ENERGY

Petroleum Plaza – North Tower 9945 – 108 Street Edmonton, Alberta Canada T5K 2G6 02-03

GAS ROYALTY CALCULATION INFORMATION BULLETIN

March 2002

A. PRICING RATES AND TRANSPORTATION INFORMATION Pricing, Royalty Rates and Transportation Information – January 2002............................................. 2 B. NOTICES

Monthly Sulphur Corporate Average Price Calculation – VA4 Form .................................................. 2 Capital Cost Allowance Reporting (AC2-V2) for New Facility Cost Centres (FCC)............................ 3 Receive the Gas Royalty Calculation Information Bulletin Electronically ........................................... 3

C. MONTHLY INFORMATION January 2002 Royalty Due April 30..................................................................................................... 3 February 2002 OAS and VA4 Due April 15 ........................................................................................ 4 Interest Rate March 2002.................................................................................................................... 4 December Provisional Assessment Charge........................................................................................ 4 December Penalty Charges ................................................................................................................ 4 Alberta Royalty Tax Credit Program Quarterly Rate ...........................................................................5 D. INFRASTRUCTURE DATA CHANGES Client ID Listing ................................................................................................................................... 5 Projects/Blocks.................................................................................................................................... 5 Struck Clients ...................................................................................................................................... 6 Operator Changes............................................................................................................................... 6 New EUB Plants .................................................................................................................................. 6 Nova Tolls – Multiple Gas Reference Prices....................................................................................... 6 E. REMINDERS

Auto Debit Processing Date for December 2001 Production.............................................................. 7 The Petroleum Registry of Alberta (formerly VIPIR) ........................................................................... 7 Submission of Production Year 2001 Allowable Cost (AC) and Corporate Average Price Calculation

(VA) Forms .......................................................................................................................................... 7 Weighted Average Aggregator Overhead Marketing and Administration Charges (OMAC) .............. 8 Annual Weighted Average Gas Reference Price................................................................................ 8 2002 Select Prices .............................................................................................................................. 8 Historical Pricing and Royalty Data..................................................................................................... 8 December 2001 Production Royalty Due Date is March 28, 2002 ..................................................... 9

Monthly Sulphur Default Price for November 2001............................................................................. 9 F. PRINCIPLES AND PROCEDURES Updates ............................................................................................................................................... 9 G. POINTS OF CONTACT Department of Energy Hotline & Internet ............................................................................................ 9 Gas Royalty Calculation .................................................................................................................... 10 Calgary Information Centre .............................................................................................................. 10 Alberta Royalty Tax Credit Information ............................................................................................ 10

Internet Address: www.energy.gov.ab.ca

INFORMATION BULLETIN – March 2002

A. PRICING RATES AND TRANSPORTATION INFORMATION

For Pricing, Royalty Rates and Transportation Information for January 2002, refer to Attachments 1, 2, 2A, and 3.

B. NOTICES

Monthly Sulphur Corporate Average Price Calculation – VA4 Form

Royalty clients with an annual sulphur production of 30,000 tonnes or greater in the production year 2001 are required to file VA4 forms monthly, beginning with the January 2002 production month. The VA4 form is due on or before the 15th day of the second month following the respective production month. A royalty client whose annual sulphur production is less than 30,000 tonnes may choose to file the VA4 forms monthly beginning with January’s production month; however, if this choice is made, the client must file VA4 forms for the entire year. The Department will use the VA4 forms to determine each client’s monthly Sulphur Corporate Average Price (S-CAP) and the monthly Sulphur Default Price. We calculate each month’s Sulphur Default Price as the weighted average unit value of all arms length sales for all clients who filed VA4 forms for that month. The Department will value and invoice the Crown royalty share of sulphur production monthly, using the respective S-CAP price for clients who file VA4 forms and the Sulphur Default Price for clients who choose not to file VA4 forms. The VA4 form is subject to $100 in late filing penalties for each month or part of the month the form is past due. Royalty clients who file monthly VA4 forms must file annual VA3 forms. The VA3 form remains the primary sulphur valuation tool and the S-CAP determined from each VA3 will replace the entire year’s monthly prices determined from the VA4 forms. The VA3 is due on or before April 15th of the year following the year of production. Interest is charged/paid on the Crown royalty difference when adjusting from monthly to annual valuation. The VA3 form is subject to a one-time $1,000 late filing penalty. The following royalty clients must submit VA4 forms effective with the production year 2002, which includes any pricing information for each of its consolidated/amalgamated entities:

Client ID Client Name Client ID Client Name 0017 Imperial Oil Resources 0JT1 ExxonMobil Canada Energy 0039 Talisman Energy Inc. 0JT3 Nexen Canada Ltd. 0045 Chevron Canada Limited 0KT5 Canadian 88 Energy Corp. 0054 Suncor Energy Inc. 0N00 Prime West Energy Inc. 0060 BP Canada Energy Company 0N80 Canadian Hunter Exp. Ltd.

0102419 Devon Canada 0NP6 PCC Energy Inc. 0246 Petro-Canada 0PF8 Hunt Oil Company of Canada 0BL1 Burlington Resources Canada Ltd. 0R46 Husky Oil Operations Limited 0BM8 Rio Alto Exploration Ltd. 0T03 Shell Canada Limited 0CW8 Compton Petroleum Corp. 0T82 Canadian Forest Oil Ltd. 0E21 AEC West Ltd. 0TC5 Vintage Petroleum Canada Inc. 0FW6 Conoco Canada Resources Ltd. 0WC8 Devon AXL 0G30 Arc Resources Ltd. 0XE2 PanCanadian Pet/PC O&G

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INFORMATION BULLETIN – March 2002

Capital Cost Allowance Reporting (AC2-V2) for New Facility Cost Centres (FCC)

To ensure that the Department correctly calculates capital cost allowance for a new FCC, the operator must follow the following procedures:

Eligible capital costs incurred up to the start-up date should be entered in both fields 2.1 and 2.2. Initial capital cost identified in 2.1 and 2.2 must also be clearly identified in Part 3 and must not be included in field 2.3. Eligible capital costs incurred subsequent to start-up should be included in field 2.3 only. For capital additions identified in Part 3, identify each Authorization for Expenditure (AFE) or provide a breakdown of capital as the description. The total capital addition on line 3.4 should not be reflected on field 2.3 for a new facility cost center. If the capital for a new FCC includes amounts transferred from a terminated FCC (the previous FCC), then:

• field 2.1 should include the Cumulative Allowable Capital Dec 31 (field 2.4), • field 2.2 should include the Allowable Capital Cost After Depreciation (field 2.7)

from the previous FCC before termination. Where the capital added to a new FCC is transferred from an existing FCC that is not terminated then the transferred capital should be included in field 2.3. The capital transferred must also be removed from the existing FCC at the same time.

Receive the Gas Royalty Calculation Information Bulletin Electronically

The Gas Royalty Calculation Information Bulletin is now available by electronic delivery. To subscribe, please go to www.energy.gov.ab.ca. Note: There is no charge for subscribing or limit to the number of recipients. Clients who elect to receive the Information Bulletin electronically will not receive a mailed paper copy.

C. MONTHLY INFORMATION January 2002 Royalty Due April 30

• Royalty clients are to remit the total amount payable shown on the April 2002 Statement of Account by April 30, 2002. If the amount payable includes accrued current period interest, the interest has only been accrued to the statement issue date. Clients must also include the additional interest that has accrued from the statement issue date to the date of payment, using the per diem amount provided.

• The April 2002 Statement of Account shows your amount payable as of the Statement issue date. It includes any outstanding balances from your previous statement, your January 2002 Invoice amount and any applicable current period interest charges. It also identifies refunds resulting from overpayments.

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INFORMATION BULLETIN – March 2002

• Current period interest will not be charged on current invoice charges for the production month of January 2002 if it is paid in full by April 30, 2002.

• Current period interest will accrue on any overdue charges commencing the first day after the due-date until it is paid in full.

Note: If the due date falls on a non-business day, payments will be accepted on the next business day.

• Cheques are payable to the Minister of Finance, Province of Alberta.

February 2002 OAS and VA4 Due April 15 The OAS and VA4 documents for the production month of February 2002 are due in the Department offices by April 15, 2002.

NOTE:

• If the due date (15th) falls on a non-business day, the next business day will apply as the due date for OAS and VA4 documents.

• The OAS due date specified by the Department is the date by which the required OAS data must be received in the Department.

• Keying services require sufficient time to process and transmit the data by the Department’s due date. Contact your keying agent for the respective cut-off dates.

• For EDI clients, the receipt date is when Value-Added Network (i.e. GE) receives the transmission.

• The importance of timely receipt of OAS data by your service provider and the Department is critical to ensure accurate royalty calculation and prevention of provisional assessment.

Interest Rate March 2002 The Department of Energy’s interest rate for March 2002 is 4.75%.

December Provisional Assessment Charge

The net Provisional Assessment Charge for the December 2001 billing period was $19,675,325.44. This includes $60,368,524.84 in first time provisional assessments and ($40,693,199.40) in reversals of provisional assessments for all production periods.

December Penalty Charges The following are the Penalty Charges by form type for the December 2001 billing period:

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INFORMATION BULLETIN – March 2002

FORM Penalties Charged AC2 $24,200 AC4 $0 AC5 $17,900 GR2 $0 NGL1 $1000 VA2 $0 VA3 $0 VA4 $0 Total Charged $43,100 Total Reversed ($30,800)

Net Penalties Charged for 2001/12 $12,300

Alberta Royalty Tax Credit Program Quarterly Rate

For the first quarter of 2002, the Alberta Royalty Tax Credit rate will be .2500. This rate is based on a royalty tax credit reference price of $228.58 per cubic metre. The Alberta Royalty Tax Credit rates for the past year were:

Fourth Quarter, 2001 .2500 Third Quarter, 2001 .2500 Second Quarter, 2001 .2500 First Quarter, 2001 .2500

If you have any questions, please contact Kent Nelson of Tax Services at (780) 427-9425, ext 250.

D. INFRASTRUCTURE DATA CHANGES

Client ID Listing The Client ID listing can be found on the Internet at the following address:

www.energy.gov.ab.ca

The listing, which is updated monthly, includes Clients, which are active, struck, and terminated since January 1997. If you require information before January 1997 regarding the status of a Client ID, please call the Gas Royalty Calculation Helpdesk at (780) 427-2962. The Department would like to remind those browsing the site to note the effective and termination dates of the Client IDs. Projects/Blocks

Projects/Blocks information will be updated in the April 2002 Information Bulletin. If further information is required on any other projects, please contact Isabelle Warwa at (780) 422-8966.

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INFORMATION BULLETIN – March 2002

Struck Clients Clients must ensure that the OAS and all other royalty documents are completed using only valid client names and IDs. It is critical that royalty clients use current legal client names and their appropriate IDs on all documents to ensure accurate royalty calculation and to prevent provisional assessment and penalties. Rejects will occur when invalid IDs are used.

If you require information regarding client names or IDs, please contact Client Registry at (780) 422-1395. The following is a list of voluntarily dissolved, struck, cancelled and revived clients:

Company Name Client ID Voluntarily Dissolved Date CAUSEWAY ENERGY CORPORATION 0NX2 February 11, 2002

Company Name Client ID Struck Date WW BECKER OIL AND GAS LTD 0R48 February 2, 2002 RIO NEVADA ENERGY INC 0TZ7 February 2, 2002 PENYGROES HOLDINGS LTD 0033113 February 2, 2002 OZADA RESOURCES LTD 0MX1 February 2, 2002 PARK RIDGE PETROLEUMS LTD 0033456 February 2, 2002 LATERAL RESOURCES LIMITED 0033020 February 2, 2002 BLUESTONE RESOURCES INC 0WC3 February 2, 2002

Company Name Client ID Cancelled Date HUSKY BORDER PIPELINES LTD 0034012 February 2, 2002

Company Name Client ID Revived Date 549767 ALBERTA LTD 0104344 February 5, 2002 CAROLINE PETROLEUMS (1985) LTD 002949 March 12, 2002

Operator Changes EUB Facility Operator changes are listed in Attachment 4.

New EUB Plants New EUB plants and corresponding plant types and transportation regions are listed in Attachment 5. Nova Tolls - Multiple Gas Reference Prices

Royalty information related to the implementation of the Factor Model negotiated with industry for determining Multiple Gas Valuation Prices is provided in Attachment 6 and on the Department Internet site at:

www.energy.gov.ab.ca

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INFORMATION BULLETIN – March 2002 E. REMINDERS

Auto Debit Processing Date for December 2001 Production

As per Section 15 (2) of Natural Gas Royalty Regulations 1994 (A.R. 351/93), the payment of royalty invoices issued in February (December production month) are due on or before the last day the offices of the Department of Energy are open in March. In view of this, the last day for submission of your auto debit request is March 22, 2002 and this amount will be processed on March 28, 2002. The Petroleum Registry of Alberta (formerly VIPIR) The Registry is a shared, interactive database, accessed through the Internet. The Registry incorporates re-engineered business processes targeted to improve the quality and management of key volume, royalty and infrastructure information associated with Alberta's upstream petroleum industry. The implementation of the registry database is scheduled for October 2002. We encourage all our Industry clients to go to the Petroleum Registry web site to prepare for these future changes, find out what the changes are, how these will affect you, and what training is available to prepare you for these changes. Petroleum Registry Website: http://www.petroleumregistry.gov.ab.ca/

Petroleum Registry of Alberta Contact List:

Email Address: petroleumregistry.energy@gov.ab.ca

Phone: Calgary: 1-403-297-6111 Other Locations: 1-800-992-1144

Mailing Address: Petroleum Registry of Alberta Offices 8th Floor, 108 Street Building 9942 - 108 Street Edmonton AB T5K 2J5 FAX: 780/422-0229 (Edmonton)

3rd Floor, Monenco Building 801 Sixth Avenue S.W. Calgary, Alberta, T2P 3W2 FAX: 403/297-3665 (Calgary)

Submission of Production Year 2001 Allowable Cost (AC) and Corporate Average Price Calculation (VA) Forms Royalty clients are advised that Allowable Cost forms (AC2, AC3, AC4, and AC5) and Corporate Average Price Calculation forms (VA2 and VA3) for the 2001 production year can be submitted to the Department for processing. The form due dates are as follows:

Form Due Date AC4 March 31, 2002 AC2 April 15, 2002 VA2 April 15, 2002 VA3 April 15, 2002 AC5 May 15, 2002 AC3 May 15, 2002

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INFORMATION BULLETIN – March 2002

Appendix C of the Natural Gas Royalty Guidelines, September 1, 2001, outlines the form edits for paper submission documents. Electronic form filers should check the Department’s Internet site for electronic form edits.

Gas royalty payers and their service providers can use the Department’s Internet site to retrieve PDF and text versions of the gas royalty reports such as the Gas Royalty Invoice, Statement of Account, Turnaround Reports, and form reject reports. Clients with reports in UDF and DDF formats can also retrieve their files on the Internet. The following Internet web site identifies all of the Department of Energy’s E-transfer systems.

www.energy.gov.ab.ca

If you are amending a facility cost centre operator or setting up a new 2001 facility cost centre, please submit your AC1 document in a timely manner to ensure that you can file your AC4 or AC2 documents without penalty.

Weighted Average Aggregator Overhead Marketing and Administration Charges (OMAC)

For Gas Corporate Average Price (CAP) filers, when determining the netback value, the weighted average OMAC type charges may be deducted for sales to non-designated aggregators. The Weighted Average Aggregator OMAC ($/GJ) for 2001 is $0.021. For further information, see Chapter III, Section 1.1.3 and 1.4.1 of the Principles and Procedures.

Annual Weighted Average Gas Reference Price

The Annual Weighted Average Gas Reference Price for 2001 is $5.111. This price is used in the calculation to determine the 2001 minimum price for the Gas Corporate Average Price.

2002 Select Prices

The following are the select prices for pentanes and old and new vintages of natural gas and ethane for the year 2002.

2002 Select Prices

Natural Gas ($/GJ) Old Gas 0.372 New Gas 1.252

Ethane ($/GJ) Old Ethane 0.372 New Ethane 1.252

Pentanes($/m3) 45.30

Historical Pricing and Royalty Data A listing of historical royalty related data for information purposes was published in the February 2002 Information Bulletin and can be found on the Internet at the following address:

www.energy.gov.ab.ca

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INFORMATION BULLETIN – March 2002

December 2001 Production Royalty Due Date is March 28, 2002

The royalty due date for December 2001 production issued in February 2002 is March 28, 2002. Effective September 1, 2001, Section 15(2) of the Natural Gas Royalty Regulations provides for payment of the royalty invoice issued in February (December production month) on or before the last day in which the offices of the Department are open in March.

Monthly Sulphur Default Price for November 2001

Based on November 2001 production month VA4 filings, the Total Net Monthly Sales Value divided by the Total Sulphur Volume resulted in a negative value. The Net Monthly Sales Value includes transportation and storage costs incurred to deliver the sulphur to the point of sale. The Sulphur Default Price for November 2001 is $0.00.

F. PRINCIPLES AND PROCEDURES

Updates The Department updates the Alberta Natural Gas Royalty Principles and Procedures manual when there is a major change in relevant policy or legislation, and regularly to incorporate information published in Information Letters and Information Bulletins. Please include any inserts provided in this section of the monthly Information Bulletin in your copy of the Principles and Procedures. There is no new information to incorporate for March 2002.

G. POINTS OF CONTACT

Department of Energy Hotline & Internet

Prices, Royalty Rates, and Transportation Information are available on the Department of Energy Internet address or hotline: (403) 297-5430. In addition, both the Gas Royalty Calculation Information Bulletin and Information Letter are also available on the Internet address:

www.energy.gov.ab.ca

Note: The sulphur price can be accessed by calling the Department of Energy hotline at (403) 297-5430. Wait to hear the recorded list of options, then press #1 on your touch-tone phone for Natural Gas Information. Again, wait for the recorded list of options, then press #3 for Gas Royalty Rates.

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INFORMATION BULLETIN – March 2002

Gas Royalty Calculation

Gas Royalty Calculation can be reached at:

Telephone: (780) 427-2962 Fax: (780) 427-3334 or (780) 422-8732

Alberta Toll Free: 310-0000 (Please do not dial “1” or “780”.) Hours of operation are 8:15 a.m. to 4:30 p.m. Voice messages left after 4:30 p.m. will be answered the next business day.

Calgary Information Centre 3rd Floor, 801 – 6th Avenue S.W. Calgary, Alberta T2P 3W2 Telephone (403) 297-6324 Fax (403) 297-8954

Alberta Royalty Tax Credit Information

Alberta Tax and Revenue Administration Tax Services Telephone: (780) 427-3044 Alberta Toll Free: 310-0000 Fax: (780) 427-5074

For further information, please contact Angelina Leung at (780) 427-9425 ext 251. David Breakwell Director, Gas Royalty Calculation Gas and Markets Development

Attachments

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INFORMATION BULLETIN – March 2002 ATTACHMENT 1

2002 PRICES

MONTH

GAS REF

PRICE ($ per GJ)

GAS PAR

PRICE ($ per GJ)

ETHANE

REFERENCE PRICE

($ per GJ)

ETHANE

PAR PRICE

($ per GJ)

PENTANES

REF PRICE

($ per m3)

PENTANES

PAR PRICE

($ per m3)

PROPANE

REF PRICE

($ per m3)

PROPANE

FLOOR PRICE

($ per m3)

BUTANE

REF PRICE

($ per m3)

BUTANE FLOOR PRICE

($ per m3)

SULPHUR DEFAULT

PRICE ($ PER

TONNE)

JAN 3.17 3.20 3.17 3.20 192.56 179.80 88.15 62.44 125.51 100.92 4.25

FEB

MAR

APR

MAY

JUN

JUL

AUG

SEPT

OCT

NOV

DEC

DETAIL OF THE JANUARY 2002 GAS REFERENCE PRICE SELECT PRICE 2002 Weighted Average Price of Alberta 3.528 $/GJ New Gas

($per GJ) Old Gas ($per GJ)

Pentanes ($per m3)

Deductions: Intra – Alberta Transportation 0.280 $/GJ 1.252 0.372 45.30

Marketing Allowance 0.033 $/GJ New Ethane($per GJ)

Old Ethane ($per GJ)

Price Before Pipeline Factor 3.215 $/GJ 1.252 0.372

Pipeline Fuel/Loss Factor 0.988 Price before Special Adjustment 3.176 $/GJ

Special Adjustment 0.000 $/GJ Price before 2% amendment limitation or rounding 3.176 $/GJ Weighted Average Reference Weighted Average OMAC Amendments:Carry forward (from previous RP month) -0.004 $/GJ Price ($/GJ) ($/GJ) Prior Period Amendment Adjustment (current RP month) -0.006 $/GJ

5.111 0.021 Calculated RP after Amendments 3.166 $/GJ JANUARY 2002 Reference Price 3.17 $/GJ Difference = value carried forward to next RP month -0.004 $/GJ

Adjusted IATD (before Prior Period Amendments) 0.277 $/GJ ANNUAL SULPHUR DEFAULT PRICE Prior period Amendments (IATD and Pipeline Fuel Loss) 0.000 $/GJ 1996 1997 1998 1999 2000 Adjusted IATD (after Prior Period Amendments) 0.277 $/GJ $11.45 $9.98 $6.01 $10.54 $10.99

INFORMATION BULLETIN – March 2002

ATTACHMENT 2 2002

TRANSPORTATION ALLOWANCE AND DEDUCTIONS

PENTANES PLUS (a)

PROPANE AND BUTANE (b)

PENTANES PLUS, PROPANE & BUTANE (c)

REGION REGION REGION

MONTH

1 2 3 4 1 2 3 4 1 2 3 4

FRAC.

ALLOW.

(per m3)

JAN 2.74 10.49 15.00 17.89 7.94 1.71 5.94* 6.39 9.99 15.92 15.26 7.81 8.75

FEB

MAR

APR

MAY

JUN

JUL

AUG

SEPT

OCT

NOV

DEC

(a) Pentanes Plus obtained as a specification gas product, (b) Propane and Butane obtained as specification products, and (c) Pentanes Plus, Propane and Butane contained in a natural gas liquids mix. * Current month calculated allowance is based on an estimate.

Note: For details on “Prior Period Amendment Effects”, see Attachment 2A.

INFORMATION BULLETIN – March 2002 ATTACHMENT 2A

PRIOR PERIOD AMENDMENT EFFECTS

NGL REFERENCE PRICES JANUARY 2002

Propane Butane Pentanes

Price before amendments 88.151905 125.516692 192.567750

Opening Rollover (from prior business month) -0.001266 -0.004622 -0.004957

Prior Period Amendment Adj. (NGL-1) 0.000000 0.000000 0.000000

Prior Period Amendment Adj. (NGL-100) 0.000000 0.000000 0.000000

Published Reference Price 88.15 125.51 192.56

TRANSPORTATION ALLOWANCES JANUARY 2002

Pentanes Plus Propane and Butane Pentanes Plus, Propane & Butane

AMENDMENTS Region 1 Region 2 Region 3 Region 4 Region 1 Region 2 Region 3 Region 4 Region 1 Region 2 Region 3 Region 4

Opening Rollover (from prior business mth) 0.001250 0.004915 0.000606 -0.001526 0.003961 -0.004152 0.001904 0.003127 0.003324 -0.001247 0.003554 0.003547

Prior Period Amendment Adj. (NGL1) 0.000000 0.000000 0.000000 0.000000 0.000000 0.000000 0.000000 0.000000 0.000000 0.000000 0.000000 0.000000

Prior Period Amendment Adj. (NGL-100) 0.000000 0.000000 -0.748003 0.000000 0.000000 0.000000 0.000000 0.000000 0.000000 0.000000 0.000000 0.000000

Total Amendment Effect 0.001250 0.004915 -0.747397 -0.001526 0.003961 -0.004152 0.001904 0.003127 0.003324 -0.001247 0.003554 0.003547

Calculated Transp. Differential 2.741250 10.482149 15.751145 17.892993 7.940650 1.716141 5.936484* 6.387315 9.986265 15.925105 15.253581 7.806857

Calculated Transp. Differential after Total

Amendments

2.742500 10.487064 15.003748 17.891467 7.944611 1.711989 5.938388* 6.390442 9.989589 15.923858 15.257135 7.810404

Published Transportation Allowance 2.74 10.49 15.00 17.89 7.94 1.71 5.94* 6.39 9.99 15.92 15.26 7.81 * Any estimates represented by (*) are calculated as the weighted average of the other regions for the same spec product transportation allowance, since the region is zero. The weightings are based on the previous

year’s production.

INFORMATION BULLETIN – March 2002

ATTACHMENT 3

2002

ROYALTY RATES

MONTH

GAS - OLD (GOL)

(per GJ)

GAS – NEW (GNE)

(per GJ)

ETHANE – OLD

(per GJ)

ETHANE – NEW

(per GJ)

PENTANES - OLD

(POL) (per m3)

PENTANES - NEW

(PNE) (per m3)

JAN 35.00000 30.00000 35.00000 30.00000 42.94549 31.72469

FEB

MAR

APR

MAY

JUN

JUL

AUG

SEPT

OCT

NOV

DEC

I NFORMATION BULLETIN - March 2002 FACILITY OPERATOR CHANGE FORM OC1 ATTACHMENT 4

EUB FACILITY FACILITY NAME PREVIOUS OPERATOR NAME PREVIOUS

CLIENT ID CURRENT OPERATOR NAME CURRENT CLIENT ID

EFFECTIVE DATE

AB-GP-1109 ACCLAIM DRUMHELLER VINTAGE RESOURCE CORP 0PK2 ACCLAIM ENERGY INC 0KX8 2002-01AB-GP-1214 PRIMEWEST PEMBINA PRIMEWEST OIL AND GAS CORP 0C00 PRIMEWEST ENERGY INC 0N00 2002-01AB-GP-1499 PRIMEWEST FARROW PRIMEWEST OIL AND GAS CORP 0C00 PRIMEWEST ENERGY INC 0N00 2002-01AB-GP-1532 BONAVISTA BERRY HADRIAN ENERGY CORP 0PX9 BONAVISTA PETROLEUM LTD 0MD6 2002-02AB-GP-1545 PRIMEWEST VEGA PRIMEWEST OIL AND GAS CORP 0C00 PRIMEWEST ENERGY INC 0N00 2002-01AB-GP-1580 PRIMEWEST THORSBY 4-27 PRIMEWEST OIL AND GAS CORP 0C00 PRIMEWEST ENERGY INC 0N00 2002-01AB-GP-1642 PRIMEWEST THORSBY 7-14 PRIMEWEST OIL AND GAS CORP 0C00 PRIMEWEST ENERGY INC 0N00 2002-01AB-GP-1653 PRIMEWEST THORSBY 6-11 PRIMEWEST OIL AND GAS CORP 0C00 PRIMEWEST ENERGY INC 0N00 2002-01AB-GP-1680 PRIMEWEST HOTCHKISS PRIMEWEST OIL AND GAS CORP 0C00 PRIMEWEST ENERGY INC 0N00 2002-01AB-GP-1728 BURLINGTON PERCY LAKE GAS PLANT NORTHWESTERN UTILITIES LIMITED 0021 BURLINGTON RESOURCES CANADA LTD 0BL1 2002-02AB-GP-1983 PRIMEWEST THUNDER LAKE WEST PLANT PRIMEWEST OIL AND GAS CORP 0C00 PRIMEWEST ENERGY INC 0N00 2002-01AB-GS-2221 PRIMEWEST PRINCESS GGS PPRIMEWEST RESOURCES LTD 0YZ3 PRIMEWEST ENERGY INC 0N00 2002-01AB-GS-2452 PRIMEWEST PATRICIA GAS UNIT #1 PRIMEWEST RESOURCES LTD 0YZ3 PRIMEWEST ENERGY INC 0N00 2002-01AB-GS-2736 BURLINGTON VIKING-KINSELLA NORTHWESTERN UTILITIES LIMITED 0021 BURLINGTON RESOURCES CANADA LTD 0BL1 2002-02AB-GS-2954 ACCLAIM PROVOST VINTAGE RESOURCE CORP 0PK2 ACCLAIM ENERGY INC 0KX8 2002-01AB-GS-3289 PRIMEWEST MELLOWDALE GGS PRIMEWEST OIL AND GAS CORP 0C00 PRIMEWEST ENERGY INC 0N00 2002-01AB-GS-3424 ACCLAIM DRUMHELLER VINTAGE RESOURCE CORP 0PK2 ACCLAIM ENERGY INC 0KX8 2002-01AB-GS-3592 PRIMEWEST KIMIWAN PRIMEWEST OIL AND GAS CORP 0C00 PRIMEWEST ENERGY INC 0N00 2002-01AB-GS-3865 BONAVISTA BERRY HADRIAN ENERGY CORP 0PX9 BONAVISTA PETROLEUM LTD 0MD6 2002-02AB-GS-4238 PRIMEWEST FARROW PRIMEWEST OIL AND GAS CORP 0C00 PRIMEWEST ENERGY INC 0N00 2002-01AB-GS-4444 VINTAGE SUNSET CANADIAN 88 ENERGY CORP 0KT5 VINTAGE PETROLEUM CANADA INC 0TC5 2000-04AB-GS-4679 PRIMEWEST LUNNFORD GGS PRIMEWEST OIL AND GAS CORP 0C00 PRIMEWEST ENERGY INC 0N00 2002-01AB-GS-4799 BURLINGTON VIKING LAKE 6-2 GGS NORTHWESTERN UTILITIES LIMITED 0021 BURLINGTON RESOURCES CANADA LTD 0BL1 2002-02AB-GS-4801 BURLINGTON VIKING-KIN 10-11 NORTHWESTERN UTILITIES LIMITED 0021 BURLINGTON RESOURCES CANADA LTD 0BL1 2002-02AB-GS-4802 BURLINGTON PERCY LAKE NORTHWESTERN UTILITIES LIMITED 0021 BURLINGTON RESOURCES CANADA LTD 0BL1 2002-02AB-GS-4803 BURLINGTON IRMA 12-1 GS NORTHWESTERN UTILITIES LIMITED 0021 BURLINGTON RESOURCES CANADA LTD 0BL1 2002-02AB-GS-6074 PRIMEWEST ROXANA 10-27 GGS PRIMEWEST OIL AND GAS CORP 0C00 PRIMEWEST ENERGY INC 0N00 2002-01AB-GS-6085 BURLINGTON VKG-PCP 10-16 NORTHWESTERN UTILITIES LIMITED 0021 BURLINGTON RESOURCES CANADA LTD 0BL1 2002-02AB-GS-6123 ACCLAIM CHIGWELL SOUTH GATHERING LINE VINTAGE RESOURCE CORP 0PK2 ACCLAIM ENERGY INC 0KX8 2002-01AB-GS-6183 PRIMEWEST ROXANA 1-21 PRIMEWEST OIL AND GAS CORP 0C00 PRIMEWEST ENERGY INC 0N00 2002-01AB-GS-6258 PRIMEWEST HARMON VALLEY 13-12 PRIMEWEST OIL AND GAS CORP 0C00 PRIMEWEST ENERGY INC 0N00 2002-01

EFFECTIVE DATE CHANGEAB-GP-1786 BP CANADA CALLUM CREEK 02-24 BP CANADA ENERGY COMPANY 0060 BP CANADA ENERGY COMPANY 0060 2000-12AB-GP-1790 AEC HARO 13-17 ALBERTA ENERGY COMPANY LTD 0R61 ALBERTA ENERGY COMPANY LTD 0R61 2000-09

INFORMATION BULLETIN –March 2002 ATTACHMENT 5

NEW PLANTS

EUB FACILITY CODE

FACILITY NAME

TRANSPORTATION REGION

PLANT TYPE

PLANT TYPE

EFFECTIVE DATE

AB-GP-1797 Shaman Fenn Big Valley Gas Plant 2 2 2002-01

AB-GP-1798 Devon Narraway 10-8 GP 4 2 2002-01

AB-GP-1799 Husky Overchem Mitsue 11-32 3 1 2001-12

AB-GS-6372 Anadarko Valhalla 9-9 GGS 4 1 2002-02

AB-GS-6377 Keyspan Sylvan Lake 13-05 1 1 2002-01

AB-GS-6378 Paramount Fort Kent 7-26 1 1 2002-01

AB-GS-6379 Devlan Cadotte 12-35 3 1 2002-01

AB-GS-6380 Talisman Central Foothills Pinto GGS 2 1 2002-02

AB-GS-6381 Summit Mirage 08-09 4 1 2002-02

AB-GS-6382 Midnight Pembina 11-35 1 1 2002-02

AB-GS-6383 PanCanadian Wintering Hills 10-23 GGS 2 1 2002-02

AB-GS-6384 Nal Sturgeon Lake 12-15 4 1 2002-02

AB-GS-6385 Husky Chin Coulee Legend 16-25 GGS 2 1 2002-02

AB-GS-6386 Devon Ferrier 5-27 GGS 1 1 2002-02

INFORMATION BULLETIN -March 2002 Multiple Gas Valuation Factors ATTACHMENT 6

Facility ID

Facility Operator

IDProduction

PeriodBilling Period

Royalty Trigger Factor

Pipeline Operator

Meter Station ID

Meter Station Factor Deleted Tie

Facility to Meter Tie

Date

Facility to Meter

Termination Date

Meter Factor Effective Date

Meter Factor Termination

DateAB-GP-1243 0060 2001-07-01 2002-01-01 1.08 NOVA 2069 1.08 2001-07-01 2002-01-01 2001-07-01 2001-10-01AB-GP-1243 0060 2001-10-01 2002-01-01 1.13 NOVA 2069 1.13 2001-07-01 2002-01-01 2001-10-01 2002-01-01AB-GP-1771 0T65 2001-07-01 2002-01-01 1.08 NOVA 2732 1.08 2001-07-01 3000-01-01 2001-07-01 2001-10-01AB-GP-1771 0T65 2001-07-01 2002-01-01 1.08 NOVA 2706 1.08 Yes 2001-07-01 3000-01-01 2001-07-01 2001-10-01AB-GP-1771 0WC8 2001-10-01 2002-01-01 1.13 NOVA 2732 1.13 2001-07-01 3000-01-01 2001-10-01 3000-01-01AB-GP-1771 0WC8 2001-10-01 2002-01-01 1.13 NOVA 2706 1.13 Yes 2001-07-01 3000-01-01 2001-10-01 3000-01-01AB-GP-1790 0R61 2001-09-01 2002-01-01 1.08 NOVA 2053 1.08 2001-09-01 3000-01-01 2001-07-01 2001-10-01AB-GP-1790 0R61 2001-10-01 2002-01-01 1.13 NOVA 2053 1.13 2001-09-01 3000-01-01 2001-10-01 3000-01-01AB-GP-1795 0A6X 2001-12-01 2002-01-01 1.13 NUL 502184 1.13 2001-12-01 3000-01-01 2001-12-01 3000-01-01AB-GS-4444 0TC5 2001-07-01 2002-01-01 1.08 NOVA 2270 1.08 2001-07-01 3000-01-01 2001-07-01 3000-01-01AB-GS-6325 0XE2 2001-11-01 2002-01-01 0.76 NOVA 1436 0.76 2001-11-01 3000-01-01 2001-10-01 3000-01-01AB-GS-6338 0WC8 2001-10-01 2002-01-01 1.13 NUL 501962 1.13 2001-10-01 3000-01-01 2001-10-01 3000-01-01AB-GS-6371 0HE9 2001-11-01 2002-01-01 1.13 NOVA 2084 1.13 2001-11-01 3000-01-01 2001-10-01 3000-01-01AB-GS-6371 0HE9 2002-01-01 2002-01-01 1.13 NOVA 2084 1.13 2001-11-01 3000-01-01 2001-10-01 3000-01-01

Injection Facilty Deleted Tie

Production Period

Billing Period

Operator ID

Reproducing Facilty ID

Effective Date

Termination Date

AB-IF-9847 2001-07-01 2002-01-01 0BP8 AB-GS-3709 2001-07-01 3000-01-01AB-IF-9905 2001-07-01 2002-01-01 0039 None 2001-07-01 3000-01-01

Injection and Reproducing Facility Ties