand charges for each of Customer’s Schedules of

Service under Rate Schedule LRS-3, determined as follows:

⎟⎠⎞

⎜⎝⎛ ××= ∑ C

BA)PF(MDC

Where:

“MDC” = the aggregate of the receipt demand charges applicable to such

Schedule of Service for such Billing Month;


Attachment C6



“F” = the FT-R Demand Rate applicable to such Schedule of Service;

“P” = the applicable Price Point in such Schedule of Service (as defined

in Rate Schedule FT-R);

“A” = each LRS-3 Contract Demand in effect for all or a portion of such

Billing Month as set out in such Schedule of Service;

“B” = the number of days in such Billing Month that Customer was

entitled to such LRS-3 Contract Demand under such Schedule of

Service; and

“C” = the number of days in such Billing Month.

4.2 Determination of LRS-3 Billing Adjustment

Customer’s monthly billing adjustment for a Billing Month for Service under Rate

Schedule LRS-3 (the “LRS-3 Billing Adjustment”) shall be calculated as follows:

(i) determine the Eligible LRS-3 Contract Demand as described in

subparagraph 4.2.1;

(ii) determine the amount that should be charged in respect of Service under

Rate Schedule LRS-3 by applying the LRS-3 Rate to the Eligible LRS-3

Contract Demand as described in subparagraph 4.2.2;

(iii) determine the amount that has been charged in respect of the Eligible

LRS-3 Contract Demand using the applicable FT-R Demand Rates and the

volumetric equivalent of the FT-D Demand Rate as described in

subparagraph 4.2.3;

Attachment C6


(iv) during the Initial LRS-3 Term, determine the amount that should be

adjusted in respect of charges for Service under Rate Schedule IT-R and

Over-run Gas at the LRS-3 Receipt Points as described in subparagraph

4.2.4; and

(v) determine the LRS-3 Billing Adjustment that will be applied to

Customer’s invoice, as described in subparagraph 4.2.5.

4.2.1. Determination of Eligible LRS-3 Contract Demand

Eligible LRS-3 contract demand for each LRS-3 Receipt Point (the “Eligible LRS-3

Contract Demand”) shall be determined by Company as follows:

ECD = E

AAV AVEV ⎟

⎠⎞

⎜⎝⎛ ×

Where:

“ECD” = the Eligible LRS-3 Contract Demand for such LRS-3 Receipt Point;

“EV” = the Eligible LRS-3 Volume as defined below in this paragraph;

“DV” = the Deemed LRS-3 Volume as defined below in this paragraph;

“ADV” = the aggregate of Deemed LRS-3 Volume for all LRS-3 Receipt Points;

and

“E” = the number of days in the month preceding such Billing Month.


Attachment C6



The eligible LRS-3 volume for Service under Rate Schedule LRS-3 for such Billing

Month (the “Eligible LRS-3 Volume”) shall be the lesser of:

(i) the aggregate actual volume of gas delivered by Company for Customer under all

Schedules of Service for Service under all Rate Schedules at the Empress

Delivery Point for the month preceding such Billing Month;

(ii) the aggregate of Customer’s LRS-3 Contract Demand in effect for the month

preceding such Billing Month multiplied by the number of days in the month

preceding such Billing Month that Customer was entitled to such Service under

Rate Schedule LRS-3 at each of Customer’s LRS-3 Receipt Point (the “Available

LRS-3 Volumes”); and

(iii) the aggregate of the volume of gas deemed to be received by Company for

Customer for Service under Rate Schedule LRS-3 for the month preceding such

Billing Month that shall be equal to the sum of the deemed LRS-3 volume of gas

at each of Customer's LRS-3 Receipt Points (the “Deemed LRS-3 Volume”),

determined by Company as follows:

DV = AV + (IT x C)

Where:

“DV’ = the Deemed LRS-3 Volume applicable to such LRS-3 Receipt

Point;

“AV” = the actual volume of gas received by Company for Customer under

Schedules of Service for Service under Rate Schedule LRS-3 at

such LRS-3 Receipt Point (the “Actual LRS-3 Volume”); and

Attachment C6



“IT” = during the Initial LRS-3 Term, the aggregate volume of gas

received by Company for Customer for Service under Rate

Schedule IT-R plus Over-run Gas at all of Customer’s LRS-3

Receipt Points which is deemed to be re-allocated to Service

under Rate Schedule LRS-3 as determined by Company shall be

the lesser of:

a) the aggregate Available LRS-3 Volume for such LRS-3 Receipt

Point less the aggregate Actual LRS-3 Volume for all of

Customer’s LRS-3 Receipt Points (the “Unutilized LRS-3

Volume”); and

b) the aggregate of actual volume of gas received by Company for

Customer for Service under Rate Schedule IT-R and Over-run Gas

as allocated by Company to Customer at all of Customer’s LRS-3

Receipt Points; and

“C” = the percentage of IT to be re-allocated to such LRS-3 Receipt

Point on a pro-rata basis, based on Unutilized LRS-3 Volume.

During the Secondary LRS-3 Term, IT shall be deemed to be zero.

4.2.2. Determination of Amounts To Be Charged in respect of Eligible LRS-3 Contract Demand

The amount to be paid for Service under Rate Schedule LRS-3 (the “LRS-3 Charge”)

will be the product of the LRS-3 Demand Rate and the aggregate Eligible LRS-3

Contract Demand.

Attachment C6



4.2.3. Determination of Customer's Monthly Charge in respect of the Eligible LRS-3 Contract

Demands using the FT-R Demand Rate(s) and the FT-D Demand Rate

Company will calculate an amount that is deemed to be the amount charged in the month

preceding the Billing Month with respect to the Eligible LRS-3 Contract Demand

determined in subparagraph 4.2.1. Such deemed amount shall be the sum of:

(i) for all of Customer’s LRS-3 Receipt Points, the aggregate of the product of

the FT-R Demand Rate, the applicable Price Point and the Eligible LRS-3

Contract Demand for each LRS-3 Receipt Point (the “LRS-3 Receipt

Demand Charge”); and

(ii) the volumetric equivalent of the FT-D Demand Rate multiplied by the

aggregate Eligible LRS-3 Contract Demand (the “LRS-3 Delivery Demand

Charge”).

4.2.4. Determination of Adjustments with respect to IT-R and Over-run Gas Charges

During the Initial LRS-3 Term, Company will determine a monthly commodity charge

adjustment for a Billing Month in respect of charges for Service under Rate Schedule IT-

R and Over-run Gas at the LRS-3 Receipt Points, determined as follows:

MA = A - [(B - C) x D]

Where:

“MA” = the monthly commodity charge adjustment applicable to such Billing

Month;

Attachment C6



“A” = the aggregate of Customer’s monthly charges for Service under Rate

Schedule IT-R and the aggregate of Customer’s Over-run Gas charges for

all LRS-3 Receipt Points for the month preceding such Billing Month;

“B” = the aggregate of the actual volume of gas received by Company for

Customer for Service under Rate Schedule IT-R and Over-run Gas as

allocated by Company to Customer at all of Customer’s LRS-3 Receipt

Points for the month preceding such Billing Month;

“C” = IT as defined in subparagraph 4.2.1; and

“D” = the IT-R Rate at Bowmanton Receipt Point No. 1216.

During the Secondary LRS-3 Term, the commodity charge adjustment shall be deemed to

be zero.

4.2.5. Determination of LRS-3 Billing Adjustment

The LRS-3 Billing Adjustment will be calculated by subtracting the aggregate amounts

calculated in subparagraphs 4.2.3 and 4.2.4 from the aggregate amount calculated in

subparagraph 4.2.2. The LRS-3 Billing Adjustment will be refunded in the second month

following such Billing Month.

If during the Initial LRS-3 Term, the LRS-3 Billing Adjustment calculated pursuant to this

paragraph is determined to be a positive number, the LRS-3 Billing Adjustment will be

deemed to be zero.


4.3.1. The aggregate of Customer’s charges for Over-Run Gas in a Billing Month for Service

under all Rate Schedules shall be equal to the sum of the monthly charges for Over-Run

Attachment C6



Gas for each Receipt Point at which Customer is entitled to Service under any Rate

Schedule, determined as follows:

MOC = V x Z

Where:

“MOC” = the monthly charge for Over-Run Gas at such Receipt Point;

“V” = total volume of gas allocated to Customer by Company as Over-

run Gas in accordance with paragraph 4.6 for Service under all

Rate Schedules at such Receipt Point for such Billing Month; and

“Z” = the IT-R Rate at such Receipt Point.







4.5 Aggregate Charge For Service


(i) the sum of the amounts calculated in accordance with paragraphs 4.1 and

4.3 less the sum of:

Attachment C6






(b) the LRS-3 Billing Adjustment, if any, calculated in accordance

with paragraph 4.2 of this Rate Schedule LRS-3; plus


4.6 Allocation of Gas Received

Notwithstanding any other provision of this LRS-3 Rate Schedule, any Service

Agreement or General Terms and Conditions of the Tariff, and without regard to how gas

may have been nominated, the aggregate volume of gas received from Customer at a

Receipt Point shall be allocated for billing purposes as follows:

(i) first to service to Customer under Rate Schedules LRS and LRS-3 to a maximum

of such Customer's LRS Contract Demand for such Receipt Point under such Rate

Schedule LRS and to a maximum of such Customer’s LRS-3 Contract Demand

for such Receipt Point under such Rate Schedule LRS-3;



Schedule FT-R;



FT-RN; and



Attachment C6



Point, gas shall be allocated as Over-Run Gas and charged in accordance with

paragraph 4.3.

5.0 AVAILABILITY OF NEW LRS-3 RECEIPT POINTS

New LRS-3 Receipt Points or new Facilities at existing Receipt Points required for

Service under Rate Schedule LRS-3 shall be made available to Customer receiving

Service under this Rate Schedule LRS-3 providing the following conditions are met:

(i) the LRS-3 Receipt Point location is on the Company's Facilities between

the Bowmanton Receipt Point No. 1216 and the Empress Delivery Point;

(ii) Customer has provided a capital contribution equal in amount to the

capital costs associated with the installation or construction of any new

LRS-3 Receipt Point or any new Facilities required at an existing Receipt

Point;

(iii) gas received from Customer is for ultimate delivery to the Empress

Delivery Point; and

(iv) Customer requests a transfer of Service pursuant to Article 9.0 for LRS-3

Contract Demand applicable to the Customer’s request for new LRS-3

Receipt Points or new Facilities at an existing Receipt Point.

Attachment C6




6.1 Initial Term

The initial term of the Service Agreement and Schedules of Service for Service under

Rate Schedule LRS-3 shall be four (4) years commencing on the Billing Commencement

Date and shall terminate on the Service Termination Date (the “Initial LRS-3 Term”).

6.2 Renewal of Service

Customer shall be entitled to renew all or a portion of Service under Rate Schedule LRS-

3 at the end of the Initial LRS-3 Term or any time after the Initial LRS-3 Term (such

renewal period here is the “Secondary LRS-3 Term”) provided that:

(i) Customer has given Company twelve (12) months prior Notice; and

(ii) the renewal volume specified by Customer for each Schedule of Service for

Service under Rate Schedule LRS-3 shall be less than or equal to LRS-3 Contract

Demand for such Schedule of Service.

Any renewal of Service is subject to the Financial Assurances provisions in Article 10.0

of the General Terms and Conditions.

6.3 Irrevocable Renewal Notice

Customer’s Notice to renew pursuant to paragraph 6.2 shall be irrevocable twelve (12)

months prior to the Service Termination Date.

6.4 Renewal Term

Customer’s renewal Notice shall specify a renewal term that:

Attachment C6



(i) shall be a minimum of one (1) year consisting of increments of whole months;

and

(ii) shall have a Termination Date no later that twenty (20) years from the Billing

Commencement Date of the Initial LRS-3 Term.

6.5 Termination

Customer shall be entitled to terminate the Service Agreement in whole and not in part at

the end of the Initial LRS-3 Term or any time after the Initial LRS-3 Term provided that

Customer gives Company twelve (12) months prior Notice. If Customer does not

provide such termination Notice to Company, Customer’s Service Agreement shall

terminate on the latest Service Termination Date of Customer’s Schedule of Service for

Service under Rate Schedule LRS-3.

7.0 CAPACITY RELEASE

7.1 A Customer entitled to receive Service under Rate Schedule LRS-3 shall not be entitled

to reduce Customer’s LRS-3 Contract Demand for all or any portion of its Service under

a Schedule of Service under Rate Schedule LRS-3.

8.0 RELIEF FOR MAINLINE RESTRICTIONS

8.1 Company may grant relief to a Customer entitled to Service under Rate Schedule LRS-3,

in accordance with the Terms and Conditions Respecting Relief for Mainline Capacity

Restrictions in Appendix "B" of the Tariff.

Attachment C6



9.0 TRANSFER OF SERVICE BETWEEN RECEIPT POINTS

9.1 If Customer desires to transfer all or any portion of any Service under Rate Schedule

LRS-3 from one LRS-3 Receipt Point to another LRS-3 Receipt Point, Customer shall

give Notice to Company of its request for such transfer specifying the particular LRS-3

Receipt Points and the Service that Customer wishes to transfer.

9.2 Company is under no obligation to permit the transfer requested in paragraph 9.1, but

may permit such transfer provided that:

(i) the transferred-to LRS-3 Receipt Point location is on the Company's

Facilities between the Bowmanton Receipt Point No. 1216 and the

Empress Delivery Point; and

(ii) if Company is required to install or construct Facilities at the transferred-

to LRS-3 Receipt Point to provide the Service requested, the installation

or construction of such Facilities is in accordance with Article 5.0.

10.0 TITLE TRANSFERS

10.1 A Customer entitled to receive Service under Rate Schedule LRS-3 shall not be entitled

to transfer or accept a transfer of Customers’ inventory to or from any other Customer

Account in respect of such Service under Rate Schedule LRS-3.

11.0 ASSIGNMENTS

11.1 Service is assignable only during the Secondary LRS-3 Term and any assignment shall be

subject to Company’s prior written consent, which consent will not be unreasonably

Attachment C6



withheld. The withholding of consent by Company to a proposed assignment shall be

deemed to be reasonable if Company determines in its sole discretion that assignee and

assignor have not agreed to be bound by the obligations and provisions of Section 8 of

the Memorandum of Understanding dated February 8, 2002 between Petro-Canada and

Company (the “MOU”). Petro-Canada shall not be liable to Company if assignee fails to

comply with the obligations and provisions of Section 8 of the MOU.

12.0 APPLICATION FOR SERVICE

12.1 Applications for Service under Rate Schedule LRS-3 shall be in such form as Company

may prescribe from time to time.

13.0 GAS USED

13.1 In respect of volumes that are transported in the Secondary Term utilizing Service under

Rate Schedule LRS-3, LRS-3 Customer shall not be charged for nor shall any deduction

be made for Gas Used.



Agreement for Service under Rate Schedule LRS-3 are applicable to Rate Schedule LRS-

3 to the extent that such terms and conditions and provisions are not inconsistent with

this Rate Schedule.

Attachment C6



APPENDIX 1 TO RATE SCHEDULE LRS-3

LRS-3 RECEIPT POINT STATION NUMBER

Bowmanton 1216 Medicine Hat North #1 1017 Medicine Hat North Arco 1184 Medicine Hat South #2 1043 Medicine Hat South #4 1128 Medicine Hat Northwest 1205 Hilda West 1402

Attachment C6

NOVA Gas Transmission Ltd. LRS-3

Service Agreement


SERVICE AGREEMENT

RATE SCHEDULE LRS-3

BETWEEN:

NOVA Gas Transmission Ltd., a body corporate having an office in

Calgary, Alberta (“Company”)

- and -






them in the General Terms and Conditions of the Tariff, unless otherwise defined.


LRS-3 in accordance with the attached Schedules of Service. The Service will

commence on the Billing Commencement Date and will terminate, subject to the

provisions of this Service Agreement, on the Service Termination Date.



Attachment C6


Service Agreement


in Rate Schedule LRS-3.

5. Customer shall:


respecting any Service to be provided pursuant to Rate Schedule LRS-3

including, without limiting the generality of the foregoing, an assurance that

necessary arrangements have been made among Customer, producers of gas for

Customer, purchasers of gas from Customer and any other Person relating to such

Service, including all gas purchase, gas sale, operating, processing and common

stream arrangements; and


provided the Person operating facilities upstream of any Receipt Point in respect

of which Customer has the right to receive Service with all authorizations

necessary to enable such Person to provide Company with all data and

information reasonably requested by Company for the purpose of allocating

volumes of gas received by Company among Company's Customers and to bind

Customer in respect of all such data and information provided.

If Customer fails to provide such assurances and information forthwith following

request by Company, from time to time, Company may at its option, to be exercised by

Notice to Customer, suspend the Service to which such assurances and information

relate until such time as Customer provides the assurances and information requested,

provided however that any such suspension of Service shall not relieve Customer from

any obligation to pay any rate, toll, charge or other amount payable to Company.


assumptions and forecasts described in Company’s Annual Plan, and that interruption

and curtailment of Service may occur if the aggregate gas volume actually received or the

Attachment C6


Service Agreement


aggregate gas volume actually delivered at the Facilities is different than forecast.

7. Every notice, request, demand, statement, bid or bill provided for in Rate Schedule LRS-

3, this Service Agreement and the General Terms and Conditions, or any other notice

which either Company or Customer may desire to give to the other (collectively referred

to as “Notice”) shall be in writing and each of them and every payment provided for shall

be directed to the Person to whom given, made or delivered at such Person's address as

follows:

Customer:

•

•

•

Attention: •

Fax: •

Company:

•

•

•


Fax: •







Attachment C6


Service Agreement











posting.





8. The terms and conditions of Rate Schedule LRS-3, the General Terms and Conditions

and Schedule of Service under Rate Schedule LRS-3 are by this reference incorporated

into and made a part of this Service Agreement.

Attachment C6


Service Agreement



signing officers duly authorized in that behalf all as of the • day of , • •.


Per: Per :

Per: Per :

Attachment C6


Schedule of Service


SCHEDULE OF SERVICE RATE SCHEDULE LRS-3

CUSTOMER: •

Schedule of

Service Number

Receipt Point

Number and Name

Legal

Description

Maximum Receipt Pressure

kPa

Service

Termination Date

LRS-3 Contract Demand 103m3/d


• • • • • • • •


Attachment C6

Attachment C1 cover - docs2.cer-rec.gc.ca

Documents

Transcript of Attachment C1 cover - docs2.cer-rec.gc.ca